TECO Energy Inactive 10-Q1 May 152015 Q1 Quarterly reportFinancial data

Company Profile

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
Document and Entity Information	Mar. 31, 2015	Apr. 24, 2015
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Trading Symbol	TE
Entity Registrant Name	TECO ENERGY INC
Entity Central Index Key	350563
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		235,121,846
Tampa Electric Company [Member]
Document Information [Line Items]
Entity Registrant Name	TAMPA ELECTRIC COMPANY
Entity Central Index Key	96271
Current Fiscal Year End Date	-19
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		10

Consolidated_Condensed_Balance

Consolidated Condensed Balance Sheets (Unaudited) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$32.80	$25.40
Receivables, less allowance for uncollectibles	262.8	299.8
Inventories, at average cost
Derivative assets	0.3	0
Regulatory assets	52	53.6
Deferred income taxes	63.2	72.8
Prepayments and other current assets	32.2	22.6
Assets held for sale	97.1	109.6
Total current assets	728.7	755.6
Property, plant and equipment
Construction work in progress	634.7	640
Other property	14.6	14.5
Property, plant and equipment, at original costs	9,810.60	9,733.90
Accumulated depreciation	-2,645.90	-2,645.70
Total property, plant and equipment, net	7,164.70	7,088.20
Other assets
Regulatory assets	350	348.5
Goodwill	408.4	408.3
Deferred charges and other assets	64.8	65.8
Assets held for sale	60.9	59.8
Total other assets	884.1	882.4
Total assets	8,777.50	8,726.20
Current liabilities
Long-term debt due within one year	524.5	274.5
Notes payable	206	139
Accounts payable	248.4	288.6
Customer deposits	178.2	176.2
Regulatory liabilities	49.4	57
Derivative liabilities	35.5	36.6
Interest accrued	57.7	39.9
Taxes accrued	29	29.9
Other	16.7	16.8
Liabilities associated with assets held for sale	33.7	39.4
Total current liabilities	1,379.10	1,097.90
Other liabilities
Deferred income taxes	547.9	519.2
Investment tax credits	8.9	9
Regulatory liabilities	720	729
Derivative liabilities	5.3	6.1
Deferred credits and other liabilities	360.1	370.9
Liabilities associated with assets held for sale	65.7	65.4
Long-term debt, less amount due within one year	3,103.20	3,354
Total other liabilities	4,811.10	5,053.60
Commitments and contingencies (see Note 10)
Capital
Common equity	235.6	234.9
Additional paid in capital	1,881.90	1,875.90
Retained earnings	484.6	479.6
Accumulated other comprehensive loss	-14.8	-15.7
Total capital	2,587.30	2,574.70
Long-term debt	3,103.20	3,354
Total liabilities and capital	8,777.50	8,726.20
Tampa Electric Company [Member]
Current assets
Cash and cash equivalents	15	10.4
Receivables, less allowance for uncollectibles	213.7	227.2
Inventories, at average cost
Derivative assets	0.3	0
Taxes receivable from affiliate	0	43.3
Regulatory assets	51.6	52.1
Deferred income taxes	17.7	24.8
Prepayments and other current assets	22.5	17.4
Total current assets	499.3	532.6
Property, plant and equipment
Construction work in progress	626.9	624.2
Utility plant in service, at original costs	9,098.20	9,027.90
Accumulated depreciation	-2,627.70	-2,633.80
Utility plant in service, net	6,470.50	6,394.10
Other property	8.7	8.6
Total property, plant and equipment, net	6,479.20	6,402.70
Other assets
Unamortized debt expense	16.4	16.8
Regulatory assets	322.3	319.6
Deferred charges and other assets	341.6	339
Other	2.9	2.6
Total assets	7,320.10	7,274.30
Current liabilities
Long-term debt due within one year	83.3	83.3
Notes payable	47	58
Accounts payable	227.6	242.3
Customer deposits	172.4	170.4
Regulatory liabilities	48.8	54.7
Derivative liabilities	35.5	36.6
Interest accrued	39.9	17
Taxes accrued	41.8	12.4
Other	10	10
Total current liabilities	706.3	684.7
Other liabilities
Deferred income taxes	1,225.40	1,209.10
Investment tax credits	8.9	9
Regulatory liabilities	612.9	623.4
Derivative liabilities	5.3	6.1
Long-term debt, less amount due within one year	2,013.80	2,013.80
Total other liabilities	2,143.40	2,146.70
Other	290.9	299.1
Commitments and contingencies (see Note 10)
Capital
Common equity	2,150.40	2,130.40
Retained earnings	313	305.8
Accumulated other comprehensive loss	-6.8	-7.1
Total capital	2,456.60	2,429.10
Long-term debt	2,013.80	2,013.80
Total capitalization	4,470.40	4,442.90
Total liabilities and capital	7,320.10	7,274.30
Fuel [Member]
Inventories, at average cost
Utility inventories	113.6	96.4
Fuel [Member] \| Tampa Electric Company [Member]
Inventories, at average cost
Utility inventories	107	85.2
Materials and Supplies [Member]
Inventories, at average cost
Utility inventories	74.7	75.4
Materials and Supplies [Member] \| Tampa Electric Company [Member]
Inventories, at average cost
Utility inventories	71.5	72.2
Electric [Member]
Property, plant and equipment
Utility plant in service, at original costs	7,152.70	7,094.80
Electric [Member] \| Tampa Electric Company [Member]
Property, plant and equipment
Utility plant in service, at original costs	7,152.70	7,094.80
Gas [Member]
Property, plant and equipment
Utility plant in service, at original costs	2,008.60	1,984.60
Gas [Member] \| Tampa Electric Company [Member]
Property, plant and equipment
Utility plant in service, at original costs	$1,318.60	$1,308.90

Consolidated_Condensed_Balance1

Consolidated Condensed Balance Sheets (Unaudited) (Parenthetical) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, except Share data, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Allowance for uncollectibles	$2.20	$2.10
Common equity, shares authorized	400,000,000	400,000,000
Common equity, par value	$1	$1
Common equity, shares outstanding	235,600,000	234,900,000
Tampa Electric Company [Member]
Allowance for uncollectibles	$1.50	$1.40

Consolidated_Condensed_Stateme

Consolidated Condensed Statements of Income (Unaudited) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues
Regulated electric and gas	$689.90	$575.70
Unregulated	3.1	2.3
Total revenues	693	578
Expenses
Fuel	144.1	149.6
Purchased power	17.1	18.2
Cost of natural gas sold	103	47.1
Other	143.7	120.6
Operations and maintenance other expense	1.6	3.2
Depreciation and amortization	85.5	75.9
Taxes, other than income	51.8	47.8
Total expenses	546.8	462.4
Income from continuing operations	146.2	115.6
Other income
Allowance for other funds used during construction	3.8	2.4
Other income	1.6	-0.9
Total other income	5.4	1.5
Interest charges
Interest expense	49.8	41
Allowance for borrowed funds used during construction	-1.9	-1.4
Total interest charges	47.9	39.6
Income from continuing operations before provision for income taxes	103.7	77.5
Provision for income taxes	39.9	29.1
Net income from continuing operations	63.8	48.4
Discontinued operations
Income (loss) from discontinued operations	-9.6	1.2
Benefit from income taxes	-3.8	-0.5
Income (loss) on discontinued operations, net	-5.8	1.7
Net income	$58	$50.10
Average common shares outstanding - Basic	232.8	215.2
Average common shares outstanding - Diluted	233.5	215.7
Earnings per share from continuing operations - Basic	$0.27	$0.22
Earnings per share from continuing operations - Diluted	$0.27	$0.22
Earnings per share from discontinued operations - Basic	($0.02)	$0.01
Earnings per share from discontinued operations - Diluted	($0.02)	$0.01
Earnings per share - Basic	$0.25	$0.23
Earnings per share - Diluted	$0.25	$0.23
Dividends paid per common share outstanding	$0.23	$0.22

Consolidated_Condensed_Stateme1

Consolidated Condensed Statements of Comprehensive Income (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Statement Of Income And Comprehensive Income [Abstract]
Net income	$58		$50.10
Other comprehensive income, net of tax
Gain on cash flow hedges	0.3		0.2
Amortization of unrecognized benefit costs	0.6	[1]	0.5	[1]
Increase in unrecognized postemployment costs	0		-8.2
Other comprehensive income (loss), net of tax	0.9		-7.5
Comprehensive income	$58.90		$42.60

[1]	Related to postretirement and postemployment benefits. See Note 5 for additional information.

Consolidated_Condensed_Stateme2

Consolidated Condensed Statements of Cash Flows (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Cash flows from operating activities
Net income	$58	$50.10
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	85.9	84.9
Depreciation and amortization	85.5	75.9
Deferred income taxes and investment tax credits	36	28.8
Allowance for other funds used during construction	-3.8	-2.4
Non-cash stock compensation	3.9	3.7
Gain on sales of business/assets	0	-0.1
Deferred recovery clauses	-5.7	2.6
Receivables, less allowance for uncollectibles	51	18.1
Inventories	-15.7	0.4
Prepayments and other current assets	-10.9	-0.2
Taxes accrued	1.7	15.5
Interest accrued	17.8	22.9
Accounts payable	-63.5	-25.2
Other	-7.7	-12.2
Cash flows from operating activities	147	186.9
Cash flows from investing activities
Capital expenditures	-160	-136.3
Allowance for other funds used during construction	3.8	2.4
Other investing activities	-0.2	0.2
Cash flows used in investing activities	-156.4	-133.7
Cash flows from financing activities
Dividends	-53	-48
Proceeds from the sale of common stock	2.8	1.6
Net increase (decrease) in short-term debt	67	-55
Cash flows from (used) in financing activities	16.8	-101.4
Net increase (decrease) in cash and cash equivalents	7.4	-48.2
Cash and cash equivalents at beginning of the period	25.4	185.2
Cash and cash equivalents at end of the period	32.8	137
Supplemental disclosure of non-cash activities
Change in accrued capital expenditures	11.5	14.6
Tampa Electric Company [Member]
Cash flows from operating activities
Net income	62.8	59.8
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	76.8	75.4
Deferred income taxes and investment tax credits	21.2	22.7
Allowance for other funds used during construction	-3.8	-2.4
Deferred recovery clauses	-4.7	2.6
Receivables, less allowance for uncollectibles	13.5	12.7
Inventories	-21.1	9.3
Prepayments	-5	-0.2
Taxes accrued	72.7	82.4
Interest accrued	22.9	20.9
Accounts payable	-28.3	-23.3
Other	-6.9	-9.1
Cash flows from operating activities	200.1	250.8
Cash flows from investing activities
Capital expenditures	-152.6	-132
Allowance for other funds used during construction	3.8	2.4
Cash flows used in investing activities	-148.8	-129.6
Cash flows from financing activities
Dividends	-55.7	-66.1
Proceeds from the sale of common stock	20	7
Net increase (decrease) in short-term debt	-11	-55
Cash flows from (used) in financing activities	-46.7	-114.1
Net increase (decrease) in cash and cash equivalents	4.6	7.1
Cash and cash equivalents at beginning of the period	10.4	9.8
Cash and cash equivalents at end of the period	15	16.9
Supplemental disclosure of non-cash activities
Change in accrued capital expenditures	$11.40	$14.70

Consolidated_Condensed_Stateme3

Consolidated Condensed Statements of Income and Comprehensive Income (Unaudited) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues
Total revenues	$693	$578
Expenses
Fuel	144.1	149.6
Purchased power	17.1	18.2
Cost of natural gas sold	103	47.1
Other	143.7	120.6
Depreciation and amortization	85.5	75.9
Taxes, other than income	51.8	47.8
Total expenses	546.8	462.4
Income from continuing operations	146.2	115.6
Other income
Allowance for other funds used during construction	3.8	2.4
Total other income	5.4	1.5
Interest charges
Interest on long-term debt	49.8	41
Allowance for borrowed funds used during construction	-1.9	-1.4
Total interest charges	47.9	39.6
Income from continuing operations before provision for income taxes	103.7	77.5
Provision for income taxes	39.9	29.1
Net income	58	50.1
Other comprehensive income, net of tax
Gain on cash flow hedges	0.3	0.2
Other comprehensive income (loss), net of tax	0.9	-7.5
Comprehensive income	58.9	42.6
Tampa Electric Company [Member]
Revenues
Electric	450.4	453
Gas	121.7	122.5
Total revenues	572.1	575.5
Expenses
Fuel	144.1	149.6
Purchased power	17.1	18.2
Cost of natural gas sold	43.3	47.2
Other	121.8	120.3
Depreciation and amortization	76.8	75.4
Taxes, other than income	47.6	47.4
Total expenses	450.7	458.1
Income from continuing operations	121.4	117.4
Other income
Allowance for other funds used during construction	3.8	2.4
Other income, net	1.2	1.2
Total other income	5	3.6
Interest charges
Interest on long-term debt	27.7	25.7
Other interest	1.1	1.1
Allowance for borrowed funds used during construction	-1.8	-1.4
Total interest charges	27	25.4
Income from continuing operations before provision for income taxes	99.4	95.6
Provision for income taxes	36.6	35.8
Net income	62.8	59.8
Other comprehensive income, net of tax
Gain on cash flow hedges	0.3	0.2
Other comprehensive income (loss), net of tax	0.3	0.2
Comprehensive income	$63.10	$60

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
Summary of Significant Accounting Policies	Mar. 31, 2015
Summary of Significant Accounting Policies	1. Summary of Significant Accounting Policies
	See TECO Energy, Inc.’s 2014 Annual Report on Form 10-K for a complete discussion of accounting policies. The significant accounting policies for all utility and diversified operations include:
	Principles of Consolidation and Basis of Presentation
	Intercompany balances and intercompany transactions have been eliminated in consolidation. In the opinion of management, the unaudited consolidated condensed financial statements include all adjustments that are of a recurring nature and necessary to state fairly the financial position of TECO Energy, Inc. and its subsidiaries as of Mar. 31, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended Mar. 31, 2015 and 2014. The results of operations for the three months ended Mar. 31, 2015 are not necessarily indicative of the results that can be expected for the entire fiscal year ending Dec. 31, 2015.
	The consolidated financial statements include NMGI and NMGC from the acquisition date of Sept. 2, 2014 through Mar. 31, 2015. In addition, all periods have been adjusted to reflect the reclassification of results from operations to discontinued operations for TECO Coal and certain charges at Parent that directly related to TECO Coal (see Note 15).
	The use of estimates is inherent in the preparation of financial statements in accordance with U.S. GAAP. Actual results could differ from these estimates. The year-end consolidated condensed balance sheet data was derived from audited financial statements; however, this quarterly report on Form 10-Q does not include all year-end disclosures required for an annual report on Form 10-K by U.S. GAAP.
	Revenues
	As of Mar. 31, 2015 and Dec. 31, 2014, unbilled revenues of $63.8 million and $86.6 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets.
	Accounting for Excise Taxes, Franchise Fees and Gross Receipts
	TECO Coal incurs most of TECO Energy’s total excise taxes, which are accrued as an expense and reconciled to the actual cash payment of excise taxes. As general expenses, they are not specifically recovered through revenues. Excise taxes paid by the regulated utilities are not material and are expensed when incurred.
	Tampa Electric and PGS are allowed to recover certain costs from customers on a dollar-per-dollar basis through prices approved by the FPSC. The amounts included in customers’ bills for franchise fees and gross receipt taxes are included as revenues on the Consolidated Condensed Statements of Income. Franchise fees and gross receipt taxes payable by Tampa Electric and PGS are included as an expense on the Consolidated Condensed Statements of Income in “Taxes, other than income”. These amounts totaled $27.4 million and $27.2 million for the three months ended Mar. 31, 2015 and 2014, respectively.
	NMGC is an agent in the collection and payment of franchise fees and gross receipt taxes and is not required by a tariff to present the amounts on a gross basis. Therefore, NMGC’s franchise fees and gross receipt taxes are presented net with no line-item impact on the Consolidated Condensed Statements of Income.
Tampa Electric Company [Member]
Summary of Significant Accounting Policies	1. Summary of Significant Accounting Policies
	See TEC’s 2014 Annual Report on Form 10-K for a complete discussion of accounting policies. The significant accounting policies for TEC include:
	Principles of Consolidation and Basis of Presentation
	TEC is a wholly owned subsidiary of TECO Energy, Inc. For the purposes of its consolidated financial reporting, TEC is comprised of the electric division, generally referred to as Tampa Electric, the natural gas division, generally referred to as PGS, and potentially the accounts of VIEs for which it is the primary beneficiary. For the periods presented, no VIEs have been consolidated (see Note 13).
	Intercompany balances and intercompany transactions have been eliminated in consolidation. In the opinion of management, the unaudited consolidated condensed financial statements include all adjustments that are of a recurring nature and necessary to state fairly the financial position of TEC as of Mar. 31, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended Mar. 31, 2015 and 2014. The results of operations for the three months ended Mar. 31, 2015 are not necessarily indicative of the results that can be expected for the entire fiscal year ending Dec. 31, 2015.
	The use of estimates is inherent in the preparation of financial statements in accordance with U.S. GAAP. Actual results could differ from these estimates. The year-end consolidated condensed balance sheet data was derived from audited financial statements; however, this quarterly report on Form 10-Q does not include all year-end disclosures required for an annual report on Form 10-K by U.S. GAAP.
	Revenues
	As of Mar. 31, 2015 and Dec. 31, 2014, unbilled revenues of $52.5 million and $49.3 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets.
	Accounting for Excise Taxes, Franchise Fees and Gross Receipts
	Tampa Electric and PGS are allowed to recover certain costs from customers on a dollar-per-dollar basis through prices approved by the FPSC. The amounts included in customers’ bills for franchise fees and gross receipt taxes are included as revenues on the Consolidated Condensed Statements of Income. Franchise fees and gross receipt taxes payable by Tampa Electric and PGS are included as an expense on the Consolidated Condensed Statements of Income in “Taxes, other than income”. These amounts totaled $27.4 million and $27.2 million for the three months ended Mar. 31, 2015 and 2014, respectively.

New_Accounting_Pronouncements

New Accounting Pronouncements	3 Months Ended
New Accounting Pronouncements	Mar. 31, 2015
New Accounting Pronouncements	2. New Accounting Pronouncements
	Revenue from Contracts with Customers
	In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. The standard is principle-based and provides a five-step model to determine when and how revenue is recognized. The core principle is that a company should recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. This guidance is effective for the company beginning in 2017 and allows for either full retrospective adoption or modified retrospective adoption. The company is currently evaluating the impact of the adoption of this guidance on its financial statements but does not expect the impact to be significant.
	Presentation of Debt Issuance Costs
	In April 2015, the FASB issued guidance regarding the presentation of debt issuance costs on the balance sheet. Under the new guidance, an entity is required to present debt issuance costs as a direct deduction from the carrying amount of the related debt liability rather than as a deferred charge (i.e., as an asset) under current guidance. This guidance is effective for the company beginning in 2016 and is required to be applied on a retrospective basis for all periods presented.
Tampa Electric Company [Member]
New Accounting Pronouncements	2. New Accounting Pronouncements
	Revenue from Contracts with Customers
	In May 2014, the FASB issued guidance regarding the accounting for revenue from contracts with customers. The standard is principle-based and provides a five-step model to determine when and how revenue is recognized. The core principle is that a company should recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. This guidance is effective for TEC beginning in 2017 and allows for either full retrospective adoption or modified retrospective adoption. TEC is currently evaluating the impact of the adoption of this guidance on its financial statements but does not expect the impact to be significant.
	Presentation of Debt Issuance Costs
	In April 2015, the FASB issued guidance regarding the presentation of debt issuance costs on the balance sheet. Under the new guidance, an entity is required to present debt issuance costs as a direct deduction from the carrying amount of the related debt liability rather than as a deferred charge (i.e., as an asset) under current guidance. This guidance is effective for TEC beginning in 2016 and is required to be applied on a retrospective basis for all periods presented.

Regulatory

Regulatory	3 Months Ended
Regulatory	Mar. 31, 2015
Regulatory	3. Regulatory
	Tampa Electric’s retail business and PGS are regulated by the FPSC. Tampa Electric is also subject to regulation by the FERC under PUHCA 2005. The operations of PGS are regulated by the FPSC separately from the operations of Tampa Electric. The FPSC has jurisdiction over rates, service, issuance of securities, safety, accounting and depreciation practices and other matters. In general, the FPSC sets rates at a level that allows utilities such as Tampa Electric and PGS to collect total revenues (revenue requirements) equal to their cost of providing service, plus a reasonable return on invested capital.
	NMGC is subject to regulation by the NMPRC. The NMPRC has jurisdiction over the regulatory matters related, directly and indirectly, to NMGC providing service to its customers, including, among other things, rates, accounting procedures, securities issuances, and standards of service. NMGC must follow certain accounting guidance that pertains specifically to entities that are subject to such regulation. Comparable to the FPSC, the NMPRC sets rates at a level that allows utilities such as NMGC to collect total revenues (revenue requirement) equal to their cost of providing service, plus a reasonable return on invested capital.

	Regulatory Assets and Liabilities
	Tampa Electric, PGS and NMGC apply the accounting standards for regulated operations. Areas of applicability include: deferral of revenues under approved regulatory agreements; revenue recognition resulting from cost-recovery clauses that provide for monthly billing charges to reflect increases or decreases in fuel, purchased power, conservation and environmental costs; the deferral of costs as regulatory assets to the period in which the regulatory agency recognizes them when cost recovery is ordered over a period longer than a fiscal year; and the advance recovery of expenditures for approved costs such as future storm damage or the future removal of property.
	Details of the regulatory assets and liabilities as of Mar. 31, 2015 and Dec. 31, 2014 are presented in the following table:

	Regulatory Assets and Liabilities
	(millions)	Mar. 31, 2015		Dec. 31, 2014
	Regulatory assets:
	Regulatory tax asset (1)	$	70.5	$	69.2
	Other:
	Cost-recovery clauses		42.8		45.1
	Postretirement benefit asset (2)		195.6		194
	Deferred bond refinancing costs (3)		7		7.2
	Debt basis adjustment (3)		20.1		20.9
	Environmental remediation		53.4		53.1
	Competitive rate adjustment		2.6		2.8
	Other		10		9.8
	Total other regulatory assets		331.5		332.9
	Total regulatory assets		402		402.1
	Less: Current portion		52		53.6
	Long-term regulatory assets	$	350	$	348.5
	Regulatory liabilities:
	Regulatory tax liability (1)	$	6.6	$	6.9
	Other:
	Cost-recovery clauses		19.4		25.9
	Transmission and delivery storm reserve		56.1		56.1
	Deferred gain on property sales (4)		0.5		0.8
	Accumulated reserve - cost of removal		686		695.2
	Other		0.8		1.1
	Total other regulatory liabilities		762.8		779.1
	Total regulatory liabilities		769.4		786
	Less: Current portion		49.4		57
	Long-term regulatory liabilities	$	720	$	729
	-1	Primarily related to plant life and derivative positions.
	-2	Amortized over remaining service life of plan participants.
	-3	Amortized over the term of the related debt instruments.
	-4	Amortized over a 5-year period with various ending dates.
	All regulatory assets are recovered through the regulatory process. The following table further details the regulatory assets and the related recovery periods:

	Regulatory Assets
		Mar. 31,		Dec. 31,
	(millions)	2015		2014
	Clause recoverable (1)	$	45.4	$	47.9
	Components of rate base (2)		200.7		199
	Regulatory tax assets (3)		70.5		69.2
	Capital structure and other (3)		85.4		86
	Total	$	402	$	402.1
	-1	To be recovered through cost-recovery mechanisms approved by the FPSC or NMPRC, as applicable, on a dollar-for-dollar basis in the next year.
	-2	Primarily reflects allowed working capital, which is included in rate base and earns a rate of return as permitted by the FPSC.
	-3	“Regulatory tax assets” and “Capital structure and other” regulatory assets, including environmental remediation, have a recoverable period longer than a fiscal year and are recognized over the period authorized by the regulatory agency. Also included are unamortized loan costs, which are amortized over the life of the related debt instruments. See footnotes 1 and 2 in the prior table for additional information.
Tampa Electric Company [Member]
Regulatory	3. Regulatory
	Tampa Electric’s and PGS’s retail businesses are regulated by the FPSC. Tampa Electric is also subject to regulation by the FERC under PUHCA 2005. The operations of PGS are regulated by the FPSC separately from the operations of Tampa Electric. The FPSC has jurisdiction over rates, service, issuance of securities, safety, accounting and depreciation practices and other matters. In general, the FPSC sets rates at a level that allows utilities such as Tampa Electric and PGS to collect total revenues (revenue requirements) equal to their cost of providing service, plus a reasonable return on invested capital.
	Regulatory Assets and Liabilities
	Tampa Electric and PGS apply the accounting standards for regulated operations. Areas of applicability include: deferral of revenues under approved regulatory agreements; revenue recognition resulting from cost-recovery clauses that provide for monthly billing charges to reflect increases or decreases in fuel, purchased power, conservation and environmental costs; the deferral of costs as regulatory assets to the period in which the regulatory agency recognizes them when cost recovery is ordered over a period longer than a fiscal year; and the advance recovery of expenditures for approved costs such as future storm damage or the future removal of property.
	Details of the regulatory assets and liabilities as of Mar. 31, 2015 and Dec. 31, 2014 are presented in the following table:

	Regulatory Assets and Liabilities
	(millions)	Mar. 31, 2015		Dec. 31, 2014
	Regulatory assets:
	Regulatory tax asset (1)	$	70.5	$	69.2
	Other:
	Cost-recovery clauses		42.4		43.6
	Postretirement benefit asset (2)		189.7		187.8
	Deferred bond refinancing costs (3)		7		7.2
	Environmental remediation		53.4		53.1
	Competitive rate adjustment		2.6		2.8
	Other		8.3		8
	Total other regulatory assets		303.4		302.5
	Total regulatory assets		373.9		371.7
	Less: Current portion		51.6		52.1
	Long-term regulatory assets	$	322.3	$	319.6
	Regulatory liabilities:
	Regulatory tax liability (1)	$	4.9	$	5.1
	Other:
	Cost-recovery clauses		18.8		23.5
	Transmission and delivery storm reserve		56.1		56.1
	Deferred gain on property sales (4)		0.5		0.8
	Accumulated reserve - cost of removal		580.7		591.5
	Provision for stipulation and other		0.7		1.1
	Total other regulatory liabilities		656.8		673
	Total regulatory liabilities		661.7		678.1
	Less: Current portion		48.8		54.7
	Long-term regulatory liabilities	$	612.9	$	623.4
	-1	Primarily related to plant life and derivative positions.
	-2	Amortized over the remaining service life of plan participants.
	-3	Amortized over the term of the related debt instruments.
	-4	Amortized over a 5-year period with various ending dates.
	All regulatory assets are recovered through the regulatory process. The following table further details the regulatory assets and the related recovery periods:

	Regulatory Assets
		Mar. 31,		Dec. 31,
	(millions)	2015		2014
	Clause recoverable (1)	$	45	$	46.4
	Components of rate base (2)		193		191
	Regulatory tax assets (3)		70.5		69.2
	Capital structure and other (3)		65.4		65.1
	Total	$	373.9	$	371.7
	-1	To be recovered through cost-recovery mechanisms approved by the FPSC on a dollar-for-dollar basis in the next year.
	-2	Primarily reflects allowed working capital, which is included in rate base and earns a rate of return as permitted by the FPSC.
	-3	“Regulatory tax assets” and “Capital structure and other” regulatory assets, including environmental remediation, have a recoverable period longer than a fiscal year and are recognized over the period authorized by the regulatory agency. Also included are unamortized loan costs, which are amortized over the life of the related debt instruments. See footnotes 1 and 2 in the prior table for additional information.

Income_Taxes

Income Taxes	3 Months Ended
Income Taxes	Mar. 31, 2015
Income Taxes	4. Income Taxes
	The effective tax rate increased to 38.48% for the three months ended Mar. 31, 2015 from 37.55% for the same period in 2014.
	The company’s U.S. subsidiaries join in the filing of a U.S. federal consolidated income tax return. The IRS concluded its examination of the company’s 2013 consolidated federal income tax return in January 2015. The U.S. federal statute of limitations remains open for the year 2011 and forward. Years 2014 and 2015 are currently under examination by the IRS under its Compliance Assurance Program. TECO Energy does not expect the results of current IRS examinations to significantly change the total amount of unrecognized tax benefits by the end of 2015. U.S. state jurisdictions have statutes of limitations generally ranging from three to four years from the filing of an income tax return. Additionally, any state net operating losses that were generated in prior years and are still being utilized are subject to examination by state jurisdictions. The state impact of any federal changes remains subject to examination by various states for a period of up to one year after formal notification to the states. Years still open to examination by taxing authorities in major state jurisdictions and foreign jurisdictions include 2005 and forward.
Tampa Electric Company [Member]
Income Taxes	4. Income Taxes

	TEC is included in the filing of a consolidated federal income tax return with TECO Energy and its affiliates. TEC’s income tax expense is based upon a separate return computation. TEC’s effective tax rates for the three months ended Mar. 31, 2015 and 2014 differ from the statutory rate principally due to state income taxes, the domestic activity production deduction and the AFUDC-equity.
	The IRS concluded its examination of TECO Energy’s 2013 consolidated federal income tax return in January 2015. The U.S. federal statute of limitations remains open for the year 2010 and forward. Years 2014 and 2015 are currently under examination by the IRS under its Compliance Assurance Program. TECO Energy does not expect the results of current IRS examinations to significantly change the total amount of unrecognized tax benefits by the end of 2015. Florida’s statute of limitations is three years from the filing of an income tax return. The state impact of any federal changes remains subject to examination by various states for a period of up to one year after formal notification to the states. Years still open to examination by Florida’s tax authorities include 2005 and forward as a result of TECO Energy’s consolidated Florida net operating loss still being utilized.

Employee_Postretirement_Benefi

Employee Postretirement Benefits	3 Months Ended
Employee Postretirement Benefits	Mar. 31, 2015
Employee Postretirement Benefits	5. Employee Postretirement Benefits
	Included in the table below is the periodic expense for pension and other postretirement benefits offered by the company.

	Pension Expense
	(millions)	Pension Benefits						Other Postretirement Benefits
	Three months ended Mar. 31,	2015			2014			2015			2014
	Components of net periodic benefit expense
	Service cost	$	4.5		$	4.1		$	0.6		$	0.6
	Interest cost		7.4			8.2			2			2.6
	Expected return on assets		(10.8	)		(10.3	)		(0.3	)		0
	Amortization of:
	Prior service (benefit) cost		(0.1	)		(0.1	)		(0.6	)		0
	Actuarial loss		3.4			3.2			0			0
	Regulatory asset		0			0			0.3			0
	Net pension expense recognized in the	$	4.4		$	5.1		$	2		$	3.2
	TECO Energy Consolidated Condensed Statements of Income	$	4.4		$	5.1		$	2		$	3.2
	For the fiscal 2015 plan year, TECO Energy is using an assumed long-term EROA of 7.00% and a discount rate of 4.256% for pension benefits under its qualified pension plan. For the Jan. 1, 2015 measurement of TECO Energy’s other postretirement benefits, TECO Energy assumed a discount rate of 4.206%. Additionally, TECO Energy made contributions of $14.9 million and $16.0 million to its pension plan for the three months ended Mar. 31, 2015 and 2014, respectively.
	For the three months ended Mar. 31, 2015 and 2014, TECO Energy and its subsidiaries reclassified $0.8 million and $0.6 million, respectively, of pretax unamortized prior service benefit and actuarial losses from AOCI to net income as part of periodic benefit expense. In addition, during the three months ended Mar. 31, 2015 and 2014, the regulated companies reclassified $2.2 million and $2.5 million, respectively, of unamortized prior service benefit and actuarial losses from regulatory assets to net income as part of periodic benefit expense.

	Black Lung Liability
	TECO Coal is required by federal and state statutes to provide benefits to terminated, retired or (under state statutes) qualifying active employees for benefits related to black lung disease. TECO Coal is self-insured for black lung related claims. TECO Coal applies the accounting guidance of ASC 715, Compensation – Retirement Benefits, and annual expense is recorded for black lung obligations as determined by an independent actuary at the present value of the actuarially-computed liability for such benefits over the employee’s applicable term of service. At Mar. 31, 2015 and Dec. 31, 2014, TECO Coal had an actuarially-determined black lung liability of $24.8 million and $24.7 million, respectively. Expense related to the black lung liability recognized during the three months ended Mar. 31, 2015 and 2014 was not material.
	As discussed in Note 15, TECO Coal was classified as an asset held for sale at Mar. 31, 2015. In accordance with ASC 715, an after-tax settlement charge of approximately $7.7 million related to the unfunded black lung obligations recorded in AOCI will be recognized as a loss from discontinued operations upon completion of the sale of TECO Coal, which is expected to occur in 2015.

Tampa Electric Company [Member]
Employee Postretirement Benefits	5. Employee Postretirement Benefits
	TEC is a participant in the comprehensive retirement plans of TECO Energy. Amounts allocable to all participants of the TECO Energy retirement plans are found in Note 5, Employee Postretirement Benefits, in the TECO Energy, Inc. Notes to Consolidated Condensed Financial Statements. TEC’s portion of the net pension expense for the three months ended Mar. 31, 2015 and 2014, respectively, was $2.6 million and $3.8 million for pension benefits, and $1.4 million and $2.6 million for other postretirement benefits.
	For the fiscal 2015 plan year, TECO Energy assumed a long-term EROA of 7.00% and a discount rate of 4.256%. For the Jan. 1, 2015 measurement of TECO Energy’s other postretirement benefits, TECO Energy used a discount rate of 4.206%. Additionally, TECO Energy made contributions of $14.9 million and $16.0 million to its pension plan in the three months ended Mar. 31, 2015 and 2014, respectively. TEC’s portion of the contributions was $11.0 million and $13.0 million, respectively.
	Included in the benefit expenses discussed above, for the three months ended Mar. 31, 2015 and 2014, TEC reclassified $1.9 million and $2.5 million, respectively, of unamortized transition obligation, prior service cost and actuarial losses from regulatory assets to net income.

ShortTerm_Debt

Short-Term Debt	3 Months Ended
Short-Term Debt	Mar. 31, 2015
Short-Term Debt
	6. Short-Term Debt
	At Mar. 31, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed:

	Credit Facilities
		Mar. 31, 2015						Dec. 31, 2014
						Letters						Letters
		Credit		Borrowings		of Credit		Credit		Borrowings		of Credit
	(millions)	Facilities		Outstanding (1)		Outstanding		Facilities		Outstanding (1)		Outstanding
	Tampa Electric Company:
	5-year facility (2)	$	325	$	5	$	0.6	$	325	$	12	$	0.6
	1-year accounts		150		42		0		150		46		0
	receivable facility		150		42		0		150		46		0
	TECO Energy/TECO Finance:
	5-year facility (2)(3)		300		144		0		300		50		0
	New Mexico Gas Company:
	5-year facility (2)		125		15		2.3		125		31		1.7
	Total	$	900	$	206	$	2.9	$	900	$	139	$	2.3

	(1) Borrowings outstanding are reported as notes payable.
	(2) This 5-year facility matures Dec. 17, 2018.
	(3) TECO Finance is the borrower and TECO Energy is the guarantor of this facility.


	At Mar. 31, 2015, these credit facilities required commitment fees ranging from 12.5 to 30.0 basis points. The weighted-average interest rate on outstanding amounts payable under the credit facilities at Mar. 31, 2015 and Dec. 31, 2014 was 1.12% and 1.16%, respectively.
	Tampa Electric Company Accounts Receivable Facility
	On Mar. 24, 2015, TEC and TRC amended and restated their $150 million accounts receivable collateralized borrowing facility in order to (i) appoint The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch (BTMU), as Program Agent, replacing the previous Program Agent, Citibank, N.A., (ii) add new lenders, and (iii) extend the scheduled termination date from Apr. 14, 2015 to Mar. 23, 2018, by entering into (a) an Amended and Restated Purchase and Contribution Agreement dated as of Mar. 24, 2015 between TEC and TRC and (b) a Loan and Servicing Agreement dated as of Mar. 24, 2015, among TEC as Servicer, TRC as Borrower, certain lenders named therein and BTMU, as Program Agent.
Tampa Electric Company [Member]
Short-Term Debt	6. Short-Term Debt
	At Mar. 31, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed:

	Credit Facilities
		Mar. 31, 2015						Dec. 31, 2014
						Letters						Letters
		Credit		Borrowings		of Credit		Credit		Borrowings		of Credit
	(millions)	Facilities		Outstanding (1)		Outstanding		Facilities		Outstanding (1)		Outstanding
	Tampa Electric Company:
	5-year facility (2)	$	325	$	5	$	0.6	$	325	$	12	$	0.6
	1-year accounts		150		42		0		150		46		0
	receivable facility		150		42		0		150		46		0
	Total	$	475	$	47	$	0.6	$	475	$	58	$	0.6
	-1	Borrowings outstanding are reported as notes payable.
	-2	This 5-year facility matures Dec. 17, 2018.
	At Mar. 31, 2015, these credit facilities required commitment fees ranging from 12.5 to 30.0 basis points. The weighted-average interest rate on outstanding amounts payable under the credit facilities at Mar. 31, 2015 and Dec. 31, 2014 was 0.87% and 0.7%, respectively.
	Tampa Electric Company Accounts Receivable Facility
	On Mar. 24, 2015, TEC and TRC amended and restated their $150 million accounts receivable collateralized borrowing facility in order to (i) appoint The Bank of Tokyo-Mitsubishi UFJ, Ltd., New York Branch (BTMU), as Program Agent, replacing the previous Program Agent, Citibank, N.A., (ii) add new lenders, and (iii) extend the scheduled termination date from Apr. 14, 2015 to Mar. 23, 2018, by entering into (a) an Amended and Restated Purchase and Contribution Agreement dated as of Mar. 24, 2015 between TEC and TRC and (b) a Loan and Servicing Agreement dated as of Mar. 24, 2015, among TEC as Servicer, TRC as Borrower, certain lenders named therein and BTMU, as Program Agent.

LongTerm_Debt

Long-Term Debt	3 Months Ended
Long-Term Debt	Mar. 31, 2015
Long-Term Debt	7. Long-Term Debt
	Fair Value of Long-Term Debt
	At Mar. 31, 2015, total long-term debt had a carrying amount of $3,627.7 million and an estimated fair market value of $4,035.8 million. At Dec. 31, 2014, total long-term debt had a carrying amount of $3,628.5 million and an estimated fair market value of $3,987.8 million. The company uses the market approach in determining fair value. The majority of the outstanding debt is valued using real-time financial market data obtained from Bloomberg Professional Service. The remaining securities are valued using prices obtained from the Municipal Securities Rulemaking Board and by applying estimated credit spreads obtained from a third party to the par value of the security. All debt securities are Level 2 instruments.

	Issuance of TECO Finance Floating Rate Notes due 2018
	On Apr. 10, 2015, TECO Finance completed an offering of $250 million aggregate principal amount of floating rate notes due 2018, which are guaranteed by TECO Energy. See Note 16 for additional information.
Tampa Electric Company [Member]
Long-Term Debt	7. Long-Term Debt
	Fair Value of Long-Term Debt
	At Mar. 31, 2015, TEC’s total long-term debt had a carrying amount of $2,097.1 million and an estimated fair market value of $2,414.8 million. At Dec. 31, 2014, TEC’s total long-term debt had a carrying amount of $2,097.1 million and an estimated fair market value of $2,372.2 million. TEC uses the market approach in determining fair value. The majority of the outstanding debt is valued using real-time financial market data obtained from Bloomberg Professional Service. The remaining securities are valued using prices obtained from the Municipal Securities Rulemaking Board and by applying estimated credit spreads obtained from a third party to the par value of the security. All debt securities are Level 2 instruments.

Other_Comprehensive_Income

Other Comprehensive Income	3 Months Ended
Other Comprehensive Income	Mar. 31, 2015
Other Comprehensive Income

	8. Other Comprehensive Income
	TECO Energy reported the following OCI for the three months ended Mar. 31, 2015 and 2014, related to changes in the fair value of cash flow hedges and amortization of unrecognized benefit costs associated with the company’s postretirement plans:

	Other Comprehensive Income
			Three months ended Mar. 31,
	(millions)		Gross				Tax				Net
	2015
	Unrealized gain on cash flow hedges		$	0.3			$	(0.2	)		$	0.1
	Reclassification from AOCI to net income (1)			0.4				(0.2	)			0.2
	Gain on cash flow hedges			0.7				(0.4	)			0.3
	Amortization of unrecognized benefit costs (2)			0.9				(0.3	)			0.6
	Total other comprehensive income (loss)		$	1.6			$	(0.7	)		$	0.9
	2014
	Unrealized loss on cash flow hedges		$	(0.1	)		$	0			$	(0.1	)
	Reclassification from AOCI to net income (1)			0.4				(0.1	)			0.3
	Gain on cash flow hedges			0.3				(0.1	)			0.2
	Amortization of unrecognized benefit costs (2)			0.8				(0.3	)			0.5
	Increase in unrecognized postemployment costs (3)			(12.9	)			4.7				(8.2	)
	Total other comprehensive income (loss)		$	(11.8	)		$	4.3			$	(7.5	)

	(1) Related to interest rate contracts recognized in Interest expense and commodity contracts recognized in Income (loss) from discontinued operations.
	(2) Related to postretirement and postemployment benefits. See Note 5 for additional information.
	(3) Amounts reflect an out-of-period adjustment related to TECO Coal's unfunded black lung liability.



	Accumulated Other Comprehensive Loss
	(millions)		Mar. 31, 2015				Dec. 31, 2014
	Unamortized pension loss and prior service credit (1)		$	(22.0	)		$	(22.5	)
	Unamortized other benefit gains, prior service costs and			14				13.9
	transition obligations (2)			14				13.9
	Net unrealized losses from cash flow hedges (3)			(6.8	)			(7.1	)
	Total accumulated other comprehensive loss		$	(14.8	)		$	(15.7	)

	(1) Net of tax benefit of $13.5 million and $13.8 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.
	(2) Net of tax expense of $8.4 million and $8.3 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively. Balance includes a $7.7 million loss as of Mar. 31, 2015 related to TECO Coal's unfunded black lung liability that will be reclassified from AOCI to net income from discontinued operations upon the settlement of the black lung obligation at the sale date. See Note 15.
	(3) Net of tax benefit of $4.1 million and $4.5 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.

Tampa Electric Company [Member]
Other Comprehensive Income	12. Other Comprehensive Income

	Other Comprehensive Income	Three months ended Mar. 31,
	(millions)	Gross				Tax				Net
	2015
	Unrealized gain on cash flow hedges	$	0.3			$	(0.2	)		$	0.1
	Reclassification from AOCI to net income		0.4				(0.2	)			0.2
	Gain on cash flow hedges		0.7				(0.4	)			0.3
	Total other comprehensive income	$	0.7			$	(0.4	)		$	0.3
	2014
	Unrealized gain on cash flow hedges	$	0			$	0			$	0
	Reclassification from AOCI to net income		0.4				(0.2	)			0.2
	Gain on cash flow hedges		0.4				(0.2	)			0.2
	Total other comprehensive income	$	0.4			$	(0.2	)		$	0.2


	Accumulated Other Comprehensive Loss
	(millions)	Mar. 31, 2015				Dec. 31, 2014
	Net unrealized losses from cash flow hedges (1)	$	(6.8	)		$	(7.1	)
	Total accumulated other comprehensive loss	$	(6.8	)		$	(7.1	)
	-1	Net of tax benefit of $4.1 million and $4.5 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.

Earnings_Per_Share

Earnings Per Share	3 Months Ended
Earnings Per Share	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Share	9. Earnings Per Share

		For the three months ended Mar. 31,
	(millions, except per share amounts)	2015			2014 (1)
	Basic earnings per share
	Net income from continuing operations	$	63.8		$	48.4
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Income before discontinued operations available to	$	63.6		$	48.2
	common shareholders - Basic	$	63.6		$	48.2
	Income (Loss) from discontinued operations, net	$	(5.8	)	$	1.7
	Amount allocated to nonvested participating shareholders		0			0
	Income (Loss) from discontinued operations available to	$	(5.8	)	$	1.7
	common shareholders - Basic	$	(5.8	)	$	1.7
	Net income	$	58		$	50.1
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Net income available to common shareholders - Basic	$	57.8		$	49.9
	Average common shares outstanding - Basic		232.8			215.2
	Earnings per share from continuing operations available to	$	0.27		$	0.22
	common shareholders - Basic	$	0.27		$	0.22
	Earnings per share from discontinued operations available to	$	(0.02	)	$	0.01
	common shareholders - Basic	$	(0.02	)	$	0.01
	Earnings per share available to common shareholders - Basic	$	0.25		$	0.23
	Diluted earnings per share
	Net income from continuing operations	$	63.8		$	48.4
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Income before discontinued operations available to	$	63.6		$	48.2
	common shareholders - Diluted	$	63.6		$	48.2
	Income (Loss) from discontinued operations, net	$	(5.8	)	$	1.7
	Amount allocated to nonvested participating shareholders		0			0
	Income (Loss) from discontinued operations available to	$	(5.8	)	$	1.7
	common shareholders - Diluted	$	(5.8	)	$	1.7
	Net income	$	58		$	50.1
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Net income available to common shareholders - Diluted	$	57.8		$	49.9
	Unadjusted average common shares outstanding - Diluted		232.8			215.2
	Assumed conversion of stock options, unvested restricted stock and		0.7			0.5
	contingent performance shares, net		0.7			0.5
	Average common shares outstanding - Diluted		233.5			215.7
	Earnings per share from continuing operations available to	$	0.27		$	0.22
	common shareholders - Diluted	$	0.27		$	0.22
	Earnings per share from discontinued operations available to	$	(0.02	)	$	0.01
	common shareholders - Diluted	$	(0.02	)	$	0.01
	Earnings per share available to common shareholders - Diluted	$	0.25		$	0.23
	Anti-dilutive shares		0.1			0
	(1) All prior periods presented reflect the classification of TECO Coal as discontinued operations (see Note 15).

Commitments_and_Contingencies

Commitments and Contingencies

3 Months Ended

Mar. 31, 2015

Commitments and Contingencies

10. Commitments and Contingencies

Legal Contingencies

From time to time, TECO Energy and its subsidiaries are involved in various legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies in the ordinary course of its business. Where appropriate, accruals are made in accordance with accounting standards for contingencies to provide for matters that are probable of resulting in an estimable loss. The company believes the claims in the pending actions described below are without merit and intends to defend the matters vigorously. The company is unable at this time to estimate the possible loss or range of loss with respect to these matters. While the outcome of such proceedings is uncertain, management does not believe that their ultimate resolution will have a material adverse effect on the company’s results of operations, financial condition or cash flows.

Tampa Electric Legal Proceedings

A thirty-six year old man died from mesothelioma in March 2014. His estate and his family are suing Tampa Electric as a result. The man allegedly suffered exposure to asbestos dust brought home by his father and grandfather, both of whom had been employed as insulators and worked at various job sites throughout the Tampa area. Plaintiff’s case against Tampa Electric and nineteen other defendants alleges, among other things, negligence, strict liability, household exposure, loss of consortium, and wrongful death.

In September 2014, a man was electrocuted when allegedly two energized, downed primary conductors fell during a heavy storm, leading to his death. Plaintiff's wrongful death complaint against Tampa Electric alleged, among other things, negligence and code violations. In March 2015, Tampa Electric entered into a confidential settlement in connection with this matter.

Peoples Gas Legal Proceedings

In November 2010, heavy equipment operated at a road construction site being conducted by Posen Construction, Inc. struck a natural gas line causing a rupture and ignition of the gas and an outage in the natural gas service to Lee and Collier counties, Florida. PGS filed suit in April 2011 against Posen Construction, Inc. in Federal Court for the Middle District of Florida to recover damages for repair and restoration relating to the incident and Posen Construction, Inc. counter-claimed against PGS alleging negligence. In the first quarter of 2014, the parties entered into a settlement agreement that resolves the claims of the parties. In addition, the suit filed in November 2011 by the Posen Construction, Inc. employee operating the heavy equipment involved in the incident in Lee County Circuit Court against PGS and a PGS contractor involved in the project, seeking damages for his injuries, remains pending.

New Mexico Gas Company Legal Proceedings

In February 2011, NMGC experienced gas shortages due to weather-related interruptions of electric service, weather-related problems on the systems of various interstate pipelines and in gas fields that are the sources of gas supplied to NMGC, and high weather-driven usage. This gas supply disruption and high usage resulted in the declaration of system emergencies by NMGC causing involuntary curtailments of gas utility service to approximately 28,700 customers (residential and business).

In March 2011, a customer purporting to represent a class consisting of all “32,000 [sic] customers” who had their gas utility service curtailed during the early-February system emergencies filed a putative class action lawsuit against NMGC. In March 2011, the Town of Bernalillo, New Mexico, purporting to represent a class consisting of all “New Mexico municipalities and governmental entities who have suffered damages as a result of the natural gas utility shut off” also filed a putative class action lawsuit against NMGC, four of its officers, and John and Jane Does at NMGC. In July 2011, the plaintiff in the Bernalillo class action filed an amended complaint to add an additional plaintiff purporting to represent a class of all “similarly situated New Mexico private businesses and enterprises.”

The two purported class action suits (three purported classes) were consolidated. The court dismissed the class actions in their entirety with prejudice in October 2014 and appeals from the dismissal were taken by the plaintiffs in November 2014 and are pending.

Two lawsuits representing 18 insurance carriers have filed subrogation lawsuits for monies paid to their insureds as a result of the curtailment of natural gas service in February 2011. These subrogation matters are pending and discovery is proceeding. NMGC anticipates filing motions to dismiss similar to those filed in the class actions.

TECO Guatemala Holdings, LLC v. The Republic of Guatemala

On Dec. 19, 2013, the ICSID Tribunal hearing the arbitration claim of TGH, a wholly owned subsidiary of TECO Energy, Inc., against the Republic of Guatemala (Guatemala) under the DR – CAFTA, issued an award in the case (the Award). The ICSID Tribunal unanimously found in favor of TGH and awarded damages to TGH of approximately U.S. $21.1 million, plus interest from Oct. 21, 2010 at a rate equal to the U.S. prime rate plus 2%. In addition, the ICSID Tribunal ruled that Guatemala must reimburse TGH for approximately U.S. $7.5 million of the costs that it incurred in pursuing the arbitration.

On Apr. 18, 2014, Guatemala filed an application for annulment of the entire Award (or, alternatively, certain parts of the Award) pursuant to applicable ICSID rules.

Also on Apr. 18, 2014, TGH separately filed an application for partial annulment of the Award on the basis of certain deficiencies in the ICSID Tribunal’s determination of the amount of TGH’s damages. If TGH’s application is successful, TGH will be able to seek additional damages from Guatemala in a new arbitration proceeding.

While the duration of the annulment proceedings is uncertain, a hearing is scheduled in October 2015 and the proceedings as a whole are expected to take approximately two years to conclude, with a decision by the ad hoc committee in mid- to late-2016. Pending the outcome of annulment proceedings, results to date do not reflect any benefit of this decision.

Superfund and Former Manufactured Gas Plant Sites

TEC, through its Tampa Electric and Peoples Gas divisions, is a PRP for certain superfund sites and, through its Peoples Gas division, for certain former manufactured gas plant sites. While the joint and several liability associated with these sites presents the potential for significant response costs, as of Mar. 31, 2015, TEC has estimated its ultimate financial liability to be $33.3 million, primarily at PGS. This amount has been accrued and is primarily reflected in the long-term liability section under “Other” on the Consolidated Condensed Balance Sheets. The environmental remediation costs associated with these sites, which are expected to be paid over many years, are not expected to have a significant impact on customer rates.

The estimated amounts represent only the portion of the cleanup costs attributable to TEC. The estimates to perform the work are based on TEC’s experience with similar work, adjusted for site-specific conditions and agreements with the respective governmental agencies. The estimates are made in current dollars, are not discounted and do not assume any insurance recoveries.

In instances where other PRPs are involved, most of those PRPs are creditworthy and are likely to continue to be creditworthy for the duration of the remediation work. However, in those instances that they are not, TEC could be liable for more than TEC’s actual percentage of the remediation costs.

Factors that could impact these estimates include the ability of other PRPs to pay their pro-rata portion of the cleanup costs, additional testing and investigation which could expand the scope of the cleanup activities, additional liability that might arise from the cleanup activities themselves or changes in laws or regulations that could require additional remediation. Under current regulations, these costs are recoverable through customer rates established in subsequent base rate proceedings.

Guarantees and Letters of Credit

A summary of the face amount or maximum theoretical obligation and the year of expiration under letters of credit and guarantees as of Mar. 31, 2015 is as follows:

(millions)

Year of expiration

Maximum

After (1)

Theoretical

Liabilities Recognized

Guarantees for the Benefit of:

2015

2016-2019

2019

Obligation

at Mar. 31, 2015 (2)

TECO Energy

Fuel sales and transportation

92.9

Maximum

(millions)

After (1)

Theoretical

Liabilities Recognized

Letters of Credit for the Benefit of:

2015

2016-2019

2019

Obligation

at Mar. 31, 2015 (2)

TEC

0.6

0.1

NMGC

2.3

(1) These letters of credit and guarantees renew annually and are shown on the basis that they will continue to renew beyond 2019.

(2) The amounts shown are the maximum theoretical amounts guaranteed under current agreements. Liabilities recognized represent the associated obligation of TECO Energy, TEC or NMGC under these agreements at Mar. 31, 2015. The obligations under these letters of credit and guarantees include net accounts payable and net derivative liabilities.

Financial Covenants

In order to utilize their respective bank facilities, TECO Energy and its subsidiaries must meet certain financial tests, including a debt to capital ratio, as defined in the applicable agreements. In addition, TECO Energy and its subsidiaries have certain restrictive covenants in specific agreements and debt instruments. At Mar. 31, 2015, TECO Energy and its subsidiaries were in compliance with all applicable financial covenants.

Tampa Electric Company [Member]

Commitments and Contingencies

8. Commitments and Contingencies

Legal Contingencies

From time to time, TEC and its subsidiaries are involved in various legal, tax and regulatory proceedings before various courts, regulatory commissions and governmental agencies in the ordinary course of its business. Where appropriate, accruals are made in accordance with accounting standards for contingencies to provide for matters that are probable of resulting in an estimable loss. The company believes the claims in the pending actions described below are without merit and intends to defend the matters vigorously. The company is unable at this time to estimate the possible loss or range of loss with respect to these matters. While the outcome of such proceedings is uncertain, management does not believe that their ultimate resolution will have a material adverse effect on the company’s results of operations, financial condition or cash flows.

Tampa Electric Legal Proceedings

Peoples Gas Legal Proceedings

Superfund and Former Manufactured Gas Plant Sites

Guarantees and Letters of Credit

A summary of the face amount or maximum theoretical obligation under TEC’s letters of credit as of Mar. 31, 2015 is as follows:

Letters of Credit - Tampa Electric Company

(millions)

After (1)

Liabilities Recognized

Letters of Credit for the Benefit of:

2015

2016-2019

2019

Total

at Mar. 31, 2015

TEC (2)

0.6

0.1

-1

These letters of credit renew annually and are shown on the basis that they will continue to renew beyond 2019.

-2

The amounts shown are the maximum theoretical amounts guaranteed under current agreements. Liabilities recognized represent the associated obligation of TEC under these agreements at Mar. 31, 2015. The obligations under these letters of credit include net accounts payable and net derivative liabilities.

Financial Covenants

In order to utilize its bank credit facilities, TEC must meet certain financial tests, including a debt to capital ratio, as defined in the applicable agreements. In addition, TEC has certain restrictive covenants in specific agreements and debt instruments. At Mar. 31, 2015, TEC was in compliance with all applicable financial covenants.

Segment_Information

Segment Information	3 Months Ended
Segment Information	Mar. 31, 2015
Segment Information
	11. Segment Information
	TECO Energy is an electric and gas utility holding company with diversified activities. Segments are determined based on how management evaluates, measures and makes decisions with respect to the operations of the entity. The management of TECO Energy reports segments based on each subsidiary’s contribution of revenues, net income and total assets as required by the accounting guidance for disclosures about segments of an enterprise and related information. Intercompany transactions are eliminated in the Consolidated Condensed Financial Statements of TECO Energy, but are included in determining reportable segments.


	Segment Information (1)
	(millions)	Tampa		Peoples		New Mexico			TECO									TECO
	Three months ended Mar. 31,	Electric		Gas		Gas Co. (2)			Coal (1)			Other (2)			Eliminations			Energy
	2015
	Revenues - external	$	449.8	$	121.7	$	119		$	0		$	2.5		$	0		$	693
	Sales to affiliates		0.8		1.2		0			0			0			(2.0	)		0
	Total revenues		450.6		122.9		119			0			2.5			(2.0	)		693
	Depreciation and amortization		62.9		13.9		8.4			0			0.3			0			85.5
	Total interest charges		23.5		3.5		3.3			0			17.9			(0.3	)		47.9
	Internally allocated interest		0		0		0			0			0.3			(0.3	)		0
	Provision (benefit) for income taxes		27.4		9.2		9			0			(5.7	)		0			39.9
	Net income (loss) from continuing operations		48.2		14.6		13.9			0			56			(68.9	)		63.8
	Income (loss) from discontinued operations, net (1)		0		0		0			(6.0	)		0.2			0			(5.8	)
	Net income (loss)	$	48.2	$	14.6	$	13.9		$	(6.0	)	$	56.2		$	(68.9	)	$	58
	2014
	Revenues - external	$	452.9	$	122.4	$	0		$	0		$	2.7		$	0		$	578
	Sales to affiliates		0.3		0.2		0			0			0			(0.5	)		0
	Total revenues		453.2		122.6		0			0			2.7			(0.5	)		578
	Depreciation and amortization		62.1		13.3		0			0			0.5			0			75.9
	Total interest charges		22		3.4		0			0			16			(1.8	)		39.6
	Internally allocated interest		0		0		0			0			1.8			(1.8	)		0
	Provision (benefit) for income taxes		26.6		9.2		0			0			(6.7	)		0			29.1
	Net income (loss) from continuing operations		45.2		14.6		0			0			37.5			(48.9	)		48.4
	Income (loss) from discontinued operations, net (1)		0		0		0			(1.6	)		3.3			0			1.7
	Net income (loss)	$	45.2	$	14.6	$	0		$	(1.6	)	$	40.8		$	(48.9	)	$	50.1
	At Mar. 31, 2015
	Total assets	$	6,619.70	$	1,085.50	$	1,207.90		$	209.6		$	5,802.50		$	(6,147.7	)	$	8,777.50
	At Dec. 31, 2014
	Total assets	$	6,565.40	$	1,082.80	$	1,237.20		$	227.7		$	5,664.40		$	(6,051.3	)		8,726.20
	(1) All periods have been adjusted to reflect the reclassification of results from operations to discontinued operations for TECO Coal and certain charges at Parent that directly relate to TECO Coal. See Note 15.
	(2) NMGI is included in the Other segment.


Tampa Electric Company [Member]
Segment Information	9. Segment Information

	(millions)	Tampa		Peoples					Tampa Electric
	Three months ended Mar. 31,	Electric		Gas		Eliminations			Company
	2015
	Revenues - external	$	450.4	$	121.7	$	0		$	572.1
	Sales to affiliates		0.2		1.2		(1.4	)		0
	Total revenues		450.6		122.9		(1.4	)		572.1
	Depreciation and amortization		62.9		13.9		0			76.8
	Total interest charges		23.5		3.5		0			27
	Provision for income taxes		27.4		9.2		0			36.6
	Net income		48.2		14.6		0			62.8
	2014
	Revenues - external	$	453.1	$	122.4	$	0		$	575.5
	Sales to affiliates		0.1		0.2		(0.3	)		0
	Total revenues		453.2		122.6		(0.3	)		575.5
	Depreciation and amortization		62.1		13.3		0			75.4
	Total interest charges		22		3.4		0			25.4
	Provision for income taxes		26.6		9.2		0			35.8
	Net income		45.2		14.6		0		$	59.8
	Total assets at Mar. 31, 2015	$	6,278.70	$	1,050.40	$	(9.0	)	$	7,320.10
	Total assets at Dec. 31, 2014		6,234.40		1,047.00		(7.1	)		7,274.30

Accounting_for_Derivative_Inst

Accounting for Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2015
Accounting for Derivative Instruments and Hedging Activities	12. Accounting for Derivative Instruments and Hedging Activities
	From time to time, TECO Energy and its affiliates enter into futures, forwards, swaps and option contracts for the following purposes:
	·	To limit the exposure to price fluctuations for physical purchases and sales of natural gas in the course of normal operations at Tampa Electric, PGS and NMGC;
	·	To limit the exposure to interest rate fluctuations on debt securities at TECO Energy and its affiliates; and
	·	To limit the exposure to price fluctuations for physical purchases of fuel at TECO Coal (all of which were settled prior to Dec. 31, 2014).
	TECO Energy and its affiliates use derivatives only to reduce normal operating and market risks, not for speculative purposes. The regulated utilities’ primary objective in using derivative instruments for regulated operations is to reduce the impact of market price volatility on ratepayers.
	The risk management policies adopted by TECO Energy provide a framework through which management monitors various risk exposures. Daily and periodic reporting of positions and other relevant metrics are performed by a centralized risk management group, which is independent of all operating companies.
	The company applies the accounting standards for derivative instruments and hedging activities. These standards require companies to recognize derivatives as either assets or liabilities in the financial statements, to measure those instruments at fair value and to reflect the changes in the fair value of those instruments as either components of OCI or in net income, depending on the designation of those instruments (see Note 13). The changes in fair value that are recorded in OCI are not immediately recognized in current net income. As the underlying hedged transaction matures or the physical commodity is delivered, the deferred gain or loss on the related hedging instrument must be reclassified from OCI to earnings based on its value at the time of the instrument’s settlement. For effective hedge transactions, the amount reclassified from OCI to earnings is offset in net income by the market change of the amount paid or received on the underlying physical transaction.
	The company applies the accounting standards for regulated operations to financial instruments used to hedge the purchase of natural gas for its regulated companies. These standards, in accordance with the FPSC and NMPRC, permit the changes in fair value of natural gas derivatives to be recorded as regulatory assets or liabilities reflecting the impact of hedging activities on the fuel recovery clause. As a result, these changes are not recorded in OCI (see Note 3).
	The company’s physical contracts qualify for the NPNS exception to derivative accounting rules, provided they meet certain criteria. Generally, NPNS applies if the company deems the counterparty creditworthy, if the counterparty owns or controls resources within the proximity to allow for physical delivery of the commodity, if the company intends to receive physical delivery and if the transaction is reasonable in relation to the company’s business needs. As of Mar. 31, 2015, all of the company’s physical contracts qualify for the NPNS exception.
	The derivatives that are designated as cash flow hedges at Mar. 31, 2015 and Dec. 31, 2014 are reflected on the company’s Consolidated Condensed Balance Sheets and classified accordingly as current and long-term assets and liabilities on a net basis as permitted by their respective master netting agreements. Derivative assets totaled $0.3 million and $0 as of Mar. 31, 2015 and Dec. 31, 2014, respectively, and derivative liabilities totaled $40.8 million and $42.7 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively. There are minor offset amount differences between the gross derivative assets and liabilities and the net amounts presented on the Consolidated Condensed Balance Sheets. There was no cash collateral posted with or received from any counterparties.
	All of the derivative assets and liabilities at Mar. 31, 2015 and Dec. 31, 2014 are designated as hedging instruments, which primarily are derivative hedges of natural gas contracts to limit the exposure to changes in market price for natural gas used to produce energy and natural gas purchased for resale to customers. The corresponding effect of these natural gas related derivatives on the regulated utilities’ fuel recovery clause mechanism is reflected on the Consolidated Condensed Balance Sheets as current and long-term regulatory assets and liabilities. Based on the fair value of the instruments at Mar. 31, 2015, net pretax losses of $35.2 million are expected to be reclassified from regulatory assets or liabilities to the Consolidated Condensed Statements of Income within the next twelve months.
	The Mar. 31, 2015 and Dec. 31, 2014 balance in AOCI related to the cash flow hedges and interest rate swaps (unsettled and previously settled) is presented in Note 8.
	For derivative instruments that meet cash flow hedge criteria, the effective portion of the gain or loss on the derivative is reported as a component of OCI and reclassified into earnings in the same period or period during which the hedged transaction affects earnings. Gains and losses on the derivatives representing either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in current earnings. For the three months ended Mar. 31, 2015 and 2014, all hedges were effective. The derivative after-tax effect on OCI and the amount of after-tax gain or loss reclassified from AOCI into earnings for the three months ended Mar. 31, 2015 and 2014 is presented in Note 8. These gains and losses were the result of interest rate contracts for TEC and diesel fuel derivatives related to TECO Coal operations. The locations of the reclassifications to income were reflected in Interest expense for TEC and Income (loss) from discontinued operations for TECO Coal.
	The maximum length of time over which the company is hedging its exposure to the variability in future cash flows extends to Mar. 31, 2017 for financial natural gas contracts. The following table presents the company’s derivative volumes that, as of Mar. 31, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years:

	Derivative Volumes	Natural Gas Contracts
	(millions)	(MMBTUs)
	Year	Physical		Financial
	2015		0		29.8
	2016		0		9.6
	2017		0		0.9
	Total		0		40.3
	The company is exposed to credit risk primarily through entering into derivative instruments with counterparties to limit its exposure to the commodity price fluctuations associated with natural gas. Credit risk is the potential loss resulting from a counterparty’s nonperformance under an agreement. The company manages credit risk with policies and procedures for, among other things, counterparty analysis, exposure measurement and exposure monitoring and mitigation.
	It is possible that volatility in commodity prices could cause the company to have material credit risk exposures with one or more counterparties. If such counterparties fail to perform their obligations under one or more agreements, the company could suffer a material financial loss. However, as of Mar. 31, 2015, substantially all of the counterparties with transaction amounts outstanding in the company’s energy portfolio were rated investment grade by the major rating agencies. The company assesses credit risk internally for counterparties that are not rated.
	The company has entered into commodity master arrangements with its counterparties to mitigate credit exposure to those counterparties. The company generally enters into the following master arrangements: (1) EEI agreements—standardized power sales contracts in the electric industry; (2) ISDA agreements—standardized financial gas and electric contracts; and (3) NAESB agreements—standardized physical gas contracts. The company believes that entering into such agreements reduces the risk from default by creating contractual rights relating to creditworthiness, collateral and termination.
	The company has implemented procedures to monitor the creditworthiness of its counterparties and to consider nonperformance risk in determining the fair value of counterparty positions. Net liability positions generally do not require a nonperformance risk adjustment as the company uses derivative transactions as hedges and has the ability and intent to perform under each of these contracts. In the instance of net asset positions, the company considers general market conditions and the observable financial health and outlook of specific counterparties in evaluating the potential impact of nonperformance risk to derivative positions.
	Certain TECO Energy derivative instruments contain provisions that require the company’s debt, or in the case of derivative instruments where TEC is the counterparty, TEC’s debt, to maintain an investment grade credit rating from any or all of the major credit rating agencies. If debt ratings, including TEC’s, were to fall below investment grade, it could trigger these provisions, and the counterparties to the derivative instruments could demand immediate and ongoing full overnight collateralization on derivative instruments in net liability positions. The company has no other contingent risk features associated with any derivative instruments.
Tampa Electric Company [Member]
Accounting for Derivative Instruments and Hedging Activities	10. Accounting for Derivative Instruments and Hedging Activities
	From time to time, TEC enters into futures, forwards, swaps and option contracts for the following purposes:
	·	To limit the exposure to price fluctuations for physical purchases and sales of natural gas in the course of normal operations, and
	·	To limit the exposure to interest rate fluctuations on debt securities.
	TEC uses derivatives only to reduce normal operating and market risks, not for speculative purposes. TEC’s primary objective in using derivative instruments for regulated operations is to reduce the impact of market price volatility on ratepayers.
	The risk management policies adopted by TEC provide a framework through which management monitors various risk exposures. Daily and periodic reporting of positions and other relevant metrics are performed by a centralized risk management group, which is independent of all operating companies.
	TEC applies the accounting standards for derivative instruments and hedging activities. These standards require companies to recognize derivatives as either assets or liabilities in the financial statements, to measure those instruments at fair value and to reflect the changes in the fair value of those instruments as either components of OCI or in net income, depending on the designation of those instruments (see Note 11). The changes in fair value that are recorded in OCI are not immediately recognized in current net income. As the underlying hedged transaction matures or the physical commodity is delivered, the deferred gain or loss on the related hedging instrument must be reclassified from OCI to earnings based on its value at the time of the instrument’s settlement. For effective hedge transactions, the amount reclassified from OCI to earnings is offset in net income by the market change of the amount paid or received on the underlying physical transaction.
	TEC applies the accounting standards for regulated operations to financial instruments used to hedge the purchase of natural gas for its regulated companies. These standards, in accordance with the FPSC, permit the changes in fair value of natural gas derivatives to be recorded as regulatory assets or liabilities reflecting the impact of hedging activities on the fuel recovery clause. As a result, these changes are not recorded in OCI (see Note 3).
	TEC’s physical contracts qualify for the NPNS exception to derivative accounting rules, provided they meet certain criteria. Generally, NPNS applies if TEC deems the counterparty creditworthy, if the counterparty owns or controls resources within the proximity to allow for physical delivery of the commodity, if TEC intends to receive physical delivery and if the transaction is reasonable in relation to TEC’s business needs. As of Mar. 31, 2015, all of TEC’s physical contracts qualify for the NPNS exception.
	The derivatives that are designated as cash flow hedges at Mar. 31, 2015 and Dec. 31, 2014 are reflected on TEC’s Consolidated Condensed Balance Sheets and classified accordingly as current and long-term assets and liabilities on a net basis as permitted by their respective master netting agreements. Derivative assets totaled $0.3 million and $0 as of Mar. 31, 2015 and Dec. 31, 2014, respectively, and derivative liabilities totaled $40.8 million and $42.7 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively. There are minor offset amount differences between the gross derivative assets and liabilities and the net amounts presented on the Consolidated Condensed Balance Sheets. There was no cash collateral posted with or received from any counterparties.
	All of the derivative assets and liabilities at Mar. 31, 2015 and Dec. 31, 2014 are designated as hedging instruments, which primarily are derivative hedges of natural gas contracts to limit the exposure to changes in market price for natural gas used to produce energy and natural gas purchased for resale to customers. The corresponding effect of these natural gas related derivatives on the regulated utilities’ fuel recovery clause mechanism is reflected on the Consolidated Condensed Balance Sheets as current and long-term regulatory assets and liabilities. Based on the fair value of the instruments at Mar. 31, 2015, net pretax losses of $35.2 million are expected to be reclassified from regulatory assets or liabilities to the Consolidated Condensed Statements of Income within the next twelve months.
	The Mar. 31, 2015 and Dec. 31, 2014 balance in AOCI related to the cash flow hedges and interest rate swaps (unsettled and previously settled) is presented in Note 12.
	For derivative instruments that meet cash flow hedge criteria, the effective portion of the gain or loss on the derivative is reported as a component of OCI and reclassified into earnings in the same period or period during which the hedged transaction affects earnings. Gains and losses on the derivatives representing either hedge ineffectiveness or hedge components excluded from the assessment of effectiveness are recognized in current earnings. For the three months ended Mar. 31, 2015 and 2014, all hedges were effective. The derivative after-tax effect on OCI and the amount of after-tax gain or loss reclassified from AOCI into earnings for the three months ended Mar. 31, 2015 and 2014 is presented in Note 12. Gains and losses were the result of interest rate contracts and the reclassifications to income were reflected in Interest expense.
	The maximum length of time over which TEC is hedging its exposure to the variability in future cash flows extends to Mar. 31, 2017 for financial natural gas contracts. The following table presents TEC’s derivative volumes that, as of Mar. 31, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years:

		Natural Gas Contracts
	(millions)	(MMBTUs)
	Year	Physical		Financial
	2015		0		29.8
	2016		0		9.6
	2017		0		0.9
	Total		0		40.3
	TEC is exposed to credit risk primarily through entering into derivative instruments with counterparties to limit its exposure to the commodity price fluctuations associated with natural gas. Credit risk is the potential loss resulting from a counterparty’s nonperformance under an agreement. TEC manages credit risk with policies and procedures for, among other things, counterparty analysis, exposure measurement and exposure monitoring and mitigation.
	It is possible that volatility in commodity prices could cause TEC to have material credit risk exposures with one or more counterparties. If such counterparties fail to perform their obligations under one or more agreements, TEC could suffer a material financial loss. However, as of Mar. 31, 2015, substantially all of the counterparties with transaction amounts outstanding in TEC’s energy portfolio were rated investment grade by the major rating agencies. TEC assesses credit risk internally for counterparties that are not rated.
	TEC has entered into commodity master arrangements with its counterparties to mitigate credit exposure to those counterparties. TEC generally enters into the following master arrangements: (1) EEI agreements—standardized power sales contracts in the electric industry; (2) ISDA agreements—standardized financial gas and electric contracts; and (3) NAESB agreements—standardized physical gas contracts. TEC believes that entering into such agreements reduces the risk from default by creating contractual rights relating to creditworthiness, collateral and termination.
	TEC has implemented procedures to monitor the creditworthiness of its counterparties and to consider nonperformance risk in determining the fair value of counterparty positions. Net liability positions generally do not require a nonperformance risk adjustment as TEC uses derivative transactions as hedges and has the ability and intent to perform under each of these contracts. In the instance of net asset positions, TEC considers general market conditions and the observable financial health and outlook of specific counterparties in evaluating the potential impact of nonperformance risk to derivative positions.
	Certain TEC derivative instruments contain provisions that require TEC’s debt to maintain an investment grade credit rating from any or all of the major credit rating agencies. If debt ratings were to fall below investment grade, it could trigger these provisions, and the counterparties to the derivative instruments could demand immediate and ongoing full overnight collateralization on derivative instruments in net liability positions. TEC has no other contingent risk features associated with any derivative instruments.

Fair_Value_Measurements

Fair Value Measurements

3 Months Ended

Mar. 31, 2015

Fair Value Measurements

13. Fair Value Measurements

Items Measured at Fair Value on a Recurring Basis

Accounting guidance governing fair value measurements and disclosures provides that fair value represents the amount that would be received in selling an asset or the amount that would be paid in transferring a liability in an orderly transaction between market participants. As such, fair value is a market-based measurement that is determined based upon assumptions that market participants would use in pricing an asset or liability. As a basis for considering such assumptions, accounting guidance also establishes a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value as follows:

Level 1: Observable inputs, such as quoted prices in active markets;

Level 2: Inputs, other than quoted prices in active markets, that are observable either directly or indirectly; and

Level 3: Unobservable inputs for which there is little or no market data, which require the reporting entity to develop its own assumptions.

Assets and liabilities are measured at fair value based on one or more of the following three valuation techniques noted under accounting guidance:

(A) Market approach: Prices and other relevant information generated by market transactions involving

identical or comparable assets or liabilities;

(B) Cost approach: Amount that would be required to replace the service capacity of an asset (replacement

cost); and

expectations (including present value techniques, option-pricing and excess earnings models).

The fair value of financial instruments is determined by using various market data and other valuation techniques.

The following tables set forth by level within the fair value hierarchy, the company’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of Mar. 31, 2015 and Dec. 31, 2014. As required by accounting standards for fair value measurements, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The company’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

Recurring Fair Value Measures

As of Mar. 31, 2015

(millions)

Level 1

Level 2

Level 3

Total

Assets

Interest rate swaps

0.3

Liabilities

Natural gas swaps

40.8

As of Dec. 31, 2014

(millions)

Level 1

Level 2

Level 3

Total

Liabilities

Natural gas swaps

42.7

Natural gas swaps are OTC swap instruments. The market approach is used in determining the fair value of natural gas swaps and the primary pricing inputs are the NYMEX quoted closing prices of exchange-traded instruments. These prices are applied to the notional amounts of active positions to determine the reported fair value (see Note 12).

Interest rate swaps are also OTC swap instruments. The income approach is used in determining the fair value of interest rate swaps and the primary pricing inputs are LIBOR swap rates. For each instrument, the projected forward swap rate is used to determine the stream of cash flows over the life of the contract. The cash flows are then discounted using a spot discount rate to determine fair value.

The company considered the impact of nonperformance risk in determining the fair value of derivatives. The company considered the net position with each counterparty, past performance of both parties, the intent of the parties, indications of credit deterioration and whether the markets in which the company transacts have experienced dislocation. At Mar. 31, 2015, the fair value of derivatives was not materially affected by nonperformance risk. There were no Level 3 assets or liabilities for the periods presented.

Tampa Electric Company [Member]

Fair Value Measurements

11. Fair Value Measurements

Items Measured at Fair Value on a Recurring Basis

Level 1: Observable inputs, such as quoted prices in active markets;

Level 2: Inputs, other than quoted prices in active markets, that are observable either directly or indirectly; and

Level 3: Unobservable inputs for which there is little or no market data, which require the reporting entity to develop its own assumptions.

Assets and liabilities are measured at fair value based on one or more of the following three valuation techniques noted under accounting guidance:

(A) Market approach: Prices and other relevant information generated by market transactions involving

identical or comparable assets or liabilities;

(B) Cost approach: Amount that would be required to replace the service capacity of an asset (replacement

cost); and

expectations (including present value techniques, option-pricing and excess earnings models).

The fair value of financial instruments is determined by using various market data and other valuation techniques.

The following tables set forth by level within the fair value hierarchy, TEC’s financial assets and liabilities that were accounted for at fair value on a recurring basis as of Mar. 31, 2015 and Dec. 31, 2014. As required by accounting standards for fair value measurements, financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. TEC’s assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of fair value assets and liabilities and their placement within the fair value hierarchy levels.

Recurring Derivative Fair Value Measures

As of Mar. 31, 2015

(millions)

Level 1

Level 2

Level 3

Total

Assets

Interest rate swaps

0.3

Liabilities

Natural gas swaps

40.8

As of Dec. 31, 2014

(millions)

Level 1

Level 2

Level 3

Total

Liabilities

Natural gas swaps

42.7

TEC considered the impact of nonperformance risk in determining the fair value of derivatives. TEC considered the net position with each counterparty, past performance of both parties, the intent of the parties, indications of credit deterioration and whether the markets in which TEC transacts have experienced dislocation. At Mar. 31, 2015, the fair value of derivatives was not materially affected by nonperformance risk. There were no Level 3 assets or liabilities for the periods presented.

Variable_Interest_Entities

Variable Interest Entities	3 Months Ended
Variable Interest Entities	Mar. 31, 2015
Variable Interest Entities	14. Variable Interest Entities
	In the determination of a VIE’s primary beneficiary, the primary beneficiary is the enterprise that has both 1) the power to direct the activities of a VIE that most significantly impact the entity’s economic performance and 2) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE.
	TEC has entered into multiple PPAs with wholesale energy providers in Florida to ensure the ability to meet customer energy demand and to provide lower cost options in the meeting of this demand. These agreements range in size from 117 MW to 160 MW of available capacity, are with similar entities and contain similar provisions. Because some of these provisions provide for the transfer or sharing of a number of risks inherent in the generation of energy, these agreements meet the definition of being variable interests. These risks include: operating and maintenance, regulatory, credit, commodity/fuel and energy market risk. TEC has reviewed these risks and has determined that the owners of these entities have retained the majority of these risks over the expected life of the underlying generating assets, have the power to direct the most significant activities, and have the obligation or right to absorb losses or benefits and hence remain the primary beneficiaries. As a result, TEC is not required to consolidate any of these entities. TEC purchased $5.4 million and $5.9 million of capacity pursuant to PPAs for the three months ended Mar. 31, 2015 and 2014, respectively.
	The company does not provide any material financial or other support to any of the VIEs it is involved with, nor is the company under any obligation to absorb losses associated with these VIEs. In the normal course of business, the company’s involvement with these VIEs does not affect its Consolidated Condensed Balance Sheets, Statements of Income or Cash Flows.
Tampa Electric Company [Member]
Variable Interest Entities	13. Variable Interest Entities
	In the determination of a VIE’s primary beneficiary, the primary beneficiary is the enterprise that has both 1) the power to direct the activities of a VIE that most significantly impact the entity’s economic performance and 2) the obligation to absorb losses of the entity that could potentially be significant to the VIE or the right to receive benefits from the entity that could potentially be significant to the VIE.
	TEC has entered into multiple PPAs with wholesale energy providers in Florida to ensure the ability to meet customer energy demand and to provide lower cost options in the meeting of this demand. These agreements range in size from 117 MW to 160 MW of available capacity, are with similar entities and contain similar provisions. Because some of these provisions provide for the transfer or sharing of a number of risks inherent in the generation of energy, these agreements meet the definition of being variable interests. These risks include: operating and maintenance, regulatory, credit, commodity/fuel and energy market risk. TEC has reviewed these risks and has determined that the owners of these entities have retained the majority of these risks over the expected life of the underlying generating assets, have the power to direct the most significant activities, and have the obligation or right to absorb losses or benefits and hence remain the primary beneficiaries. As a result, TEC is not required to consolidate any of these entities. TEC purchased $5.4 million and $5.9 million of capacity pursuant to PPAs for the three months ended Mar. 31, 2015 and 2014, respectively.
	TEC does not provide any material financial or other support to any of the VIEs it is involved with, nor is TEC under any obligation to absorb losses associated with these VIEs. In the normal course of business, TEC’s involvement with these VIEs does not affect its Consolidated Condensed Balance Sheets, Statements of Income or Cash Flows.

Discontinued_Operations_Assets

Discontinued Operations, Assets Held for Sale and Asset Impairments	3 Months Ended
	Mar. 31, 2015
Discontinued Operations And Disposal Groups [Abstract]
Discontinued Operations, Assets Held for Sale and Asset Impairments	15. Discontinued Operations, Assets Held for Sale and Asset Impairments
	TECO Coal
	In September 2014, the Board of Directors of TECO Energy authorized management to enter into negotiations for the sale of TECO Coal. As a result of this and other factors, the TECO Coal segment was accounted for as an asset held for sale and reported as a discontinued operation beginning in the third quarter of 2014.
	On Oct. 17, 2014, TECO Diversified entered into an SPA to sell all of its ownership interest in TECO Coal to Cambrian Coal Corporation (“Cambrian”). On Feb. 5, 2015, the SPA was amended to extend the closing date to Mar. 13, 2015 and modify the purchase price to $80 million, subject to working capital adjustments, plus contingent payments of up to $60 million that may be paid between 2015 and 2019 depending on specified coal benchmark prices. As a result, in 2014 the company recorded impairment charges totaling $115.9 million pretax to write down the held-for-sale TECO Coal assets to their implied fair value based on the binding offer less estimated costs to sell. On Mar. 12, 2015, the SPA was further amended to extend the closing date to Apr. 24, 2015. On Apr. 17, 2015, the SPA was amended again to further extend the closing date to June 5, 2015, in order to allow for Cambrian’s financing arrangements to be completed (see Note 16). No additional asset impairments were recorded in the first quarter of 2015.
	The SPA contains customary representations, warranties, covenants, and closing conditions, including the purchaser’s obtaining debt financing in order to pay a portion of the purchase prices. The SPA also contains indemnification provisions subject to specified limitations as to time and amount. In addition, the SPA, as amended, is subject to termination by either party if specified closing conditions are not met by June 5, 2015. After closing of the sale, TECO Energy will not have influence over operations of TECO Coal, therefore the contingent payments and indemnification provisions are not considered to meet the definition of direct cash flows under the applicable discontinued operations FASB guidance.
	All periods have been adjusted to reflect the reclassification of results from operations to discontinued operations for TECO Coal and certain charges at Parent that directly relate to the sale of TECO Coal.

	The following table provides a summary of the carrying amounts of the significant assets and liabilities reported in the combined current and non-current “Assets held for sale” and “Liabilities associated with assets held for sale” line items:

	Assets held for sale
	(millions)	Mar. 31, 2015			Dec. 31, 2014
	Current assets (1)	$	97.1		$	109.6
	Property, plant and equipment, net and other long-term assets		60.9			59.8
	Total assets held for sale	$	158		$	169.4

	Liabilities associated with assets held for sale
	(millions)	Mar. 31, 2015			Dec. 31, 2014
	Current liabilities	$	33.7		$	39.4
	Long-term liabilities		65.7			65.4
	Total liabilities associated with assets held for sale	$	99.4		$	104.8
	-1	Certain items within Current assets are excluded from the SPA working capital adjustments.
	TECO Guatemala
	In 2012, TECO Guatemala completed the sale of its interests in the Alborada and San José power stations, and related solid fuel handling and port facilities in Guatemala. All periods presented reflect the classification of results from operations for TECO Guatemala and certain charges at Parent that directly relate to TECO Guatemala as discontinued operations. While TECO Energy and its subsidiaries no longer have assets or operations in Guatemala, its subsidiary, TECO Guatemala Holdings, LLC, has retained its rights under its arbitration claim filed against the Republic of Guatemala (see Note 10). The first quarter 2015 charges shown in the table below are legal costs associated with that claim. Additionally, in March 2014, an indemnification provision for an uncertain tax position at TCAE that was provided for in the 2012 purchase agreement was reversed due to a favorable final decision by the highest court in Guatemala, resulting in the income from operations amount shown in the table below.
	Combined Components of Discontinued Operations
	The following table provides selected components of discontinued operations related to the sales of TECO Coal and TECO Guatemala:

	Components of income from discontinued operations	Three months ended
		Mar. 31,
	(millions)	2015			2014
	Revenues—TECO Coal	$	72.7		$	106.1
	Loss from operations—TECO Coal		(9.5	)		(3.8	)
	Income (loss) from operations—TECO Guatemala		(0.1	)		5
	Loss from discontinued operations—TECO Coal		(9.5	)		(3.8	)
	Income (loss) from discontinued operations—TECO Guatemala		(0.1	)		5
	Income (loss) from discontinued operations		(9.6	)		1.2
	Benefit for income taxes		(3.8	)		(0.5	)
	Income (loss) from discontinued operations, net	$	(5.8	)	$	1.7

Subsequent_Events

Subsequent Events	3 Months Ended
Subsequent Events	Mar. 31, 2015
Subsequent Events [Abstract]
Subsequent Events	16. Subsequent Events
	Issuance of TECO Finance Floating Rate Notes due 2018
	On Apr. 10, 2015, TECO Finance completed an offering of $250 million aggregate principal amount of floating rate notes due 2018 (the 2018 Notes), which are guaranteed by TECO Energy. The 2018 Notes were sold at par and mature on Apr. 10, 2018. The 2018 Notes will bear interest at a floating rate that is reset quarterly based on the three-month LIBOR plus 60 basis points, which is payable quarterly on Jan. 10, Apr. 10, July 10 and Oct. 10 of each year, beginning July 10, 2015. Interest on the 2018 Notes will be computed on the basis of the actual number of days elapsed over a 360-day year. The 2018 Notes will not be subject to redemption prior to maturity. The 2018 Notes are effectively subordinated to existing and future liabilities of TECO Energy’s subsidiaries to their respective creditors, and also are effectively subordinated to any secured debt that TECO Finance and TECO Energy incur to the extent of the value of the assets securing that indebtedness. TECO Finance is a wholly owned subsidiary of TECO Energy whose business activities consist solely of providing funds to TECO Energy.
	The offering resulted in net proceeds to TECO Finance (after deducting underwriting discounts and commissions and estimated offering expenses) of approximately $248.6 million. TECO Finance will use these net proceeds to repay borrowings under the TECO Finance credit facility and to fund a portion of the redemption of $191 million of TECO Finance notes due in May 2015.
	Amendment to TECO Coal SPA
	On Apr. 17, 2015, TECO Diversified entered into an amendment (the Amendment) to the SPA dated as of Oct. 17, 2014, as amended, with Cambrian. As disclosed in Note 15, the SPA related to the sale of all of the ownership interest in TECO Coal to Cambrian, and was subject to termination by either party if specified closing conditions, including the purchaser’s obtaining financing in order to pay a portion of the purchase price, were not met by Apr. 24, 2015. The Amendment extends this date and provides that the SPA, as amended, is subject to termination by either party if the specified closing conditions are not met by June 5, 2015.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	3 Months Ended
Summary of Significant Accounting Policies (Policies)	Mar. 31, 2015
Principles of Consolidation and Basis of Presentation	Principles of Consolidation and Basis of Presentation
	Intercompany balances and intercompany transactions have been eliminated in consolidation. In the opinion of management, the unaudited consolidated condensed financial statements include all adjustments that are of a recurring nature and necessary to state fairly the financial position of TECO Energy, Inc. and its subsidiaries as of Mar. 31, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended Mar. 31, 2015 and 2014. The results of operations for the three months ended Mar. 31, 2015 are not necessarily indicative of the results that can be expected for the entire fiscal year ending Dec. 31, 2015.
	The consolidated financial statements include NMGI and NMGC from the acquisition date of Sept. 2, 2014 through Mar. 31, 2015. In addition, all periods have been adjusted to reflect the reclassification of results from operations to discontinued operations for TECO Coal and certain charges at Parent that directly related to TECO Coal (see Note 15).
	The use of estimates is inherent in the preparation of financial statements in accordance with U.S. GAAP. Actual results could differ from these estimates. The year-end consolidated condensed balance sheet data was derived from audited financial statements; however, this quarterly report on Form 10-Q does not include all year-end disclosures required for an annual report on Form 10-K by U.S. GAAP.
Revenues	Revenues
Revenues	As of Mar. 31, 2015 and Dec. 31, 2014, unbilled revenues of $63.8 million and $86.6 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets.
Accounting for Excise Taxes, Franchise Fees and Gross Receipts	Accounting for Excise Taxes, Franchise Fees and Gross Receipts
	TECO Coal incurs most of TECO Energy’s total excise taxes, which are accrued as an expense and reconciled to the actual cash payment of excise taxes. As general expenses, they are not specifically recovered through revenues. Excise taxes paid by the regulated utilities are not material and are expensed when incurred.
	Tampa Electric and PGS are allowed to recover certain costs from customers on a dollar-per-dollar basis through prices approved by the FPSC. The amounts included in customers’ bills for franchise fees and gross receipt taxes are included as revenues on the Consolidated Condensed Statements of Income. Franchise fees and gross receipt taxes payable by Tampa Electric and PGS are included as an expense on the Consolidated Condensed Statements of Income in “Taxes, other than income”. These amounts totaled $27.4 million and $27.2 million for the three months ended Mar. 31, 2015 and 2014, respectively.
	NMGC is an agent in the collection and payment of franchise fees and gross receipt taxes and is not required by a tariff to present the amounts on a gross basis. Therefore, NMGC’s franchise fees and gross receipt taxes are presented net with no line-item impact on the Consolidated Condensed Statements of Income.
Tampa Electric Company [Member]
Principles of Consolidation and Basis of Presentation	Principles of Consolidation and Basis of Presentation
	TEC is a wholly owned subsidiary of TECO Energy, Inc. For the purposes of its consolidated financial reporting, TEC is comprised of the electric division, generally referred to as Tampa Electric, the natural gas division, generally referred to as PGS, and potentially the accounts of VIEs for which it is the primary beneficiary. For the periods presented, no VIEs have been consolidated (see Note 13).
	Intercompany balances and intercompany transactions have been eliminated in consolidation. In the opinion of management, the unaudited consolidated condensed financial statements include all adjustments that are of a recurring nature and necessary to state fairly the financial position of TEC as of Mar. 31, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended Mar. 31, 2015 and 2014. The results of operations for the three months ended Mar. 31, 2015 are not necessarily indicative of the results that can be expected for the entire fiscal year ending Dec. 31, 2015.
	The use of estimates is inherent in the preparation of financial statements in accordance with U.S. GAAP. Actual results could differ from these estimates. The year-end consolidated condensed balance sheet data was derived from audited financial statements; however, this quarterly report on Form 10-Q does not include all year-end disclosures required for an annual report on Form 10-K by U.S. GAAP.
Revenues	Revenues
Revenues	As of Mar. 31, 2015 and Dec. 31, 2014, unbilled revenues of $52.5 million and $49.3 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets.
Accounting for Excise Taxes, Franchise Fees and Gross Receipts	Accounting for Excise Taxes, Franchise Fees and Gross Receipts
	Tampa Electric and PGS are allowed to recover certain costs from customers on a dollar-per-dollar basis through prices approved by the FPSC. The amounts included in customers’ bills for franchise fees and gross receipt taxes are included as revenues on the Consolidated Condensed Statements of Income. Franchise fees and gross receipt taxes payable by Tampa Electric and PGS are included as an expense on the Consolidated Condensed Statements of Income in “Taxes, other than income”. These amounts totaled $27.4 million and $27.2 million for the three months ended Mar. 31, 2015 and 2014, respectively.

Regulatory_Tables

Regulatory (Tables)	3 Months Ended
Regulatory (Tables)	Mar. 31, 2015
Schedule of Regulatory Assets and Regulatory Liabilities	Details of the regulatory assets and liabilities as of Mar. 31, 2015 and Dec. 31, 2014 are presented in the following table:

	Regulatory Assets and Liabilities
	(millions)	Mar. 31, 2015		Dec. 31, 2014
	Regulatory assets:
	Regulatory tax asset (1)	$	70.5	$	69.2
	Other:
	Cost-recovery clauses		42.8		45.1
	Postretirement benefit asset (2)		195.6		194
	Deferred bond refinancing costs (3)		7		7.2
	Debt basis adjustment (3)		20.1		20.9
	Environmental remediation		53.4		53.1
	Competitive rate adjustment		2.6		2.8
	Other		10		9.8
	Total other regulatory assets		331.5		332.9
	Total regulatory assets		402		402.1
	Less: Current portion		52		53.6
	Long-term regulatory assets	$	350	$	348.5
	Regulatory liabilities:
	Regulatory tax liability (1)	$	6.6	$	6.9
	Other:
	Cost-recovery clauses		19.4		25.9
	Transmission and delivery storm reserve		56.1		56.1
	Deferred gain on property sales (4)		0.5		0.8
	Accumulated reserve - cost of removal		686		695.2
	Other		0.8		1.1
	Total other regulatory liabilities		762.8		779.1
	Total regulatory liabilities		769.4		786
	Less: Current portion		49.4		57
	Long-term regulatory liabilities	$	720	$	729
	-1	Primarily related to plant life and derivative positions.
	-2	Amortized over remaining service life of plan participants.
	-3	Amortized over the term of the related debt instruments.
	-4	Amortized over a 5-year period with various ending dates.
Regulatory Assets and Related Recovery Period	All regulatory assets are recovered through the regulatory process. The following table further details the regulatory assets and the related recovery periods:

	Regulatory Assets
		Mar. 31,		Dec. 31,
	(millions)	2015		2014
	Clause recoverable (1)	$	45.4	$	47.9
	Components of rate base (2)		200.7		199
	Regulatory tax assets (3)		70.5		69.2
	Capital structure and other (3)		85.4		86
	Total	$	402	$	402.1
	-1	To be recovered through cost-recovery mechanisms approved by the FPSC or NMPRC, as applicable, on a dollar-for-dollar basis in the next year.
	-2	Primarily reflects allowed working capital, which is included in rate base and earns a rate of return as permitted by the FPSC.
	-3	“Regulatory tax assets” and “Capital structure and other” regulatory assets, including environmental remediation, have a recoverable period longer than a fiscal year and are recognized over the period authorized by the regulatory agency. Also included are unamortized loan costs, which are amortized over the life of the related debt instruments. See footnotes 1 and 2 in the prior table for additional information.
Tampa Electric Company [Member]
Schedule of Regulatory Assets and Regulatory Liabilities	Details of the regulatory assets and liabilities as of Mar. 31, 2015 and Dec. 31, 2014 are presented in the following table:

	Regulatory Assets and Liabilities
	(millions)	Mar. 31, 2015		Dec. 31, 2014
	Regulatory assets:
	Regulatory tax asset (1)	$	70.5	$	69.2
	Other:
	Cost-recovery clauses		42.4		43.6
	Postretirement benefit asset (2)		189.7		187.8
	Deferred bond refinancing costs (3)		7		7.2
	Environmental remediation		53.4		53.1
	Competitive rate adjustment		2.6		2.8
	Other		8.3		8
	Total other regulatory assets		303.4		302.5
	Total regulatory assets		373.9		371.7
	Less: Current portion		51.6		52.1
	Long-term regulatory assets	$	322.3	$	319.6
	Regulatory liabilities:
	Regulatory tax liability (1)	$	4.9	$	5.1
	Other:
	Cost-recovery clauses		18.8		23.5
	Transmission and delivery storm reserve		56.1		56.1
	Deferred gain on property sales (4)		0.5		0.8
	Accumulated reserve - cost of removal		580.7		591.5
	Provision for stipulation and other		0.7		1.1
	Total other regulatory liabilities		656.8		673
	Total regulatory liabilities		661.7		678.1
	Less: Current portion		48.8		54.7
	Long-term regulatory liabilities	$	612.9	$	623.4
	-1	Primarily related to plant life and derivative positions.
	-2	Amortized over the remaining service life of plan participants.
	-3	Amortized over the term of the related debt instruments.
	-4	Amortized over a 5-year period with various ending dates.
Regulatory Assets and Related Recovery Period	All regulatory assets are recovered through the regulatory process. The following table further details the regulatory assets and the related recovery periods:

	Regulatory Assets
		Mar. 31,		Dec. 31,
	(millions)	2015		2014
	Clause recoverable (1)	$	45	$	46.4
	Components of rate base (2)		193		191
	Regulatory tax assets (3)		70.5		69.2
	Capital structure and other (3)		65.4		65.1
	Total	$	373.9	$	371.7
	-1	To be recovered through cost-recovery mechanisms approved by the FPSC on a dollar-for-dollar basis in the next year.
	-2	Primarily reflects allowed working capital, which is included in rate base and earns a rate of return as permitted by the FPSC.
	-3	“Regulatory tax assets” and “Capital structure and other” regulatory assets, including environmental remediation, have a recoverable period longer than a fiscal year and are recognized over the period authorized by the regulatory agency. Also included are unamortized loan costs, which are amortized over the life of the related debt instruments. See footnotes 1 and 2 in the prior table for additional information.

Employee_Postretirement_Benefi1

Employee Postretirement Benefits (Tables)	3 Months Ended
Employee Postretirement Benefits (Tables)	Mar. 31, 2015
Compensation And Retirement Disclosure [Abstract]
Schedule of Net Periodic Benefit Cost	Included in the table below is the periodic expense for pension and other postretirement benefits offered by the company.

	Pension Expense
	(millions)	Pension Benefits						Other Postretirement Benefits
	Three months ended Mar. 31,	2015			2014			2015			2014
	Components of net periodic benefit expense
	Service cost	$	4.5		$	4.1		$	0.6		$	0.6
	Interest cost		7.4			8.2			2			2.6
	Expected return on assets		(10.8	)		(10.3	)		(0.3	)		0
	Amortization of:
	Prior service (benefit) cost		(0.1	)		(0.1	)		(0.6	)		0
	Actuarial loss		3.4			3.2			0			0
	Regulatory asset		0			0			0.3			0
	Net pension expense recognized in the	$	4.4		$	5.1		$	2		$	3.2
	TECO Energy Consolidated Condensed Statements of Income	$	4.4		$	5.1		$	2		$	3.2

ShortTerm_Debt_Tables

Short-Term Debt (Tables)	3 Months Ended
Short-Term Debt (Tables)	Mar. 31, 2015
Short-Term Debt Credit Facilities	At Mar. 31, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed:
	Credit Facilities
		Mar. 31, 2015						Dec. 31, 2014
						Letters						Letters
		Credit		Borrowings		of Credit		Credit		Borrowings		of Credit
	(millions)	Facilities		Outstanding (1)		Outstanding		Facilities		Outstanding (1)		Outstanding
	Tampa Electric Company:
	5-year facility (2)	$	325	$	5	$	0.6	$	325	$	12	$	0.6
	1-year accounts		150		42		0		150		46		0
	receivable facility		150		42		0		150		46		0
	TECO Energy/TECO Finance:
	5-year facility (2)(3)		300		144		0		300		50		0
	New Mexico Gas Company:
	5-year facility (2)		125		15		2.3		125		31		1.7
	Total	$	900	$	206	$	2.9	$	900	$	139	$	2.3

	(1) Borrowings outstanding are reported as notes payable.
	(2) This 5-year facility matures Dec. 17, 2018.
	(3) TECO Finance is the borrower and TECO Energy is the guarantor of this facility.


Tampa Electric Company [Member]
Short-Term Debt Credit Facilities	At Mar. 31, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed:

	Credit Facilities
		Mar. 31, 2015						Dec. 31, 2014
						Letters						Letters
		Credit		Borrowings		of Credit		Credit		Borrowings		of Credit
	(millions)	Facilities		Outstanding (1)		Outstanding		Facilities		Outstanding (1)		Outstanding
	Tampa Electric Company:
	5-year facility (2)	$	325	$	5	$	0.6	$	325	$	12	$	0.6
	1-year accounts		150		42		0		150		46		0
	receivable facility		150		42		0		150		46		0
	Total	$	475	$	47	$	0.6	$	475	$	58	$	0.6
	-1	Borrowings outstanding are reported as notes payable.
	-2	This 5-year facility matures Dec. 17, 2018.

Other_Comprehensive_Income_Tab

Other Comprehensive Income (Tables)	3 Months Ended
Other Comprehensive Income (Tables)	Mar. 31, 2015
Other Comprehensive Income	TECO Energy reported the following OCI for the three months ended Mar. 31, 2015 and 2014, related to changes in the fair value of cash flow hedges and amortization of unrecognized benefit costs associated with the company’s postretirement plans:

	Other Comprehensive Income
			Three months ended Mar. 31,
	(millions)		Gross				Tax				Net
	2015
	Unrealized gain on cash flow hedges		$	0.3			$	(0.2	)		$	0.1
	Reclassification from AOCI to net income (1)			0.4				(0.2	)			0.2
	Gain on cash flow hedges			0.7				(0.4	)			0.3
	Amortization of unrecognized benefit costs (2)			0.9				(0.3	)			0.6
	Total other comprehensive income (loss)		$	1.6			$	(0.7	)		$	0.9
	2014
	Unrealized loss on cash flow hedges		$	(0.1	)		$	0			$	(0.1	)
	Reclassification from AOCI to net income (1)			0.4				(0.1	)			0.3
	Gain on cash flow hedges			0.3				(0.1	)			0.2
	Amortization of unrecognized benefit costs (2)			0.8				(0.3	)			0.5
	Increase in unrecognized postemployment costs (3)			(12.9	)			4.7				(8.2	)
	Total other comprehensive income (loss)		$	(11.8	)		$	4.3			$	(7.5	)

	(1) Related to interest rate contracts recognized in Interest expense and commodity contracts recognized in Income (loss) from discontinued operations.
	(2) Related to postretirement and postemployment benefits. See Note 5 for additional information.
	(3) Amounts reflect an out-of-period adjustment related to TECO Coal's unfunded black lung liability.


Accumulated Other Comprehensive Loss
	Accumulated Other Comprehensive Loss
	(millions)		Mar. 31, 2015				Dec. 31, 2014
	Unamortized pension loss and prior service credit (1)		$	(22.0	)		$	(22.5	)
	Unamortized other benefit gains, prior service costs and			14				13.9
	transition obligations (2)			14				13.9
	Net unrealized losses from cash flow hedges (3)			(6.8	)			(7.1	)
	Total accumulated other comprehensive loss		$	(14.8	)		$	(15.7	)

	(1) Net of tax benefit of $13.5 million and $13.8 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.
	(2) Net of tax expense of $8.4 million and $8.3 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively. Balance includes a $7.7 million loss as of Mar. 31, 2015 related to TECO Coal's unfunded black lung liability that will be reclassified from AOCI to net income from discontinued operations upon the settlement of the black lung obligation at the sale date. See Note 15.
	(3) Net of tax benefit of $4.1 million and $4.5 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.

Tampa Electric Company [Member]
Other Comprehensive Income
	Other Comprehensive Income	Three months ended Mar. 31,
	(millions)	Gross				Tax				Net
	2015
	Unrealized gain on cash flow hedges	$	0.3			$	(0.2	)		$	0.1
	Reclassification from AOCI to net income		0.4				(0.2	)			0.2
	Gain on cash flow hedges		0.7				(0.4	)			0.3
	Total other comprehensive income	$	0.7			$	(0.4	)		$	0.3
	2014
	Unrealized gain on cash flow hedges	$	0			$	0			$	0
	Reclassification from AOCI to net income		0.4				(0.2	)			0.2
	Gain on cash flow hedges		0.4				(0.2	)			0.2
	Total other comprehensive income	$	0.4			$	(0.2	)		$	0.2

Accumulated Other Comprehensive Loss
	Accumulated Other Comprehensive Loss
	(millions)	Mar. 31, 2015				Dec. 31, 2014
	Net unrealized losses from cash flow hedges (1)	$	(6.8	)		$	(7.1	)
	Total accumulated other comprehensive loss	$	(6.8	)		$	(7.1	)

	-1	Net of tax benefit of $4.1 million and $4.5 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	3 Months Ended
Earnings Per Share (Tables)	Mar. 31, 2015
Earnings Per Share [Abstract]
Schedule of Earnings Per Share		For the three months ended Mar. 31,
	(millions, except per share amounts)	2015			2014 (1)
	Basic earnings per share
	Net income from continuing operations	$	63.8		$	48.4
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Income before discontinued operations available to	$	63.6		$	48.2
	common shareholders - Basic	$	63.6		$	48.2
	Income (Loss) from discontinued operations, net	$	(5.8	)	$	1.7
	Amount allocated to nonvested participating shareholders		0			0
	Income (Loss) from discontinued operations available to	$	(5.8	)	$	1.7
	common shareholders - Basic	$	(5.8	)	$	1.7
	Net income	$	58		$	50.1
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Net income available to common shareholders - Basic	$	57.8		$	49.9
	Average common shares outstanding - Basic		232.8			215.2
	Earnings per share from continuing operations available to	$	0.27		$	0.22
	common shareholders - Basic	$	0.27		$	0.22
	Earnings per share from discontinued operations available to	$	(0.02	)	$	0.01
	common shareholders - Basic	$	(0.02	)	$	0.01
	Earnings per share available to common shareholders - Basic	$	0.25		$	0.23
	Diluted earnings per share
	Net income from continuing operations	$	63.8		$	48.4
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Income before discontinued operations available to	$	63.6		$	48.2
	common shareholders - Diluted	$	63.6		$	48.2
	Income (Loss) from discontinued operations, net	$	(5.8	)	$	1.7
	Amount allocated to nonvested participating shareholders		0			0
	Income (Loss) from discontinued operations available to	$	(5.8	)	$	1.7
	common shareholders - Diluted	$	(5.8	)	$	1.7
	Net income	$	58		$	50.1
	Amount allocated to nonvested participating shareholders		(0.2	)		(0.2	)
	Net income available to common shareholders - Diluted	$	57.8		$	49.9
	Unadjusted average common shares outstanding - Diluted		232.8			215.2
	Assumed conversion of stock options, unvested restricted stock and		0.7			0.5
	contingent performance shares, net		0.7			0.5
	Average common shares outstanding - Diluted		233.5			215.7
	Earnings per share from continuing operations available to	$	0.27		$	0.22
	common shareholders - Diluted	$	0.27		$	0.22
	Earnings per share from discontinued operations available to	$	(0.02	)	$	0.01
	common shareholders - Diluted	$	(0.02	)	$	0.01
	Earnings per share available to common shareholders - Diluted	$	0.25		$	0.23
	Anti-dilutive shares		0.1			0
	(1) All prior periods presented reflect the classification of TECO Coal as discontinued operations (see Note 15).

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	3 Months Ended
Commitments and Contingencies (Tables)	Mar. 31, 2015
Letters of Credit and Guarantees	A summary of the face amount or maximum theoretical obligation and the year of expiration under letters of credit and guarantees as of Mar. 31, 2015 is as follows:


	(millions)	Year of expiration						Maximum
						After (1)		Theoretical		Liabilities Recognized
	Guarantees for the Benefit of:	2015		2016-2019		2019		Obligation		at Mar. 31, 2015 (2)
	TECO Energy
	Fuel sales and transportation	$	0	$	0	$	92.9	$	92.9	$	0

								Maximum
	(millions)					After (1)		Theoretical		Liabilities Recognized
	Letters of Credit for the Benefit of:	2015		2016-2019		2019		Obligation		at Mar. 31, 2015 (2)
	TEC	$	0	$	0	$	0.6	$	0.6	$	0.1
	NMGC	$	0	$	0	$	2.3	$	2.3	$	0

	(1) These letters of credit and guarantees renew annually and are shown on the basis that they will continue to renew beyond 2019.
	(2) The amounts shown are the maximum theoretical amounts guaranteed under current agreements. Liabilities recognized represent the associated obligation of TECO Energy, TEC or NMGC under these agreements at Mar. 31, 2015. The obligations under these letters of credit and guarantees include net accounts payable and net derivative liabilities.

Tampa Electric Company [Member]
Letters of Credit and Guarantees	A summary of the face amount or maximum theoretical obligation under TEC’s letters of credit as of Mar. 31, 2015 is as follows:

	Letters of Credit - Tampa Electric Company
	(millions)					After (1)				Liabilities Recognized
	Letters of Credit for the Benefit of:	2015		2016-2019		2019		Total		at Mar. 31, 2015
	TEC (2)	$	0	$	0	$	0.6	$	0.6	$	0.1
	-1	These letters of credit renew annually and are shown on the basis that they will continue to renew beyond 2019.
	-2	The amounts shown are the maximum theoretical amounts guaranteed under current agreements. Liabilities recognized represent the associated obligation of TEC under these agreements at Mar. 31, 2015. The obligations under these letters of credit include net accounts payable and net derivative liabilities.

Segment_Information_Tables

Segment Information (Tables)	3 Months Ended
Segment Information (Tables)	Mar. 31, 2015
Schedule of Segment Information	TECO Energy is an electric and gas utility holding company with diversified activities. Segments are determined based on how management evaluates, measures and makes decisions with respect to the operations of the entity. The management of TECO Energy reports segments based on each subsidiary’s contribution of revenues, net income and total assets as required by the accounting guidance for disclosures about segments of an enterprise and related information. Intercompany transactions are eliminated in the Consolidated Condensed Financial Statements of TECO Energy, but are included in determining reportable segments.


	Segment Information (1)
	(millions)	Tampa		Peoples		New Mexico			TECO									TECO
	Three months ended Mar. 31,	Electric		Gas		Gas Co. (2)			Coal (1)			Other (2)			Eliminations			Energy
	2015
	Revenues - external	$	449.8	$	121.7	$	119		$	0		$	2.5		$	0		$	693
	Sales to affiliates		0.8		1.2		0			0			0			(2.0	)		0
	Total revenues		450.6		122.9		119			0			2.5			(2.0	)		693
	Depreciation and amortization		62.9		13.9		8.4			0			0.3			0			85.5
	Total interest charges		23.5		3.5		3.3			0			17.9			(0.3	)		47.9
	Internally allocated interest		0		0		0			0			0.3			(0.3	)		0
	Provision (benefit) for income taxes		27.4		9.2		9			0			(5.7	)		0			39.9
	Net income (loss) from continuing operations		48.2		14.6		13.9			0			56			(68.9	)		63.8
	Income (loss) from discontinued operations, net (1)		0		0		0			(6.0	)		0.2			0			(5.8	)
	Net income (loss)	$	48.2	$	14.6	$	13.9		$	(6.0	)	$	56.2		$	(68.9	)	$	58
	2014
	Revenues - external	$	452.9	$	122.4	$	0		$	0		$	2.7		$	0		$	578
	Sales to affiliates		0.3		0.2		0			0			0			(0.5	)		0
	Total revenues		453.2		122.6		0			0			2.7			(0.5	)		578
	Depreciation and amortization		62.1		13.3		0			0			0.5			0			75.9
	Total interest charges		22		3.4		0			0			16			(1.8	)		39.6
	Internally allocated interest		0		0		0			0			1.8			(1.8	)		0
	Provision (benefit) for income taxes		26.6		9.2		0			0			(6.7	)		0			29.1
	Net income (loss) from continuing operations		45.2		14.6		0			0			37.5			(48.9	)		48.4
	Income (loss) from discontinued operations, net (1)		0		0		0			(1.6	)		3.3			0			1.7
	Net income (loss)	$	45.2	$	14.6	$	0		$	(1.6	)	$	40.8		$	(48.9	)	$	50.1
	At Mar. 31, 2015
	Total assets	$	6,619.70	$	1,085.50	$	1,207.90		$	209.6		$	5,802.50		$	(6,147.7	)	$	8,777.50
	At Dec. 31, 2014
	Total assets	$	6,565.40	$	1,082.80	$	1,237.20		$	227.7		$	5,664.40		$	(6,051.3	)		8,726.20
	(1) All periods have been adjusted to reflect the reclassification of results from operations to discontinued operations for TECO Coal and certain charges at Parent that directly relate to TECO Coal. See Note 15.
	(2) NMGI is included in the Other segment.


Tampa Electric Company [Member]
Schedule of Segment Information	(millions)	Tampa		Peoples					Tampa Electric
	Three months ended Mar. 31,	Electric		Gas		Eliminations			Company
	2015
	Revenues - external	$	450.4	$	121.7	$	0		$	572.1
	Sales to affiliates		0.2		1.2		(1.4	)		0
	Total revenues		450.6		122.9		(1.4	)		572.1
	Depreciation and amortization		62.9		13.9		0			76.8
	Total interest charges		23.5		3.5		0			27
	Provision for income taxes		27.4		9.2		0			36.6
	Net income		48.2		14.6		0			62.8
	2014
	Revenues - external	$	453.1	$	122.4	$	0		$	575.5
	Sales to affiliates		0.1		0.2		(0.3	)		0
	Total revenues		453.2		122.6		(0.3	)		575.5
	Depreciation and amortization		62.1		13.3		0			75.4
	Total interest charges		22		3.4		0			25.4
	Provision for income taxes		26.6		9.2		0			35.8
	Net income		45.2		14.6		0		$	59.8
	Total assets at Mar. 31, 2015	$	6,278.70	$	1,050.40	$	(9.0	)	$	7,320.10
	Total assets at Dec. 31, 2014		6,234.40		1,047.00		(7.1	)		7,274.30

Accounting_for_Derivative_Inst1

Accounting for Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2015
Derivative Volumes Expected to Settle	The maximum length of time over which the company is hedging its exposure to the variability in future cash flows extends to Mar. 31, 2017 for financial natural gas contracts. The following table presents the company’s derivative volumes that, as of Mar. 31, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years:

	Derivative Volumes	Natural Gas Contracts
	(millions)	(MMBTUs)
	Year	Physical		Financial
	2015		0		29.8
	2016		0		9.6
	2017		0		0.9
	Total		0		40.3

Tampa Electric Company [Member]
Derivative Volumes Expected to Settle	The maximum length of time over which TEC is hedging its exposure to the variability in future cash flows extends to Mar. 31, 2017 for financial natural gas contracts. The following table presents TEC’s derivative volumes that, as of Mar. 31, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years:

		Natural Gas Contracts
	(millions)	(MMBTUs)
	Year	Physical		Financial
	2015		0		29.8
	2016		0		9.6
	2017		0		0.9
	Total		0		40.3

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	3 Months Ended
Fair Value Measurements (Tables)	Mar. 31, 2015
Schedule of Recurring Fair Value Measurements

	Recurring Fair Value Measures
		As of Mar. 31, 2015
	(millions)	Level 1		Level 2		Level 3		Total
	Assets
	Interest rate swaps	$	0	$	0.3	$	0	$	0.3

	Liabilities
	Natural gas swaps	$	0	$	40.8	$	0	$	40.8

		As of Dec. 31, 2014
	(millions)	Level 1		Level 2		Level 3		Total
	Liabilities
	Natural gas swaps	$	0	$	42.7	$	0	$	42.7

Tampa Electric Company [Member]
Schedule of Recurring Fair Value Measurements	Recurring Derivative Fair Value Measures
		As of Mar. 31, 2015
	(millions)	Level 1		Level 2		Level 3		Total
	Assets
	Interest rate swaps	$	0	$	0.3	$	0	$	0.3

	Liabilities
	Natural gas swaps	$	0	$	40.8	$	0	$	40.8

		As of Dec. 31, 2014
	(millions)	Level 1		Level 2		Level 3		Total
	Liabilities
	Natural gas swaps	$	0	$	42.7	$	0	$	42.7

Discontinued_Operations_Assets1

Discontinued Operations, Assets Held for Sale and Asset Impairments (Tables)	3 Months Ended
	Mar. 31, 2015
TECO Coal [Member]
Components of Discontinued Operations	The following table provides a summary of the carrying amounts of the significant assets and liabilities reported in the combined current and non-current “Assets held for sale” and “Liabilities associated with assets held for sale” line items:

	Assets held for sale
	(millions)	Mar. 31, 2015			Dec. 31, 2014
	Current assets (1)	$	97.1		$	109.6
	Property, plant and equipment, net and other long-term assets		60.9			59.8
	Total assets held for sale	$	158		$	169.4

	Liabilities associated with assets held for sale
	(millions)	Mar. 31, 2015			Dec. 31, 2014
	Current liabilities	$	33.7		$	39.4
	Long-term liabilities		65.7			65.4
	Total liabilities associated with assets held for sale	$	99.4		$	104.8
	-1	Certain items within Current assets are excluded from the SPA working capital adjustments.
TECO Coal and TECO Guatemala [Member]
Components of Discontinued Operations	The following table provides selected components of discontinued operations related to the sales of TECO Coal and TECO Guatemala:

	Components of income from discontinued operations	Three months ended
		Mar. 31,
	(millions)	2015			2014
	Revenues—TECO Coal	$	72.7		$	106.1
	Loss from operations—TECO Coal		(9.5	)		(3.8	)
	Income (loss) from operations—TECO Guatemala		(0.1	)		5
	Loss from discontinued operations—TECO Coal		(9.5	)		(3.8	)
	Income (loss) from discontinued operations—TECO Guatemala		(0.1	)		5
	Income (loss) from discontinued operations		(9.6	)		1.2
	Benefit for income taxes		(3.8	)		(0.5	)
	Income (loss) from discontinued operations, net	$	(5.8	)	$	1.7

Summary_of_Significant_Account2

Summary of Significant Accounting Policies - Additional Information (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Summary Of Significant Accounting Policies [Line Items]
Unbilled revenues	$63.80		$86.60
Franchise fees and gross receipts taxes	27.4	27.2
Tampa Electric Company [Member]
Summary Of Significant Accounting Policies [Line Items]
Unbilled revenues	52.5		49.3
Franchise fees and gross receipts taxes	$27.40	$27.20

Regulatory_Schedule_of_Regulat

Regulatory - Schedule of Regulatory Assets and Regulatory Liabilities (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Regulatory assets:
Regulatory assets	$402	$402.10
Less: Current portion	52	53.6
Long-term regulatory assets	350	348.5
Regulatory liabilities:
Regulatory liabilities	769.4	786
Less: Current portion	49.4	57
Long-term regulatory liabilities	720	729
Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	373.9	371.7
Less: Current portion	51.6	52.1
Long-term regulatory assets	322.3	319.6
Regulatory liabilities:
Regulatory liabilities	661.7	678.1
Less: Current portion	48.8	54.7
Long-term regulatory liabilities	612.9	623.4
Regulatory Tax Asset [Member]
Regulatory assets:
Regulatory assets	70.5	69.2
Regulatory Tax Asset [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	70.5	69.2
Cost-Recovery Clauses [Member]
Regulatory assets:
Regulatory assets	42.8	45.1
Cost-Recovery Clauses [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	42.4	43.6
Postretirement Benefit Asset [Member]
Regulatory assets:
Regulatory assets	195.6	194
Postretirement Benefit Asset [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	189.7	187.8
Deferred Bond Refinancing Costs [Member]
Regulatory assets:
Regulatory assets	7	7.2
Deferred Bond Refinancing Costs [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	7	7.2
Debt Basis Adjustment [Member]
Regulatory assets:
Regulatory assets	20.1	20.9
Environmental Remediation [Member]
Regulatory assets:
Regulatory assets	53.4	53.1
Environmental Remediation [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	53.4	53.1
Competitive Rate Adjustment [Member]
Regulatory assets:
Regulatory assets	2.6	2.8
Competitive Rate Adjustment [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	2.6	2.8
Other [Member]
Regulatory assets:
Regulatory assets	10	9.8
Other [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	8.3	8
Total Other Regulatory Assets [Member]
Regulatory assets:
Regulatory assets	331.5	332.9
Total Other Regulatory Assets [Member] \| Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	303.4	302.5
Regulatory Tax Liability [Member]
Regulatory liabilities:
Regulatory liabilities	6.6	6.9
Regulatory Tax Liability [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	4.9	5.1
Cost-Recovery Clauses [Member]
Regulatory liabilities:
Regulatory liabilities	19.4	25.9
Cost-Recovery Clauses [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	18.8	23.5
Transmission and Delivery Storm Reserve [Member]
Regulatory liabilities:
Regulatory liabilities	56.1	56.1
Transmission and Delivery Storm Reserve [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	56.1	56.1
Deferred Gain on Property Sales [Member]
Regulatory liabilities:
Regulatory liabilities	0.5	0.8
Deferred Gain on Property Sales [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	0.5	0.8
Accumulated Reserve - Cost of Removal [Member]
Regulatory liabilities:
Regulatory liabilities	686	695.2
Accumulated Reserve - Cost of Removal [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	580.7	591.5
Other [Member]
Regulatory liabilities:
Regulatory liabilities	0.8	1.1
Other [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	0.7	1.1
Total Other Regulatory Liabilities [Member]
Regulatory liabilities:
Regulatory liabilities	762.8	779.1
Total Other Regulatory Liabilities [Member] \| Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	$656.80	$673

Regulatory_Schedule_of_Regulat1

Regulatory - Schedule of Regulatory Assets and Regulatory Liabilities (Parenthetical) (Detail)	3 Months Ended
	Mar. 31, 2015
Schedule Of Regulatory Assets And Liabilities [Line Items]
Amortization period	Amortized over a 5-year
Tampa Electric Company [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Amortization period	Amortized over a 5-year

Regulatory_Regulatory_Assets_a

Regulatory - Regulatory Assets and Related Recovery Periods (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Regulatory Asset [Line Items]
Regulatory assets	$402	$402.10
Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	373.9	371.7
Components of Rate Base [Member]
Regulatory Asset [Line Items]
Regulatory assets	200.7	199
Components of Rate Base [Member] \| Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	193	191
Clause Recoverable [Member]
Regulatory Asset [Line Items]
Regulatory assets	45.4	47.9
Clause Recoverable [Member] \| Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	45	46.4
Regulatory Tax Asset [Member]
Regulatory Asset [Line Items]
Regulatory assets	70.5	69.2
Regulatory Tax Asset [Member] \| Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	70.5	69.2
Capital Structure and Other [Member]
Regulatory Asset [Line Items]
Regulatory assets	85.4	86
Capital Structure and Other [Member] \| Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	$65.40	$65.10

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Detail)	3 Months Ended
Income Taxes - Additional Information (Detail)	Mar. 31, 2015	Mar. 31, 2014
Income Taxes [Line Items]
Effective tax rate	38.48%	37.55%
Income tax examination period	1 year
Tampa Electric Company [Member]
Income Taxes [Line Items]
Statutes of limitations	3 years
Income tax examination period	1 year
Minimum [Member]
Income Taxes [Line Items]
Statutes of limitations	3 years
Maximum [Member]
Income Taxes [Line Items]
Statutes of limitations	4 years

Employee_Postretirement_Benefi2

Employee Postretirement Benefits - Schedule of Net Periodic Benefit Cost (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$4.50	$4.10
Interest cost	7.4	8.2
Expected return on assets	-10.8	-10.3
Amortization of:
Prior service (benefit) cost	-0.1	-0.1
Actuarial loss	3.4	3.2
Regulatory asset	0	0
Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income	4.4	5.1
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0.6	0.6
Interest cost	2	2.6
Expected return on assets	-0.3	0
Amortization of:
Prior service (benefit) cost	-0.6	0
Actuarial loss	0	0
Regulatory asset	0.3	0
Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income	$2	$3.20

Employee_Postretirement_Benefi3

Employee Postretirement Benefits - Additional Information (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014	Jan. 01, 2015
Defined Benefit Plan Disclosure [Line Items]
Reclassification of AOCI to net income as part of periodic benefit expense	$0.80	$0.60
Reclassification of regulatory assets to net income as part of periodic benefit expense	2.2	2.5
TECO Coal [Member]
Defined Benefit Plan Disclosure [Line Items]
Black lung liability	24.8		24.7
Expenses related to black lung liability	0	0
Settlement charge, related to unfunded black lung obligations	7.7
Tampa Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term EROA	7.00%
Employer contributions	11	13
Reclassification of regulatory assets to net income as part of periodic benefit expense	1.9	2.5
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term EROA	7.00%
Discount rate	4.26%
Employer contributions	14.9	16
Net pension expense	4.4	5.1
Pension Benefits [Member] \| Tampa Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.26%
Net pension expense	2.6	3.8
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate				4.21%
Net pension expense	2	3.2
Other Postretirement Benefits [Member] \| Tampa Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate				4.21%
Net pension expense	$1.40	$2.60

ShortTerm_Debt_Credit_Faciliti

Short-Term Debt - Credit Facilities (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Line Of Credit Facility [Line Items]
Credit Facilities	$900	$900
Borrowings Outstanding	206	139
Letters of Credit Outstanding	2.9	2.3
Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	475	475
Borrowings Outstanding	47	58
Letters of Credit Outstanding	0.6	0.6
Tampa Electric Company [Member] \| 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	325	325
Borrowings Outstanding	5	12
Letters of Credit Outstanding	0.6	0.6
Tampa Electric Company [Member] \| 1-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	150	150
Borrowings Outstanding	42	46
Letters of Credit Outstanding	0	0
TECO Energy [Member] \| 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	300	300
Borrowings Outstanding	144	50
Letters of Credit Outstanding	0	0
New Mexico Gas Company [Member] \| 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	125	125
Borrowings Outstanding	15	31
Letters of Credit Outstanding	$2.30	$1.70

ShortTerm_Debt_Credit_Faciliti1

Short-Term Debt - Credit Facilities (Parenthetical) (Detail)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Line Of Credit Facility [Line Items]
Credit facility maturity date	17-Dec-18	17-Dec-18
Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	17-Dec-18	17-Dec-18

ShortTerm_Debt_Additional_Info

Short-Term Debt - Additional Information (Detail) (USD $)	3 Months Ended	12 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Mar. 24, 2015
Line Of Credit Facility [Line Items]
Line of Credit Facility maximum borrowing capacity	$900	$900
Credit facility maturity date	17-Dec-18	17-Dec-18
Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate	0.87%	0.70%
Line of Credit Facility maximum borrowing capacity	475	475
Credit facility maturity date	17-Dec-18	17-Dec-18
Tampa Electric Company [Member] \| 1-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Line of Credit Facility maximum borrowing capacity	$150	$150
Credit facility maturity date			23-Mar-18
Credit Facility amendment date			24-Mar-15
Tampa Electric Company [Member] \| 1-year Accounts Receivable Facility [Member] \| Before Amendment and Restatement
Line Of Credit Facility [Line Items]
Credit facility maturity date			14-Apr-15
TECO Energy [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate	1.12%	1.16%
TECO Finance [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate	1.12%	1.16%
New Mexico Gas Company [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate	1.12%	1.16%
Minimum [Member] \| Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Commitment fees, percentage	0.13%
Maximum [Member] \| Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Commitment fees, percentage	0.30%

LongTerm_Debt_Additional_Infor

Long-Term Debt - Additional Information (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Apr. 10, 2015
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014	Apr. 10, 2015
Debt Instrument [Line Items]
Long-term debt, carrying amount	$3,627.70	$3,628.50
Estimated fair value	4,035.80	3,987.80
TECO Finance [Member] \| Floating Rate Notes Due 2018 [Member] \| Subsequent Event [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued			250
Tampa Electric Company [Member]
Debt Instrument [Line Items]
Long-term debt, carrying amount	2,097.10	2,097.10
Estimated fair value	$2,414.80	$2,372.20

Other_Comprehensive_Income_Acc

Other Comprehensive Income - Accumulated Other Comprehensive Loss (Income) (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014		Dec. 31, 2014
Other Comprehensive Income Loss [Line Items]
Unrealized gain (loss) on cash flow hedges, Gross	$0.30		($0.10)
Reclassification from AOCI to net income, Gross	0.4	[1]	0.4	[1]
Gain (Loss) on cash flow hedges, Gross	0.7		0.3
Amortization of unrecognized benefit costs, Gross	0.9	[2]	0.8	[2]
Increase in unrecognized postemployment costs, Gross			-12.9	[3]
Total other comprehensive income (loss), Gross	1.6		-11.8
Unrealized gain (loss) on cash flow hedges, Tax	-0.2		0
Reclassification from AOCI to net income, Tax	-0.2	[1]	-0.1	[1]
Gain (loss) on cash flow hedges, Tax	-0.4		-0.1
Amortization of unrecognized benefit costs, Tax	-0.3	[2]	-0.3	[2]
Increase in unrecognized postemployment costs, Tax			4.7	[3]
Total other comprehensive income (loss), Tax	-0.7		4.3
Unrealized gain (loss) on cash flow hedges, Net	0.1		-0.1
Reclassification from AOCI to net income, Net	0.2	[1]	0.3	[1]
Gain (loss) on cash flow hedges, Net	0.3		0.2
Amortization of unrecognized benefit costs	0.6	[2]	0.5	[2]
Increase in unrecognized postemployment costs, Net			-8.2	[3]
Other comprehensive income (loss), net of tax	0.9		-7.5
Unamortized pension loss and prior service credit	-22	[4]			-22.5	[4]
Unamortized other benefit gains, prior service costs and transition obligations	14	[5]			13.9	[5]
Net unrealized losses from cash flow hedges	-6.8	[6]			-7.1	[6]
Total accumulated other comprehensive loss	-14.8				-15.7
Tampa Electric Company [Member]
Other Comprehensive Income Loss [Line Items]
Unrealized gain (loss) on cash flow hedges, Gross	0.3		0
Reclassification from AOCI to net income, Gross	0.4		0.4
Gain (Loss) on cash flow hedges, Gross	0.7		0.4
Total other comprehensive income (loss), Gross	0.7		0.4
Unrealized gain (loss) on cash flow hedges, Tax	-0.2		0
Reclassification from AOCI to net income, Tax	-0.2		-0.2
Gain (loss) on cash flow hedges, Tax	-0.4		-0.2
Total other comprehensive income (loss), Tax	-0.4		-0.2
Unrealized gain (loss) on cash flow hedges, Net	0.1		0
Reclassification from AOCI to net income, Net	0.2		0.2
Gain (loss) on cash flow hedges, Net	0.3		0.2
Other comprehensive income (loss), net of tax	0.3		0.2
Net unrealized losses from cash flow hedges	-6.8	[6]			-7.1	[6]
Total accumulated other comprehensive loss	($6.80)				($7.10)

[1]	Related to interest rate contracts recognized in Interest expense and commodity contracts recognized in Income (loss) from discontinued operations.
[2]	Related to postretirement and postemployment benefits. See Note 5 for additional information.
[3]	Amounts reflect an out-of-period adjustment related to TECO Coal's unfunded black lung liability.
[4]	Net of tax benefit of $13.5 million and $13.8 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.
[5]	Net of tax expense of $8.4 million and $8.3 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively. Balance includes a $7.7 million loss as of Mar. 31, 2015 related to TECO Coal's unfunded black lung liability that will be reclassified from AOCI to net income from discontinued operations upon the settlement of the black lung obligation at the sale date. See Note 15.
[6]	Net of tax benefit of $4.1 million and $4.5 million as of Mar. 31, 2015 and Dec. 31, 2014, respectively.

Other_Comprehensive_Income_Acc1

Other Comprehensive Income - Accumulated Other Comprehensive Loss (Parenthetical) (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Accumulated Other Comprehensive Income Loss [Line Items]
Net income discontinued operations settlement	$7.70
Net unrealized losses from cash flow hedges, tax benefit	4.1	4.5
Tampa Electric Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Net unrealized losses from cash flow hedges, tax benefit	4.1	4.5
Pension Benefits [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Unrecognized pension and other benefit loss, prior service cost (credit) and transition obligation, tax expense (benefit)	13.5	13.8
Other Postretirement Benefits [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Unrecognized pension and other benefit loss, prior service cost (credit) and transition obligation, tax expense (benefit)	$8.40	$8.30

Earnings_Per_Share_Schedule_of

Earnings Per Share - Schedule of Earnings Per Share (Detail) (USD $)	3 Months Ended
In Millions, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Basic earnings per share
Net income from continuing operations	$63.80	$48.40
Amount allocated to nonvested participating shareholders	-0.2	-0.2
Income before discontinued operations available to common shareholders - Basic	63.6	48.2
Income (Loss) from discontinued operations, net	-5.8	1.7
Amount allocated to nonvested participating shareholders	0	0
Income (Loss) from discontinued operations available to common shareholders - Basic	-5.8	1.7
Net income	58	50.1
Amount allocated to nonvested participating shareholders	-0.2	-0.2
Net income available to common shareholders - Basic	57.8	49.9
Average common shares outstanding - Basic	232.8	215.2
Earnings per share from continuing operations - Basic	$0.27	$0.22
Earnings per share from discontinued operations - Basic	($0.02)	$0.01
Earnings per share - Basic	$0.25	$0.23
Diluted earnings per share
Net income from continuing operations	63.8	48.4
Amount allocated to nonvested participating shareholders	-0.2	-0.2
Income before discontinued operations available to common shareholders - Diluted	63.6	48.2
Income (Loss) from discontinued operations, net	-5.8	1.7
Amount allocated to nonvested participating shareholders	0	0
Income (Loss) from discontinued operations available to common shareholders - Diluted	-5.8	1.7
Net income	58	50.1
Amount allocated to nonvested participating shareholders	-0.2	-0.2
Net income available to common shareholders - Diluted	$57.80	$49.90
Average common shares outstanding - Basic	232.8	215.2
Assumed conversion of stock options, unvested restricted stock and contingent performance shares, net	0.7	0.5
Average common shares outstanding - Diluted	233.5	215.7
Earnings per share from continuing operations available to common shareholders - Diluted	$0.27	$0.22
Earnings per share from discontinued operations available to common shareholders - Diluted	($0.02)	$0.01
Earnings per share - Diluted	$0.25	$0.23
Anti-dilutive shares	0.1	0

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Detail) (USD $)	0 Months Ended	3 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Feb. 08, 2011	Mar. 31, 2015	Dec. 19, 2013	Mar. 31, 2011
	InsuranceCarrier	Claims		Customer
	Lawsuit
Long Term Commitments [Line Items]
Gas supply disruption of high utility customers				32,000
Number of class dismissed		2
Period of appeal expires		30 days
Right to appeal expiration date		Oct-14
Number of lawsuits for insurance carriers	2
Number of insurance carriers	18
Expected period for annulment proceedings		2 years
TECO Guatemala Holdings, LLC v. The Republic of Guatemala [Member]
Long Term Commitments [Line Items]
Litigation settlement amount			$7.50
Damages awarded			21.1
TECO Guatemala Holdings, LLC v. The Republic of Guatemala [Member] \| U.S. prime rate plus [Member]
Long Term Commitments [Line Items]
Litigation settlement interest			2.00%
Gas Shortages [Member]
Long Term Commitments [Line Items]
Gas supply disruption of high utility customers	28,700
PGS [Member]
Long Term Commitments [Line Items]
Ultimate financial liability to superfund sites and former MGP sites		33.3
PGS [Member] \| Tampa Electric Company [Member]
Long Term Commitments [Line Items]
Ultimate financial liability to superfund sites and former MGP sites		33.3

Commitments_and_Contingencies_2

Commitments and Contingencies - Letters of Credit and Guarantees (Detail) (USD $)	Mar. 31, 2015
Tampa Electric Company [Member] \| Letters Of Credit [Member]
Guarantee Obligations [Line Items]
Year of Expiration	$0
Year of expiration 2016-2019	0
Year of expiration After 2019	600,000
Maximum Theoretical Obligation	600,000
Liabilities Recognized at Mar 31, 2015	100,000
New Mexico Gas Company [Member] \| Letters Of Credit [Member]
Guarantee Obligations [Line Items]
Year of Expiration	0
Year of expiration 2016-2019	0
Year of expiration After 2019	2,300,000
Maximum Theoretical Obligation	2,300,000
Liabilities Recognized at Mar 31, 2015	0
Fuel Sales and Transportation [Member]
Guarantee Obligations [Line Items]
Year of Expiration	0
Year of expiration 2016-2019	0
Year of expiration After 2019	92,900,000
Maximum Theoretical Obligation	92,900,000
Liabilities Recognized at Mar 31, 2015	$0

Segment_Information_Schedule_o

Segment Information - Schedule of Segment Information (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Total revenues	$693	$578
Depreciation and amortization	85.5	75.9
Total interest charges	47.9	39.6
Internally allocated interest	0	0
Provision (benefit) for income taxes	39.9	29.1
Net income (loss) from continuing operations	63.8	48.4
Income (loss) from discontinued operations, net	-5.8	1.7
Net income (loss)	58	50.1
Total assets	8,777.50		8,726.20
Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	572.1	575.5
Depreciation and amortization	76.8	75.4
Total interest charges	27	25.4
Provision (benefit) for income taxes	36.6	35.8
Net income (loss)	62.8	59.8
Total assets	7,320.10		7,274.30
Eliminations [Member]
Segment Reporting Information [Line Items]
Total revenues	-2	-0.5
Depreciation and amortization	0	0
Total interest charges	-0.3	-1.8
Internally allocated interest	-0.3	-1.8
Provision (benefit) for income taxes	0	0
Net income (loss) from continuing operations	-68.9	-48.9
Income (loss) from discontinued operations, net	0	0
Net income (loss)	-68.9	-48.9
Total assets	-6,147.70		-6,051.30
Eliminations \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	-1.4	-0.3
Depreciation and amortization	0	0
Total interest charges	0	0
Provision (benefit) for income taxes	0	0
Net income (loss)	0	0
Total assets	-9		-7.1
Tampa Electric [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	450.6	453.2
Depreciation and amortization	62.9	62.1
Total interest charges	23.5	22
Internally allocated interest	0	0
Provision (benefit) for income taxes	27.4	26.6
Net income (loss) from continuing operations	48.2	45.2
Income (loss) from discontinued operations, net	0	0
Net income (loss)	48.2	45.2
Total assets	6,619.70		6,565.40
Tampa Electric [Member] \| Operating Segments [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	450.6	453.2
Depreciation and amortization	62.9	62.1
Total interest charges	23.5	22
Provision (benefit) for income taxes	27.4	26.6
Net income (loss)	48.2	45.2
Total assets	6,278.70		6,234.40
PGS [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	122.9	122.6
Depreciation and amortization	13.9	13.3
Total interest charges	3.5	3.4
Internally allocated interest	0	0
Provision (benefit) for income taxes	9.2	9.2
Net income (loss) from continuing operations	14.6	14.6
Income (loss) from discontinued operations, net	0	0
Net income (loss)	14.6	14.6
Total assets	1,085.50		1,082.80
PGS [Member] \| Operating Segments [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	122.9	122.6
Depreciation and amortization	13.9	13.3
Total interest charges	3.5	3.4
Provision (benefit) for income taxes	9.2	9.2
Net income (loss)	14.6	14.6
Total assets	1,050.40		1,047
NMGC [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	119	0
Depreciation and amortization	8.4	0
Total interest charges	3.3	0
Internally allocated interest	0	0
Provision (benefit) for income taxes	9	0
Net income (loss) from continuing operations	13.9	0
Income (loss) from discontinued operations, net	0	0
Net income (loss)	13.9	0
Total assets	1,207.90		1,237.20
TECO Coal [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0
Depreciation and amortization	0	0
Total interest charges	0	0
Internally allocated interest	0	0
Provision (benefit) for income taxes	0	0
Net income (loss) from continuing operations	0	0
Income (loss) from discontinued operations, net	-6	-1.6
Net income (loss)	-6	-1.6
Total assets	209.6		227.7
Other [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	2.5	2.7
Depreciation and amortization	0.3	0.5
Total interest charges	17.9	16
Internally allocated interest	0.3	1.8
Provision (benefit) for income taxes	-5.7	-6.7
Net income (loss) from continuing operations	56	37.5
Income (loss) from discontinued operations, net	0.2	3.3
Net income (loss)	56.2	40.8
Total assets	5,802.50		5,664.40
Revenues - External [Member]
Segment Reporting Information [Line Items]
Total revenues	693	578
Revenues - External [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	572.1	575.5
Revenues - External [Member] \| Eliminations [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0
Revenues - External [Member] \| Eliminations \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0
Revenues - External [Member] \| Tampa Electric [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	449.8	452.9
Revenues - External [Member] \| Tampa Electric [Member] \| Operating Segments [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	450.4	453.1
Revenues - External [Member] \| PGS [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	121.7	122.4
Revenues - External [Member] \| PGS [Member] \| Operating Segments [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	121.7	122.4
Revenues - External [Member] \| NMGC [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	119	0
Revenues - External [Member] \| TECO Coal [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0
Revenues - External [Member] \| Other [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	2.5	2.7
Sales to Affiliates [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0
Sales to Affiliates [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0
Sales to Affiliates [Member] \| Eliminations [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	-2	-0.5
Sales to Affiliates [Member] \| Eliminations \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	-1.4	-0.3
Sales to Affiliates [Member] \| Tampa Electric [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0.8	0.3
Sales to Affiliates [Member] \| Tampa Electric [Member] \| Operating Segments [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0.2	0.1
Sales to Affiliates [Member] \| PGS [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	1.2	0.2
Sales to Affiliates [Member] \| PGS [Member] \| Operating Segments [Member] \| Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	1.2	0.2
Sales to Affiliates [Member] \| NMGC [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0
Sales to Affiliates [Member] \| TECO Coal [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0
Sales to Affiliates [Member] \| Other [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	$0	$0

Accounting_for_Derivative_Inst2

Accounting for Derivative Instruments and Hedging Activities - Additional Information (Detail) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative assets	$300,000	$0
Derivative liabilities	40,800,000	42,700,000
Cash collateral posted with or received from any counterparties	0	0
Net pretax gain (loss) expected to be reclassified from regulatory assets or liabilities	-35,200,000
Tampa Electric Company [Member]
Derivative [Line Items]
Derivative assets	300,000	0
Derivative liabilities	40,800,000	42,700,000
Cash collateral posted with or received from any counterparties	0	0
Net pretax gain (loss) expected to be reclassified from regulatory assets or liabilities	($35,200,000)
Natural Gas Contracts [Member]
Derivative [Line Items]
Maximum length of time hedging in future cash flow	31-Mar-17
Natural Gas Contracts [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Maximum length of time hedging in future cash flow	31-Mar-17

Accounting_for_Derivative_Inst3

Accounting for Derivative Instruments and Hedging Activities - Derivative Volumes Expected to Settle (Detail) (Natural Gas Contracts [Member])	Mar. 31, 2015
	MMBTU
Physical [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
Physical [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
Financial [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	40,300,000
Financial [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	40,300,000
2015 [Member] \| Physical [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
2015 [Member] \| Physical [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
2015 [Member] \| Financial [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	29,800,000
2015 [Member] \| Financial [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	29,800,000
2016 [Member] \| Physical [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
2016 [Member] \| Physical [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
2016 [Member] \| Financial [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	9,600,000
2016 [Member] \| Financial [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	9,600,000
2017 [Member] \| Physical [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
2017 [Member] \| Physical [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	0
2017 [Member] \| Financial [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	900,000
2017 [Member] \| Financial [Member] \| Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	900,000

Fair_Value_Measurements_Schedu

Fair Value Measurements - Schedule of Recurring Fair Value Measurements (Detail) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	$0.30	$0
Total Swap Liabilities	40.8	42.7
Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0.3	0
Total Swap Liabilities	40.8	42.7
Fair Value, Measurements, Recurring [Member] \| Interest Rate Swap [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0.3
Fair Value, Measurements, Recurring [Member] \| Interest Rate Swap [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0.3
Fair Value, Measurements, Recurring [Member] \| Level 1 [Member] \| Interest Rate Swap [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0
Fair Value, Measurements, Recurring [Member] \| Level 1 [Member] \| Interest Rate Swap [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0
Fair Value, Measurements, Recurring [Member] \| Level 2 [Member] \| Interest Rate Swap [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0.3
Fair Value, Measurements, Recurring [Member] \| Level 2 [Member] \| Interest Rate Swap [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0.3
Fair Value, Measurements, Recurring [Member] \| Level 3 [Member] \| Interest Rate Swap [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0
Fair Value, Measurements, Recurring [Member] \| Level 3 [Member] \| Interest Rate Swap [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Assets	0
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	40.8	42.7
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	40.8	42.7
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Level 1 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	0	0
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Level 1 [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	0	0
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Level 2 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	40.8	42.7
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Level 2 [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	40.8	42.7
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Level 3 [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	0	0
Fair Value, Measurements, Recurring [Member] \| Natural Gas Derivatives [Member] \| Level 3 [Member] \| Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Total Swap Liabilities	$0	$0

Variable_Interest_Entities_Add

Variable Interest Entities - Additional Information (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	$17.10	$18.20
Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	17.1	18.2
Power Purchase Agreements [Member] \| Variable Interest Entities [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	5.4	5.9
Power Purchase Agreements [Member] \| Variable Interest Entities [Member] \| Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	$5.40	$5.90
Minimum [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range	117
Minimum [Member] \| Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range	117
Maximum [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range	160
Maximum [Member] \| Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range	160

Discontinued_Operations_Assets2

Discontinued Operations, Assets Held for Sale and Asset Impairments - Additional Information (Detail) (TECO Coal [Member], USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014	Feb. 05, 2015
TECO Coal [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Contingent Payments			$60,000,000
Purchase price			80,000,000
Total pretax impairment charges	$0	$115,900,000

Discontinued_Operations_Assets3

Discontinued Operations, Assets Held for Sale and Asset Impairments - Carrying Amount of Assets and Liabilities Held for Sale (Detail) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Millions, unless otherwise specified	Mar. 31, 2015		Dec. 31, 2014
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Current assets	$97.10		$109.60
Property, plant and equipment, net and other long-term assets	60.9		59.8
Current liabilities	33.7		39.4
Long-term liabilities	65.7		65.4
TECO Coal [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Current assets	97.1	[1]	109.6	[1]
Property, plant and equipment, net and other long-term assets	60.9		59.8
Total assets held for sale	158		169.4
Current liabilities	33.7		39.4
Long-term liabilities	65.7		65.4
Total liabilities associated with assets held for sale	$99.40		$104.80

[1]	(1) Certain items within Current assets are excluded from the SPA working capital adjustments.

Discontinued_Operations_Assets4

Discontinued Operations, Assets Held for Sale and Asset Impairments - Components of Discontinued Operations (Detail) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations	($9.60)	$1.20
Benefit for income taxes	-3.8	-0.5
Income (loss) on discontinued operations, net	-5.8	1.7
TECO Coal [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues	72.7	106.1
Income (loss) from operations	-9.5	-3.8
Income (loss) from discontinued operations	-9.5	-3.8
TECO Guatemala [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (loss) from operations	-0.1	5
Income (loss) from discontinued operations	-0.1	5
TECO Coal and TECO Guatemala [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations	-9.6	1.2
Benefit for income taxes	-3.8	-0.5
Income (loss) on discontinued operations, net	($5.80)	$1.70

Subsequent_Events_Additional_I

Subsequent Events - Additional Information (Detail) (TECO Finance [Member], USD $)	3 Months Ended	0 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Apr. 10, 2015
Floating Rate Notes Due 2018 [Member]
Subsequent Event [Line Items]
Interest rate, description	The 2018 Notes will bear interest at a floating rate that is reset quarterly based on the three-month LIBOR plus 60 basis points, which is payable quarterly on Jan. 10, Apr. 10, July 10 and Oct. 10 of each year, beginning July 10, 2015.
Subsequent Event [Member] \| Floating Rate Notes Due 2018 [Member]
Subsequent Event [Line Items]
Aggregate principal amount issued		$250
Debt instrument, offering date		10-Apr-15
Debt instrument maturity date		10-Apr-18
Basis spread on federal funds rate		0.60%
Proceeds from notes net of issuance		248.6
Subsequent Event [Member] \| Notes Due in May 2015 [Member]
Subsequent Event [Line Items]
Redemption of notes		$191