TECO Energy 10-Q 5 Aug 15 2015 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 31, 2015
Document Information [Line Items]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Trading Symbol	TE
Entity Registrant Name	TECO ENERGY INC
Entity Central Index Key	350,563
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		235,215,710
Tampa Electric Company [Member]
Document Information [Line Items]
Entity Registrant Name	TAMPA ELECTRIC COMPANY
Entity Central Index Key	96,271
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		10

Consolidated Condensed Balance

Consolidated Condensed Balance Sheets (Unaudited) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Current assets
Cash and cash equivalents	$ 56	$ 25.4
Receivables, less allowance for uncollectibles	273.3	299.8
Inventories, at average cost
Derivative assets	0.6	0
Regulatory assets	39.4	53.6
Deferred income taxes	73.4	72.8
Prepayments and other current assets	31.5	22.6
Assets held for sale	96.5	109.6
Total current assets	779.2	755.6
Property, plant and equipment
Construction work in progress	648	640
Other property	14.8	14.5
Property, plant and equipment, at original costs	9,935.1	9,733.9
Accumulated depreciation	(2,693.4)	(2,645.7)
Total property, plant and equipment, net	7,241.7	7,088.2
Other assets
Regulatory assets	343.3	348.5
Goodwill	408.4	408.3
Deferred charges and other assets	65.8	65.8
Assets held for sale	0	59.8
Total other assets	817.5	882.4
Total assets	8,838.4	8,726.2
Current liabilities
Long-term debt due within one year	333.3	274.5
Notes payable	85.5	139
Accounts payable	258.2	288.6
Customer deposits	179.5	176.2
Regulatory liabilities	49.9	57
Derivative liabilities	24.4	36.6
Interest accrued	38.1	39.9
Taxes accrued	46	29.9
Other	16.7	16.8
Liabilities associated with assets held for sale	30.2	39.4
Total current liabilities	1,061.8	1,097.9
Other liabilities
Deferred income taxes	573.1	519.2
Investment tax credits	8.8	9
Regulatory liabilities	713.2	729
Derivative liabilities	1.9	6.1
Deferred credits and other liabilities	341.5	370.9
Liabilities associated with assets held for sale	66.3	65.4
Long-term debt, less amount due within one year	3,518.5	3,354
Total other liabilities	$ 5,223.3	$ 5,053.6
Commitments and contingencies (see Note 10)
Capital
Common equity	$ 235.1	$ 234.9
Additional paid in capital	1,885.7	1,875.9
Retained earnings	443.5	479.6
Accumulated other comprehensive loss	(11)	(15.7)
Total capital	2,553.3	2,574.7
Long-term debt	3,518.5	3,354
Total liabilities and capital	8,838.4	8,726.2
Tampa Electric Company [Member]
Current assets
Cash and cash equivalents	33.9	10.4
Receivables, less allowance for uncollectibles	251.6	227.2
Inventories, at average cost
Taxes receivable from affiliate	0	43.3
Regulatory assets	39.3	52.1
Deferred income taxes	21	24.8
Prepayments and other current assets	23.6	17.4
Total current assets	568.9	532.6
Property, plant and equipment
Construction work in progress	633.2	624.2
Utility plant in service, at original costs	9,209.3	9,027.9
Accumulated depreciation	(2,668.8)	(2,633.8)
Utility plant in service, net	6,540.5	6,394.1
Other property	8.9	8.6
Total property, plant and equipment, net	6,549.4	6,402.7
Other assets
Unamortized debt expense	18.7	16.8
Regulatory assets	316.9	319.6
Deferred charges and other assets	338	339
Other	2.4	2.6
Total assets	7,456.3	7,274.3
Current liabilities
Long-term debt due within one year	83.3	83.3
Notes payable	0	58
Accounts payable	231.4	242.3
Customer deposits	173.7	170.4
Regulatory liabilities	49.5	54.7
Derivative liabilities	24.4	36.6
Interest accrued	19	17
Taxes accrued	62.2	12.4
Other	10	10
Total current liabilities	653.5	684.7
Other liabilities
Deferred income taxes	1,240.5	1,209.1
Investment tax credits	8.8	9
Regulatory liabilities	604.5	623.4
Derivative liabilities	1.9	6.1
Deferred credits and other liabilities	276.4	299.1
Long-term debt, less amount due within one year	2,179.9	2,013.8
Total other liabilities	$ 2,132.1	$ 2,146.7
Commitments and contingencies (see Note 10)
Capital
Common equity	$ 2,160.4	$ 2,130.4
Retained earnings	334.4	305.8
Accumulated other comprehensive loss	(4)	(7.1)
Total capital	2,490.8	2,429.1
Long-term debt	2,179.9	2,013.8
Total capitalization	4,670.7	4,442.9
Total liabilities and capital	7,456.3	7,274.3
Fuel [Member]
Inventories, at average cost
Utility inventories	132.7	96.4
Fuel [Member] | Tampa Electric Company [Member]
Inventories, at average cost
Utility inventories	127	85.2
Materials and Supplies [Member]
Inventories, at average cost
Utility inventories	75.8	75.4
Materials and Supplies [Member] | Tampa Electric Company [Member]
Inventories, at average cost
Utility inventories	72.5	72.2
Electric [Member]
Property, plant and equipment
Utility plant in service, at original costs	7,217.1	7,094.8
Electric [Member] | Tampa Electric Company [Member]
Property, plant and equipment
Utility plant in service, at original costs	7,217.1	7,094.8
Gas [Member]
Property, plant and equipment
Utility plant in service, at original costs	2,055.2	1,984.6
Gas [Member] | Tampa Electric Company [Member]
Property, plant and equipment
Utility plant in service, at original costs	$ 1,359	$ 1,308.9

Consolidated Condensed Balance3

Consolidated Condensed Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Allowance for uncollectibles	$ 2.2	$ 2.1
Common equity, shares authorized	400,000,000	400,000,000
Common equity, par value	$ 1	$ 1
Common equity, shares outstanding	235,100,000	234,900,000
Tampa Electric Company [Member]
Allowance for uncollectibles	$ 1.5	$ 1.4

Consolidated Condensed Statemen

Consolidated Condensed Statements of Income (Unaudited) - USD ($) shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues
Regulated electric and gas	$ 678.2	$ 603.6	$ 1,368.1	$ 1,179.3
Unregulated	2.4	2.1	5.5	4.4
Total revenues	680.6	605.7	1,373.6	1,183.7
Expenses
Fuel	171.8	169.7	315.9	319.3
Purchased power	19.6	19.9	36.7	38.1
Cost of natural gas sold	49.1	29.1	152.1	76.2
Other	155.4	126.8	299.1	247.4
Operations and maintenance other expense	1.1	4.6	2.7	7.8
Depreciation and amortization	87	75.5	172.5	151.4
Taxes, other than income	53.3	48.1	105.1	95.9
Total expenses	537.3	473.7	1,084.1	936.1
Income from operations	143.3	132	289.5	247.6
Other income
Allowance for other funds used during construction	3.7	2	7.5	4.4
Other income, net	1.4	(0.5)	3	(1.4)
Total other income	5.1	1.5	10.5	3
Interest charges
Interest expense	48.2	41.4	98	82.4
Allowance for borrowed funds used during construction	(1.8)	(0.7)	(3.7)	(2.1)
Total interest charges	46.4	40.7	94.3	80.3
Income from continuing operations before provision for income taxes	102	92.8	205.7	170.3
Provision for income taxes	40.5	35.2	80.4	64.3
Net income from continuing operations	61.5	57.6	125.3	106
Discontinued operations
Income (loss) from discontinued operations	(78.1)	0	(87.7)	1.2
Benefit from income taxes	(28.4)	(0.8)	(32.2)	(1.3)
Income (loss) on discontinued operations, net	(49.7)	0.8	(55.5)	2.5
Net income	$ 11.8	$ 58.4	$ 69.8	$ 108.5
Average common shares outstanding - Basic	233	215.4	232.9	215.3
Average common shares outstanding - Diluted	233.6	215.9	233.5	215.8
Earnings per share from continuing operations - Basic	$ 0.26	$ 0.27	$ 0.53	$ 0.49
Earnings per share from continuing operations - Diluted	0.26	0.27	0.53	0.49
Earnings per share from discontinued operations - Basic	(0.21)	0	(0.23)	0.01
Earnings per share from discontinued operations - Diluted	(0.21)	0	(0.23)	0.01
Earnings per share - Basic	0.05	0.27	0.30	0.50
Earnings per share - Diluted	0.05	0.27	0.30	0.50
Dividends paid per common share outstanding	$ 0.225	$ 0.220	$ 0.45	$ 0.44

Consolidated Condensed Stateme5

Consolidated Condensed Statements of Comprehensive Income (Unaudited) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014		Jun. 30, 2015	Jun. 30, 2014
Statement Of Income And Comprehensive Income [Abstract]
Net income		$ 11.8	$ 58.4		$ 69.8	$ 108.5
Other comprehensive income, net of tax
Gain on cash flow hedges		2.8	0.1		3.1	0.3
Amortization of unrecognized benefit costs	[1]	1	0.5		1.6	1
Increase in unrecognized postemployment costs		0	0	[2]	0	(8.2)	[2]
Other comprehensive income (loss), net of tax		3.8	0.6		4.7	(6.9)
Comprehensive income		$ 15.6	$ 59		$ 74.5	$ 101.6
[1]	Related to postretirement and postemployment benefits. See Note 5 for additional information.
[2]	Amounts reflect an out-of-period adjustment related to TECO Coal's unfunded black lung liability.

Consolidated Condensed Stateme6

Consolidated Condensed Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Cash flows from operating activities
Net income	$ 69.8	$ 108.5
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	173.3	169.1
Depreciation and amortization	172.5	151.4
Deferred income taxes and investment tax credits	46.9	61.8
Allowance for other funds used during construction	(7.5)	(4.4)
Non-cash stock compensation	6.9	7.1
Gain on sales of business/assets	0	(0.1)
Deferred recovery clauses	(4.1)	(14.4)
Asset impairment, pretax	78.6	0
Receivables, less allowance for uncollectibles	39.8	(36.6)
Inventories	(37.2)	(16.2)
Prepayments and other current assets	(12.2)	(2.1)
Taxes accrued	19	34.3
Interest accrued	(1.8)	2.5
Accounts payable	(58.3)	(36)
Other	(16.4)	(12.5)
Cash flows from operating activities	296.8	261
Cash flows from investing activities
Capital expenditures	(343.2)	(320.3)
Allowance for other funds used during construction	7.5	4.4
Other investing activities	(0.1)	0.3
Cash flows used in investing activities	(335.8)	(315.6)
Cash flows from financing activities
Dividends	(105.9)	(95.9)
Proceeds from the sale of common stock	3.5	3
Proceeds from long-term debt issuance	500	296.6
Repayment of long-term debt	(274.5)	(83.3)
Net decrease in short-term debt	(53.5)	(84)
Cash flows from financing activities	69.6	36.4
Net increase (decrease) in cash and cash equivalents	30.6	(18.2)
Cash and cash equivalents at beginning of the period	25.4	185.2
Cash and cash equivalents at end of the period	56	167
Supplemental disclosure of non-cash activities
Change in accrued capital expenditures	1.6	8.6
Tampa Electric Company [Member]
Cash flows from operating activities
Net income	138.1	129.5
Adjustments to reconcile net income to net cash from operating activities:
Depreciation and amortization	154.8	150.5
Deferred income taxes and investment tax credits	30	34.8
Allowance for other funds used during construction	(7.5)	(4.4)
Deferred recovery clauses	(3.2)	(14.4)
Receivables, less allowance for uncollectibles	(24.4)	(29.1)
Inventories	(42.1)	(2.6)
Prepayments	(6.2)	(2.8)
Taxes accrued	93.1	100.5
Interest accrued	2	2.2
Accounts payable	(14.3)	(34.3)
Other	(14.9)	(10.6)
Cash flows from operating activities	305.4	319.3
Cash flows from investing activities
Capital expenditures	(319.9)	(312.7)
Allowance for other funds used during construction	7.5	4.4
Net proceeds from sale of assets	0	0.1
Cash flows used in investing activities	(312.4)	(308.2)
Cash flows from financing activities
Dividends	(109.5)	(112)
Proceeds from the sale of common stock	30	17
Proceeds from long-term debt issuance	251.3	296.6
Repayment of long-term debt	(83.3)	(83.3)
Net decrease in short-term debt	(58)	(84)
Cash flows from financing activities	30.5	34.3
Net increase (decrease) in cash and cash equivalents	23.5	45.4
Cash and cash equivalents at beginning of the period	10.4	9.8
Cash and cash equivalents at end of the period	33.9	55.2
Supplemental disclosure of non-cash activities
Change in accrued capital expenditures	$ 1.5	$ 8.6

Consolidated Condensed Stateme7

Consolidated Condensed Statements of Income and Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues
Total revenues	$ 680.6	$ 605.7	$ 1,373.6	$ 1,183.7
Expenses
Fuel	171.8	169.7	315.9	319.3
Purchased power	19.6	19.9	36.7	38.1
Cost of natural gas sold	49.1	29.1	152.1	76.2
Other	155.4	126.8	299.1	247.4
Depreciation and amortization	87	75.5	172.5	151.4
Taxes, other than income	53.3	48.1	105.1	95.9
Total expenses	537.3	473.7	1,084.1	936.1
Income from operations	143.3	132	289.5	247.6
Other income
Allowance for other funds used during construction	3.7	2	7.5	4.4
Other income, net	1.4	(0.5)	3	(1.4)
Total other income	5.1	1.5	10.5	3
Interest charges
Interest on long-term debt	48.2	41.4	98	82.4
Allowance for borrowed funds used during construction	(1.8)	(0.7)	(3.7)	(2.1)
Total interest charges	46.4	40.7	94.3	80.3
Income from continuing operations before provision for income taxes	102	92.8	205.7	170.3
Provision for income taxes	40.5	35.2	80.4	64.3
Net income	11.8	58.4	69.8	108.5
Other comprehensive income, net of tax
Gain on cash flow hedges	2.8	0.1	3.1	0.3
Other comprehensive income (loss), net of tax	3.8	0.6	4.7	(6.9)
Comprehensive income	15.6	59	74.5	101.6
Tampa Electric Company [Member]
Revenues
Electric	532.4	512.7	982.8	965.7
Gas	92.2	90.6	213.9	213.1
Total revenues	624.6	603.3	1,196.7	1,178.8
Expenses
Fuel	171.8	169.7	315.9	319.3
Purchased power	19.6	19.9	36.7	38.1
Cost of natural gas sold	30.1	29	73.4	76.2
Other	134.3	126.8	256.1	247.1
Depreciation and amortization	78	75.1	154.8	150.5
Taxes, other than income	49.5	47.6	97.1	95
Total expenses	483.3	468.1	934	926.2
Income from operations	141.3	135.2	262.7	252.6
Other income
Allowance for other funds used during construction	3.7	2	7.5	4.4
Other income, net	1.2	1.1	2.4	2.3
Total other income	4.9	3.1	9.9	6.7
Interest charges
Interest on long-term debt	27.8	26.4	55.5	52.1
Other interest	1.2	1	2.3	2.1
Allowance for borrowed funds used during construction	(1.8)	(0.7)	(3.6)	(2.1)
Total interest charges	27.2	26.7	54.2	52.1
Income from continuing operations before provision for income taxes	119	111.6	218.4	207.2
Provision for income taxes	43.7	41.9	80.3	77.7
Net income	75.3	69.7	138.1	129.5
Other comprehensive income, net of tax
Gain on cash flow hedges	2.8	0	3.1	0.2
Other comprehensive income (loss), net of tax	2.8	0	3.1	0.2
Comprehensive income	$ 78.1	$ 69.7	$ 141.2	$ 129.7

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 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 June 30, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended June 30, 2015 and 2014. The results of operations for the three and six months ended June 30, 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 June 30, 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 and TECO Guatemala (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 June 30, 2015 and Dec. 31, 2014, unbilled revenues of $66.7 million and $86.6 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets. Accounting for Franchise Fees, Gross Receipt Taxes and Excise Taxes 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 $29.3 million and $56.6 million, respectively, for the three and six months ended June 30, 2015, compared to $27.8 million and $55.0 million, respectively, for the three and six months ended June 30, 2014. 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. 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 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 June 30, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended June 30, 2015 and 2014. The results of operations for the three and six months ended June 30, 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 June 30, 2015 and Dec. 31, 2014, unbilled revenues of $60.3 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 $29.3 million and $56.6 million, respectively, for the three and six months ended June 30, 2015, compared to $27.8 million and $55.0 million, respectively, for the three and six months ended June 30, 2014.

New Accounting Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 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 will be effective for the company beginning in 2018 and will allow 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 will be effective for the company beginning in 2016 and will be required to be applied on a retrospective basis for all periods presented. As of June 30, 2015, $30.5 million of debt issuance costs are included in the “Deferred charges and other assets” line item on the company’s Consolidated Condensed Balance Sheet. Disclosure of Investments Using Net Asset Value In May 2015, the FASB issued guidance stating that investments for which fair value is measured using the NAV per share practical expedient should not be categorized in the fair value hierarchy but should be provided to reconcile to total investments on the balance sheet. In addition, the guidance clarifies that a plan sponsor’s pension assets are eligible to be measured at NAV as a practical expedient and that those investments should also not be categorized in the fair value hierarchy. TECO Energy’s pension plan has such investments as disclosed in Note 5 2014 Annual Report on Form 10-K
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 will be effective for TEC beginning in 2018 and will allow 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 will be effective for TEC beginning in 2016 and will be required to be applied on a retrospective basis for all periods presented. As of June 30, 2015, $18.7 million of debt issuance costs are included in “Deferred debits” on TEC’s Consolidated Condensed Balance Sheet. Disclosure of Investments Using Net Asset Value In May 2015, the FASB issued guidance stating that investments for which fair value is measured using the NAV per share practical expedient should not be categorized in the fair value hierarchy but should be provided to reconcile to total investments on the balance sheet. In addition, the guidance clarifies that a plan sponsor’s pension assets are eligible to be measured at NAV as a practical expedient and that those investments should also not be categorized in the fair value hierarchy. TECO Energy’s pension plan has such investments as disclosed in Note 5 2014 Annual Report on Form 10-K

Regulatory

Regulatory	6 Months Ended
	Jun. 30, 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. 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 requirement) 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 June 30, 2015 and Dec. 31, 2014 are presented in the following table: Regulatory Assets and Liabilities (millions) June 30, 2015 Dec. 31, 2014 Regulatory assets: Regulatory tax asset (1) $ 71.7 $ 69.2 Other: Cost-recovery clauses 27.0 45.1 Postretirement benefit asset (2) 188.8 194.0 Deferred bond refinancing costs (3) 6.8 7.2 Debt basis adjustment (3) 19.2 20.9 Environmental remediation 52.5 53.1 Competitive rate adjustment 2.5 2.8 Other 14.2 9.8 Total other regulatory assets 311.0 332.9 Total regulatory assets 382.7 402.1 Less: Current portion 39.4 53.6 Long-term regulatory assets $ 343.3 $ 348.5 Regulatory liabilities: Regulatory tax liability (1) $ 6.3 $ 6.9 Other: Cost-recovery clauses 20.6 25.9 Transmission and delivery storm reserve 56.1 56.1 Deferred gain on property sales (4) 0.2 0.8 Accumulated reserve - cost of removal 679.1 695.2 Other 0.8 1.1 Total other regulatory liabilities 756.8 779.1 Total regulatory liabilities 763.1 786.0 Less: Current portion 49.9 57.0 Long-term regulatory liabilities $ 713.2 $ 729.0 (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 June 30, Dec. 31, (millions) 2015 2014 Clause recoverable (1) $ 29.5 $ 47.9 Components of rate base (2) 193.8 199.0 Regulatory tax assets (3) 71.7 69.2 Capital structure and other (3) 87.7 86.0 Total $ 382.7 $ 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 or NMPRC, as applicable. (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. 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 requirement) 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 June 30, 2015 and Dec. 31, 2014 are presented in the following table: Regulatory Assets and Liabilities (millions) June 30, 2015 Dec. 31, 2014 Regulatory assets: Regulatory tax asset (1) $ 71.7 $ 69.2 Other: Cost-recovery clauses 27.0 43.6 Postretirement benefit asset (2) 183.1 187.8 Deferred bond refinancing costs (3) 6.8 7.2 Environmental remediation 52.5 53.1 Competitive rate adjustment 2.5 2.8 Other 12.6 8.0 Total other regulatory assets 284.5 302.5 Total regulatory assets 356.2 371.7 Less: Current portion 39.3 52.1 Long-term regulatory assets $ 316.9 $ 319.6 Regulatory liabilities: Regulatory tax liability (1) $ 4.6 $ 5.1 Other: Cost-recovery clauses 20.2 23.5 Transmission and delivery storm reserve 56.1 56.1 Deferred gain on property sales (4) 0.2 0.8 Accumulated reserve - cost of removal 572.3 591.5 Provision for stipulation and other 0.6 1.1 Total other regulatory liabilities 649.4 673.0 Total regulatory liabilities 654.0 678.1 Less: Current portion 49.5 54.7 Long-term regulatory liabilities $ 604.5 $ 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 June 30, Dec. 31, (millions) 2015 2014 Clause recoverable (1) $ 29.5 $ 46.4 Components of rate base (2) 186.5 191.0 Regulatory tax assets (3) 71.7 69.2 Capital structure and other (3) 68.5 65.1 Total $ 356.2 $ 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	6 Months Ended
	Jun. 30, 2015
Income Taxes	4. Income Taxes The effective tax rate increased to 39.09% for the six months ended June 30, 2015 from 37.76% for the same period in 2014 primarily due to tax expense related to long-term incentive compensation shares that vested below target levels. 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 six months ended June 30, 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 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. 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 Benefit

Employee Postretirement Benefits	6 Months Ended
	Jun. 30, 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 June 30, 2015 2014 2015 2014 Components of net periodic benefit expense Service cost $ 6.4 $ 4.2 $ 0.5 $ 0.6 Interest cost 8.7 8.2 2.1 2.6 Expected return on assets (12.5 ) (10.4 ) (0.2 ) 0.0 Amortization of: Prior service (benefit) cost 0.0 (0.1 ) (0.6 ) (0.1 ) Actuarial loss 4.8 3.5 0.0 0.1 Regulatory asset 0.0 0.0 0.2 0.0 Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income $ 7.4 $ 5.4 $ 2.0 $ 3.2 Six months ended June 30, Components of net periodic benefit expense Service cost $ 10.9 $ 8.3 $ 1.1 $ 1.2 Interest cost 16.1 16.4 4.1 5.2 Expected return on assets (23.3 ) (20.7 ) (0.5 ) 0.0 Amortization of: Prior service (benefit) cost (0.1 ) (0.2 ) (1.2 ) (0.1 ) Actuarial loss 8.2 6.7 0.0 0.1 Regulatory asset 0.0 0.0 0.5 0.0 Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income $ 11.8 $ 10.5 $ 4.0 $ 6.4 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 $24.5 million and $26.5 million to its pension plan for the six months ended June 30, 2015 and 2014, respectively. For the three and six months ended June 30, 2015, TECO Energy and its subsidiaries reclassified $1.4 million and $2.2 million, respectively, of pretax unamortized prior service benefit and actuarial losses from AOCI to net income as part of periodic benefit expense, compared with $0.7 million and $1.3 million for the three and six months ended June 30, 2014, respectively. In addition, during the three and six months ended June 30, 2015, the regulated companies reclassified $3.0 million and $5.2 million, respectively, of unamortized prior service benefit and actuarial losses from regulatory assets to net income as part of periodic benefit expense, compared with $2.7 million and $5.2 million during the three and six months ended June 30, 2014, respectively. 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 June 30, 2015 and Dec. 31, 2014, TECO Coal had an actuarially-determined black lung liability of $25.0 million and $24.7 million, respectively. Expense related to the black lung liability recognized during the three and six months ended June 30, 2015 and 2014 was not material. As discussed in Note 15
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 Notes to Consolidated Condensed Financial Statements 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 $24.5 million and $26.5 million to its pension plan in the six months ended June 30, 2015 and 2014, respectively. TEC’s portion of the contributions was $18.5 million and $21.5 million, respectively. Included in the benefit expenses discussed above, for the three and six months ended June 30, 2015, TEC reclassified $2.8 million and $4.7 million, respectively, of prior service benefit and actuarial losses from regulatory assets to net income, compared with $2.7 million and $5.2 million for the three and six months ended June 30, 2014, respectively.

Short-Term Debt

Short-Term Debt	6 Months Ended
	Jun. 30, 2015
Short-Term Debt	6. Short-Term Debt At June 30, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed: Credit Facilities June 30, 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) $ 325.0 $ 0.0 $ 0.6 $ 325.0 $ 12.0 $ 0.6 3-year accounts receivable facility (3) 150.0 0.0 0.0 150.0 46.0 0.0 TECO Energy/TECO Finance: 5-year facility (2)(4) 300.0 75.0 0.0 300.0 50.0 0.0 New Mexico Gas Company: 5-year facility (2) 125.0 10.5 1.7 125.0 31.0 1.7 Total $ 900.0 $ 85.5 $ 2.3 $ 900.0 $ 139.0 $ 2.3 (1) Borrowings outstanding are reported as notes payable. (2) This 5-year facility matures Dec. 17, 2018. (3) Prior to Mar. 24, 2015, this was a 1-year facility. This 3-year facility matures Mar. 23, 2018. (4) TECO Finance is the borrower and TECO Energy is the guarantor of this facility. At June 30, 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 June 30, 2015 and Dec. 31, 2014 was 1.23% 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 (the Loan Agreement). Under the terms of the Loan Agreement, TEC has pledged as collateral a pool of receivables equal to the borrowings outstanding in the case of default. TEC continues to service, administer and collect the pledged receivables, which are classified as receivables on the balance sheet. As of June 30, 2015, TEC was in compliance with the requirements of the agreement.
Tampa Electric Company [Member]
Short-Term Debt	6. Short-Term Debt At June 30, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed: Credit Facilities June 30, 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) $ 325.0 $ 0.0 $ 0.6 $ 325.0 $ 12.0 $ 0.6 3-year accounts receivable facility (3) 150.0 0.0 0.0 150.0 46.0 0.0 Total $ 475.0 $ 0.0 $ 0.6 $ 475.0 $ 58.0 $ 0.6 (1) Borrowings outstanding are reported as notes payable. (2) This 5-year facility matures Dec. 17, 2018. (3) Prior to Mar. 24, 2015, this was a 1-year facility. This 3-year facility matures Mar. 23, 2018. At June 30, 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 June 30, 2015 and Dec. 31, 2014 was 0.6% 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 (the Loan Agreement). Under the terms of the Loan Agreement, TEC has pledged as collateral a pool of receivables equal to the borrowings outstanding in the case of default. TEC continues to service, administer and collect the pledged receivables, which are classified as receivables on the balance sheet. As of June 30, 2015, TEC was in compliance with the requirements of the agreement.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2015
Long-Term Debt	7. Long-Term Debt Fair Value of Long-Term Debt At June 30, 2015, total long-term debt had a carrying amount of $3,851.8 million and an estimated fair market value of $4,136.2 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 TEC 4.20% Notes due 2045 On May 20, 2015, TEC completed an offering of $250 million aggregate principal amount of 4.20% Notes due May 15, 2045 (the Notes). The Notes were sold at 99.814% of par. The offering resulted in net proceeds to TEC (after deducting underwriting discounts, commissions, estimated offering expenses and before settlement of interest rate swaps) of approximately $246.8 million. Net proceeds were used to repay short-term debt and for general corporate purposes. Until Nov. 15, 2044, TEC may redeem all or any part of the Notes at its option at any time and from time to time at a redemption price equal to the greater of (i) 100% of the principal amount of Notes to be redeemed or (ii) the sum of the present value of the remaining payments of principal and interest on the Notes to be redeemed, discounted at an applicable treasury rate (as defined in the indenture), plus 20 basis points; in either case, the redemption price would include accrued and unpaid interest to the redemption date. At any time on or after Nov. 15, 2044, TEC may, at its option, redeem the Notes, in whole or in part, at 100% of the principal amount of the Notes being redeemed plus accrued and unpaid interest thereon to but excluding the date of redemption. 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 used these net proceeds to repay borrowings under the TECO Finance credit facility and to fund a portion of the payment at maturity of $191 million of TECO Finance notes due in May 2015.
Tampa Electric Company [Member]
Long-Term Debt	7. Long-Term Debt Fair Value of Long-Term Debt At June 30, 2015, TEC’s total long-term debt had a carrying amount of $2,263.2 million and an estimated fair market value of $2,479.6 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. Issuance of TEC 4.20% Notes due 2045 On May 20, 2015, TEC completed an offering of $250 million aggregate principal amount of 4.20% Notes due May 15, 2045 (the Notes). The Notes were sold at 99.814% of par. The offering resulted in net proceeds to TEC (after deducting underwriting discounts, commissions, estimated offering expenses and before settlement of interest rate swaps) of approximately $246.8 million. Net proceeds were used to repay short-term debt and for general corporate purposes. Until Nov. 15, 2044, TEC may redeem all or any part of the Notes at its option at any time and from time to time at a redemption price equal to the greater of (i) 100% of the principal amount of Notes to be redeemed or (ii) the sum of the present value of the remaining payments of principal and interest on the Notes to be redeemed, discounted at an applicable treasury rate (as defined in the indenture), plus 20 basis points; in either case, the redemption price would include accrued and unpaid interest to the redemption date. At any time on or after Nov. 15, 2044, TEC may, at its option, redeem the Notes, in whole or in part, at 100% of the principal amount of the Notes being redeemed plus accrued and unpaid interest thereon to but excluding the date of redemption.

Other Comprehensive Income

Other Comprehensive Income	6 Months Ended
	Jun. 30, 2015
Other Comprehensive Income	8. Other Comprehensive Income TECO Energy reported the following OCI for the three and six months ended June 30, 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 June 30, Six months ended June 30, (millions) Gross Tax Net Gross Tax Net 2015 Unrealized gain on cash flow hedges $ 4.0 $ (1.4 ) $ 2.6 $ 4.3 $ (1.5 ) $ 2.8 Reclassification from AOCI to net income (1) 0.3 (0.1 ) 0.2 0.7 (0.4 ) 0.3 Gain on cash flow hedges 4.3 (1.5 ) 2.8 5.0 (1.9 ) 3.1 Amortization of unrecognized benefit costs (2) 1.6 (0.6 ) 1.0 2.5 (0.9 ) 1.6 Total other comprehensive income (loss) $ 5.9 $ (2.1 ) $ 3.8 $ 7.5 $ (2.8 ) $ 4.7 2014 Unrealized gain on cash flow hedges $ 0.1 $ 0.0 $ 0.1 $ 0.0 $ 0.0 $ 0.0 Reclassification from AOCI to net income (1) 0.1 (0.1 ) 0.0 0.5 (0.2 ) 0.3 Gain on cash flow hedges 0.2 (0.1 ) 0.1 0.5 (0.2 ) 0.3 Amortization of unrecognized benefit costs (2) 0.8 (0.3 ) 0.5 1.6 (0.6 ) 1.0 Decrease (increase) in unrecognized postemployment costs (3) 0.0 0.0 0.0 (12.9 ) 4.7 (8.2 ) Total other comprehensive income (loss) $ 1.0 $ (0.4 ) $ 0.6 $ (10.8 ) $ 3.9 $ (6.9 ) (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 (3) Amounts reflect an out-of-period adjustment related to TECO Coal's unfunded black lung liability. Accumulated Other Comprehensive Loss (millions) June 30, 2015 Dec. 31, 2014 Unamortized pension loss and prior service credit (1) $ (21.0 ) $ (22.5 ) Unamortized other benefit gains, prior service costs and transition obligations (2) 14.0 13.9 Net unrealized gains (losses) from cash flow hedges (3) (4.0 ) (7.1 ) Total accumulated other comprehensive loss $ (11.0 ) $ (15.7 ) (1) Net of tax benefit of $12.9 million and $13.8 million as of June 30, 2015 and Dec. 31, 2014, respectively. (2) Net of tax expense of $8.3 million and $8.3 million as of June 30, 2015 and Dec. 31, 2014, respectively. Balance includes a $7.7 million loss as of June 30, 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 $2.5 million and $4.5 million as of June 30, 2015 and Dec. 31, 2014, respectively.
Tampa Electric Company [Member]
Other Comprehensive Income	12. Other Comprehensive Income Other Comprehensive Income Three months ended June 30, Six months ended June 30, (millions) Gross Tax Net Gross Tax Net 2015 Unrealized gain on cash flow hedges $ 4.0 $ (1.4 ) $ 2.6 $ 4.3 $ (1.5 ) $ 2.8 Reclassification from AOCI to net income 0.3 (0.1 ) 0.2 0.7 (0.4 ) 0.3 Gain on cash flow hedges 4.3 (1.5 ) 2.8 5.0 (1.9 ) 3.1 Total other comprehensive income $ 4.3 $ (1.5 ) $ 2.8 $ 5.0 $ (1.9 ) $ 3.1 2014 Unrealized gain on cash flow hedges $ 0.0 $ 0.0 $ 0.0 $ 0.0 $ 0.0 $ 0.0 Reclassification from AOCI to net income 0.0 0.0 0.0 0.4 (0.2 ) 0.2 Gain on cash flow hedges 0.0 0.0 0.0 0.4 (0.2 ) 0.2 Total other comprehensive income $ 0.0 $ 0.0 $ 0.0 $ 0.4 $ (0.2 ) $ 0.2 Accumulated Other Comprehensive Loss (millions) June 30, 2015 Dec. 31, 2014 Net unrealized losses from cash flow hedges (1) $ (4.0 ) $ (7.1 ) Total accumulated other comprehensive loss $ (4.0 ) $ (7.1 ) (1) Net of tax benefit of $2.5 million and $4.5 million as of June 30, 2015 and Dec. 31, 2014, respectively.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
Earnings Per Share	9. Earnings Per Share For the three months ended June 30, For the six months ended June 30, (millions, except per share amounts) 2015 2014 (1) 2015 2014 (1) Basic earnings per share Net income from continuing operations $ 61.5 $ 57.6 $ 125.3 $ 106.0 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Income before discontinued operations available to common shareholders - Basic $ 61.3 $ 57.4 $ 124.9 $ 105.6 Income (loss) from discontinued operations, net $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Amount allocated to nonvested participating shareholders 0.0 0.0 0.0 0.0 Income (loss) from discontinued operations available to common shareholders - Basic $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Net income $ 11.8 $ 58.4 $ 69.8 $ 108.5 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Net income available to common shareholders - Basic $ 11.6 $ 58.2 $ 69.4 $ 108.1 Average common shares outstanding - Basic 233.0 215.4 232.9 215.3 Earnings per share from continuing operations available to common shareholders - Basic $ 0.26 $ 0.27 $ 0.53 $ 0.49 Earnings per share from discontinued operations available to common shareholders - Basic $ (0.21 ) $ 0.0 $ (0.23 ) $ 0.01 Earnings per share available to common shareholders - Basic $ 0.05 $ 0.27 $ 0.30 $ 0.50 Diluted earnings per share Net income from continuing operations $ 61.5 $ 57.6 $ 125.3 $ 106.0 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Income before discontinued operations available to common shareholders - Diluted $ 61.3 $ 57.4 $ 124.9 $ 105.6 Income (loss) from discontinued operations, net $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Amount allocated to nonvested participating shareholders 0.0 0.0 0.0 0.0 Income (loss) from discontinued operations available to common shareholders - Diluted $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Net income $ 11.8 $ 58.4 $ 69.8 $ 108.5 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Net income available to common shareholders - Diluted $ 11.6 $ 58.2 $ 69.4 $ 108.1 Unadjusted average common shares outstanding - Diluted 233.0 215.4 232.9 215.3 Assumed conversion of stock options, unvested restricted stock and contingent performance shares, net 0.6 0.5 0.6 0.5 Average common shares outstanding - Diluted 233.6 215.9 233.5 215.8 Earnings per share from continuing operations available to common shareholders - Diluted $ 0.26 $ 0.27 $ 0.53 $ 0.49 Earnings per share from discontinued operations available to common shareholders - Diluted $ (0.21 ) $ 0.0 $ (0.23 ) $ 0.01 Earnings per share available to common shareholders - Diluted $ 0.05 $ 0.27 $ 0.30 $ 0.50 Anti-dilutive shares 0.4 0.0 0.3 0.0 (1) All prior periods presented reflect the classification of TECO Coal as discontinued operations (see Note 15

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 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 which the company or its subsidiary is a defendant 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 fourteen other defendants alleges, among other things, negligence, strict liability, household exposure, loss of consortium, and wrongful death. This case is scheduled for trial in the fall of 2015. A thirty-three year old man made contact with a primary line in June 2013, suffering severe burns. He and his wife are suing Tampa Electric as a result. The man apparently made contact with the line as he was attempting to trim a tree at a local residence. Plaintiffs' case against Tampa Electric alleges, among other things, negligence and loss of consortium. Discovery is currently ongoing in the case. 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, with a trial currently scheduled for the fourth quarter of 2015. 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. Eighteen insurance carriers have filed two 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 has filed 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 with a decision by the ad hoc committee expected 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 June 30, 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 “Deferred credits and other liabilities” 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 June 30, 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 June 30, 2015 (2) TECO Energy Fuel sales and transportation $ 0.0 $ 0.0 $ 92.9 $ 92.9 $ 0.0 Maximum (millions) After (1) Theoretical Liabilities Recognized Letters of Credit for the Benefit of: 2015 2016-2019 2019 Obligation at June 30, 2015 (3) TEC $ 0.0 $ 0.0 $ 0.6 $ 0.6 $ 0.1 NMGC $ 0.0 $ 0.0 $ 1.7 $ 1.7 $ 0.0 (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 represent the maximum theoretical amounts of cash collateral that TECO Energy would be required to post in the event of a downgrade below investment grade for its long term debt ratings by the major credit rating agencies. Liabilities recognized represent the associated potential obligation related to net derivative liabilities under these agreements at June 30, 2015. See Note 12 (3) 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 June 30, 2015. The obligations under these letters of credit include certain accrued injuries and damages when a letter of credit covers the failure to pay these claims. 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 June 30, 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 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 fourteen other defendants alleges, among other things, negligence, strict liability, household exposure, loss of consortium, and wrongful death. This case is scheduled for trial in the fall of 2015. A thirty-three year old man made contact with a primary line in June 2013, suffering severe burns. He and his wife are suing Tampa Electric as a result. The man apparently made contact with the line as he was attempting to trim a tree at a local residence. Plaintiffs' case against Tampa Electric alleges, among other things, negligence and loss of consortium. Discovery is currently ongoing in the case. 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, with a trial currently scheduled for the fourth quarter of 2015. 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 June 30, 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 “Deferred credits and other liabilities” 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 under TEC’s letters of credit as of June 30, 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 June 30, 2015 TEC (2) $ 0.0 $ 0.0 $ 0.6 $ 0.6 $ 0.1 (1) (2) The amounts shown are the maximum theoretical amounts guaranteed under current agreements. Liabilities recognized represent the associated obligation under these agreements at June 30, 2015. The obligations under these letters of credit include certain accrued injuries and damages when a letter of credit covers the failure to pay these claims. 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 June 30, 2015, TEC was in compliance with all applicable financial covenants.

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 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 June 30, Electric Gas Gas Co. (2) Coal (1) Other (2) (3) Eliminations (3) Energy 2015 Revenues - external $ 531.6 $ 92.2 $ 54.0 $ 0.0 $ 2.8 $ 0.0 $ 680.6 Sales to affiliates 0.8 1.3 0.0 0.0 0.1 (2.2 ) 0.0 Total revenues 532.4 93.5 54.0 0.0 2.9 (2.2 ) 680.6 Depreciation and amortization 64.0 14.0 8.4 0.0 0.6 0.0 87.0 Total interest charges 23.6 3.6 3.3 0.0 16.3 (0.4 ) 46.4 Internally allocated interest 0.0 0.0 0.0 0.0 0.4 (0.4 ) 0.0 Provision (benefit) for income taxes 38.9 4.8 0.0 0.0 (3.2 ) 0.0 40.5 Net income (loss) from continuing operations 67.7 7.6 (0.1 ) 0.0 (13.7 ) 0.0 61.5 Income (loss) from discontinued operations, net (1) 0.0 0.0 0.0 (51.5 ) 1.8 0.0 (49.7 ) Net income (loss) $ 67.7 $ 7.6 $ (0.1 ) $ (51.5 ) $ (11.9 ) $ 0.0 $ 11.8 2014 Revenues - external $ 512.5 $ 90.7 $ 0.0 $ 0.0 $ 2.5 $ 0.0 $ 605.7 Sales to affiliates 0.2 0.4 0.0 0.0 0.1 (0.7 ) 0.0 Total revenues 512.7 91.1 0.0 0.0 2.6 (0.7 ) 605.7 Depreciation and amortization 61.7 13.4 0.0 0.0 0.4 0.0 75.5 Total interest charges 23.3 3.4 0.0 0.0 15.9 (1.9 ) 40.7 Internally allocated interest 0.0 0.0 0.0 0.0 1.9 (1.9 ) 0.0 Provision (benefit) for income taxes 37.1 4.8 0.0 0.0 (6.7 ) 0.0 35.2 Net income (loss) from continuing operations 62.2 7.5 0.0 0.0 (12.1 ) 0.0 57.6 Income (loss) from discontinued operations, net (1) 0.0 0.0 0.0 0.8 0.0 0.0 0.8 Net income (loss) $ 62.2 $ 7.5 $ 0.0 $ 0.8 $ (12.1 ) $ 0.0 58.4 (millions) Tampa Peoples New Mexico TECO TECO Six months ended June 30, Electric Gas Gas Co. (2) Coal (1) Other (2) (3) Eliminations (3) Energy 2015 Revenues - external $ 981.4 $ 213.9 $ 173.0 $ 0.0 $ 5.3 $ 0.0 $ 1,373.6 Sales to affiliates 1.6 2.5 0.0 0.0 0.1 (4.2 ) 0.0 Total revenues 983.0 216.4 173.0 0.0 5.4 (4.2 ) 1,373.6 Depreciation and amortization 126.9 27.9 16.8 0.0 0.9 0.0 172.5 Total interest charges 47.1 7.1 6.6 0.0 34.2 (0.7 ) 94.3 Internally allocated interest 0.0 0.0 0.0 0.0 0.7 (0.7 ) 0.0 Provision (benefit) for income taxes 66.3 14.0 9.0 0.0 (8.9 ) 0.0 80.4 Net income (loss) from continuing operations 115.9 22.2 13.8 0.0 (26.6 ) 0.0 125.3 Income from discontinued operations, net (1) 0.0 0.0 0.0 (57.5 ) 2.0 0.0 (55.5 ) Net income (loss) $ 115.9 $ 22.2 $ 13.8 $ (57.5 ) $ (24.6 ) $ 0.0 $ 69.8 2014 Revenues - external $ 965.4 $ 213.1 $ 0.0 $ 0.0 $ 5.2 $ 0.0 $ 1,183.7 Sales to affiliates 0.5 0.6 0.0 0.0 0.1 (1.2 ) 0.0 Total revenues 965.9 213.7 0.0 0.0 5.3 (1.2 ) 1,183.7 Depreciation and amortization 123.8 26.7 0.0 0.0 0.9 0.0 151.4 Total interest charges 45.3 6.8 0.0 0.0 31.9 (3.7 ) 80.3 Internally allocated interest 0.0 0.0 0.0 0.0 3.7 (3.7 ) 0.0 Provision (benefit) for income taxes 63.7 14.0 0.0 0.0 (13.4 ) 0.0 64.3 Net income (loss) from continuing operations 107.4 22.1 0.0 0.0 (23.5 ) 0.0 106.0 Income (loss) from discontinued operations, net (1) 0.0 0.0 0.0 (0.8 ) 3.3 0.0 2.5 Net income (loss) $ 107.4 $ 22.1 $ 0.0 $ (0.8 ) $ (20.2 ) $ 0.0 $ 108.5 At June 30, 2015 Total assets $ 6,739.5 $ 1,089.2 $ 1,180.2 $ 173.0 $ 1,701.7 $ (2,045.2 ) $ 8,838.4 At Dec. 31, 2014 Total assets $ 6,565.4 $ 1,082.8 $ 1,237.2 $ 227.7 $ 1,611.6 $ (1,998.5 ) 8,726.2 (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 and TECO Guatemala. See Note 15 (2) NMGI is included in the Other segment. (3) Certain prior year amounts have been reclassified to conform to current year presentation.
Tampa Electric Company [Member]
Segment Information	9. Segment Information (millions) Tampa Peoples Tampa Electric Three months ended June 30, Electric Gas Eliminations Company 2015 Revenues - external $ 532.4 $ 92.2 $ 0.0 $ 624.6 Sales to affiliates 0.0 1.3 (1.3 ) 0.0 Total revenues 532.4 93.5 (1.3 ) 624.6 Depreciation and amortization 64.0 14.0 0.0 78.0 Total interest charges 23.6 3.6 0.0 27.2 Provision for income taxes 38.9 4.8 0.0 43.7 Net income 67.7 7.6 0.0 75.3 2014 Revenues - external $ 512.6 $ 90.7 $ 0.0 $ 603.3 Sales to affiliates 0.1 0.4 (0.5 ) 0.0 Total revenues 512.7 91.1 (0.5 ) 603.3 Depreciation and amortization 61.7 13.4 0.0 75.1 Total interest charges 23.3 3.4 0.0 26.7 Provision for income taxes 37.1 4.8 0.0 41.9 Net income $ 62.2 $ 7.5 $ 0.0 $ 69.7 Six months ended June 30, 2015 Revenues - external $ 982.8 $ 213.9 $ 0.0 $ 1,196.7 Sales to affiliates 0.2 2.5 (2.7 ) 0.0 Total revenues 983.0 216.4 (2.7 ) 1,196.7 Depreciation and amortization 126.9 27.9 0.0 154.8 Total interest charges 47.1 7.1 0.0 54.2 Provision for income taxes 66.3 14.0 0.0 80.3 Net income $ 115.9 $ 22.2 $ 0.0 $ 138.1 2014 Revenues - external $ 965.7 $ 213.1 $ 0.0 $ 1,178.8 Sales to affiliates 0.2 0.6 (0.8 ) 0.0 Total revenues 965.9 213.7 (0.8 ) 1,178.8 Depreciation and amortization 123.8 26.7 0.0 150.5 Total interest charges 45.3 6.8 0.0 52.1 Provision for income taxes 63.7 14.0 0.0 77.7 Net income $ 107.4 $ 22.1 $ 0.0 $ 129.5 Total assets at June 30, 2015 $ 6,406.3 $ 1,055.7 $ (5.7 ) $ 7,456.3 Total assets at Dec. 31, 2014 6,234.4 1,047.0 (7.1 ) 7,274.3

Accounting for Derivative Instr

Accounting for Derivative Instruments and Hedging Activities	6 Months Ended
	Jun. 30, 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 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 June 30, 2015, all of the company’s physical contracts qualify for the NPNS exception. The derivatives that are designated as cash flow hedges at June 30, 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 $0.6 million and $0 as of June 30, 2015 and Dec. 31, 2014, respectively, and derivative liabilities totaled $26.3 million and $42.7 million as of June 30, 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 June 30, 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 June 30, 2015, net pretax losses of $23.8 million are expected to be reclassified from regulatory assets or liabilities to the Consolidated Condensed Statements of Income within the next twelve months. The June 30, 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 and six months ended June 30, 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 and six months ended June 30, 2015 and 2014 is presented in Note 8 The maximum length of time over which the company is hedging its exposure to the variability in future cash flows extends to June 30, 2017 for financial natural gas contracts. The following table presents the company’s derivative volumes that, as of June 30, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years: Derivative Volumes Natural Gas Contracts (millions) (MMBTUs) Year Physical Financial 2015 0.0 21.3 2016 0.0 15.7 2017 0.0 1.8 Total 0.0 38.8 The company is exposed to credit risk by 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 June 30, 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 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 June 30, 2015, all of TEC’s physical contracts qualify for the NPNS exception. The derivatives that are designated as cash flow hedges at June 30, 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 as of June 30, 2015 and Dec. 31, 2014, and derivative liabilities totaled $26.3 million and $42.7 million as of June 30, 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 June 30, 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 June 30, 2015, net pretax losses of $24.4 million are expected to be reclassified from regulatory assets or liabilities to the Consolidated Condensed Statements of Income within the next twelve months. The June 30, 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 and six months ended June 30, 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 and six months ended June 30, 2015 and 2014 is presented in Note 12 The maximum length of time over which TEC is hedging its exposure to the variability in future cash flows extends to June 30, 2017 for financial natural gas contracts. The following table presents TEC’s derivative volumes that, as of June 30, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years: Natural Gas Contracts (millions) (MMBTUs) Year Physical Financial 2015 0.0 18.8 2016 0.0 11.3 2017 0.0 1.8 Total 0.0 31.9 TEC is exposed to credit risk by 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 June 30, 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	6 Months Ended
	Jun. 30, 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 (C) Income approach Techniques to convert future amounts to a single present amount based upon market 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 June 30, 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 June 30, 2015 (millions) Level 1 Level 2 Level 3 Total Assets Natural gas derivatives $ 0.0 $ 0.6 $ 0.0 $ 0.6 Liabilities Natural gas derivatives $ 0.0 $ 26.3 $ 0.0 $ 26.3 As of Dec. 31, 2014 (millions) Level 1 Level 2 Level 3 Total Liabilities Natural gas derivatives $ 0.0 $ 42.7 $ 0.0 $ 42.7 The natural gas derivatives are OTC swap and option instruments. Fair values of swaps and options are estimated utilizing the market and income approach, respectively. The price of swaps is calculated using observable NYMEX quoted closing prices of exchange-traded futures. The price of options is calculated using the Black-Scholes model with observable exchange-traded futures as the primary pricing inputs to the model. Additional inputs to the model include historical volatility, discount rate, and a locational basis adjustment to NYMEX. The resulting prices are applied to the notional quantities of active swap and option positions to determine the fair value (see Note 12 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 June 30, 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 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 (C) Income approach Techniques to convert future amounts to a single present amount based upon market 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 June 30, 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 June 30, 2015 (millions) Level 1 Level 2 Level 3 Total Liabilities Natural gas swaps $ 0.0 $ 26.3 $ 0.0 $ 26.3 As of Dec. 31, 2014 (millions) Level 1 Level 2 Level 3 Total Liabilities Natural gas swaps $ 0.0 $ 42.7 $ 0.0 $ 42.7 Natural gas swaps are OTC swap instruments. The fair value of the swaps is estimated utilizing the market approach. The price of swaps is calculated using observable NYMEX quoted closing prices of exchange-traded futures. These prices are applied to the notional quantities of active positions to determine the reported fair value (see Note 10 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 June 30, 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	6 Months Ended
	Jun. 30, 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 159 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 $9.9 million and $15.3 million of capacity pursuant to PPAs for the three and six months ended June 30, 2015, respectively, and $7.0 million and $12.8 million for the three and six months ended June 30, 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 159 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 $9.9 million and $15.3 million of capacity pursuant to PPAs for the three and six months ended June 30, 2015, respectively, and $7.0 million and $12.8 million for the three and six months ended June 30, 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	6 Months Ended
	Jun. 30, 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 actively pursue 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. 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. 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 price per the amended SPA 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. The closing did not occur on June 5, 2015, and the SPA was not terminated by either party. Management continues to be in active discussions with interested parties in an effort to complete the sale. Based on management’s assessment of current market conditions and the discussions with interested parties, an additional impairment charge of $78.6 million pretax was recorded in the second quarter of 2015, which includes the estimated selling costs associated with this transaction. After closing of the sale, which management expects to occur in 2015, TECO Energy will not have influence over operations of TECO Coal, therefore the contingent payments 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) June 30, 2015 Dec. 31, 2014 Current assets $ 96.5 $ 109.6 Property, plant and equipment, net and other long-term assets 0.0 59.8 Total assets held for sale $ 96.5 $ 169.4 Liabilities associated with assets held for sale (millions) June 30, 2015 Dec. 31, 2014 Current liabilities $ 30.2 $ 39.4 Long-term liabilities 66.3 65.4 Total liabilities associated with assets held for sale $ 96.5 $ 104.8 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 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 Six months ended June 30, June 30, (millions) 2015 2014 2015 2014 Revenues—TECO Coal $ 76.1 $ 120.6 $ 148.8 $ 226.7 Income (loss) from operations—TECO Coal 0.5 0.0 (9.0 ) (3.8 ) Loss on impairment—TECO Coal (78.6 ) 0.0 (78.6 ) 0.0 Income (loss) from operations—TECO Guatemala 0.0 0.0 (0.1 ) 5.0 Loss from discontinued operations—TECO Coal (78.1 ) 0.0 (87.6 ) (3.8 ) Income (loss) from discontinued operations—TECO Guatemala 0.0 0.0 (0.1 ) 5.0 Income (loss) from discontinued operations (78.1 ) 0.0 (87.7 ) 1.2 Benefit from income taxes (28.4 ) (0.8 ) (32.2 ) (1.3 ) Income (loss) from discontinued operations, net $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5

Summary of Significant Accoun23

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 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 June 30, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended June 30, 2015 and 2014. The results of operations for the three and six months ended June 30, 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 June 30, 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 and TECO Guatemala (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 As of June 30, 2015 and Dec. 31, 2014, unbilled revenues of $66.7 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 Franchise Fees, Gross Receipt Taxes and Excise Taxes 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 $29.3 million and $56.6 million, respectively, for the three and six months ended June 30, 2015, compared to $27.8 million and $55.0 million, respectively, for the three and six months ended June 30, 2014. 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. 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 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 June 30, 2015 and Dec. 31, 2014, and the results of operations and cash flows for the periods ended June 30, 2015 and 2014. The results of operations for the three and six months ended June 30, 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 As of June 30, 2015 and Dec. 31, 2014, unbilled revenues of $60.3 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 $29.3 million and $56.6 million, respectively, for the three and six months ended June 30, 2015, compared to $27.8 million and $55.0 million, respectively, for the three and six months ended June 30, 2014.

Regulatory (Tables)

Regulatory (Tables)	6 Months Ended
	Jun. 30, 2015
Schedule of Regulatory Assets and Regulatory Liabilities	Details of the regulatory assets and liabilities as of June 30, 2015 and Dec. 31, 2014 are presented in the following table: Regulatory Assets and Liabilities (millions) June 30, 2015 Dec. 31, 2014 Regulatory assets: Regulatory tax asset (1) $ 71.7 $ 69.2 Other: Cost-recovery clauses 27.0 45.1 Postretirement benefit asset (2) 188.8 194.0 Deferred bond refinancing costs (3) 6.8 7.2 Debt basis adjustment (3) 19.2 20.9 Environmental remediation 52.5 53.1 Competitive rate adjustment 2.5 2.8 Other 14.2 9.8 Total other regulatory assets 311.0 332.9 Total regulatory assets 382.7 402.1 Less: Current portion 39.4 53.6 Long-term regulatory assets $ 343.3 $ 348.5 Regulatory liabilities: Regulatory tax liability (1) $ 6.3 $ 6.9 Other: Cost-recovery clauses 20.6 25.9 Transmission and delivery storm reserve 56.1 56.1 Deferred gain on property sales (4) 0.2 0.8 Accumulated reserve - cost of removal 679.1 695.2 Other 0.8 1.1 Total other regulatory liabilities 756.8 779.1 Total regulatory liabilities 763.1 786.0 Less: Current portion 49.9 57.0 Long-term regulatory liabilities $ 713.2 $ 729.0 (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 June 30, Dec. 31, (millions) 2015 2014 Clause recoverable (1) $ 29.5 $ 47.9 Components of rate base (2) 193.8 199.0 Regulatory tax assets (3) 71.7 69.2 Capital structure and other (3) 87.7 86.0 Total $ 382.7 $ 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 or NMPRC, as applicable. (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 June 30, 2015 and Dec. 31, 2014 are presented in the following table: Regulatory Assets and Liabilities (millions) June 30, 2015 Dec. 31, 2014 Regulatory assets: Regulatory tax asset (1) $ 71.7 $ 69.2 Other: Cost-recovery clauses 27.0 43.6 Postretirement benefit asset (2) 183.1 187.8 Deferred bond refinancing costs (3) 6.8 7.2 Environmental remediation 52.5 53.1 Competitive rate adjustment 2.5 2.8 Other 12.6 8.0 Total other regulatory assets 284.5 302.5 Total regulatory assets 356.2 371.7 Less: Current portion 39.3 52.1 Long-term regulatory assets $ 316.9 $ 319.6 Regulatory liabilities: Regulatory tax liability (1) $ 4.6 $ 5.1 Other: Cost-recovery clauses 20.2 23.5 Transmission and delivery storm reserve 56.1 56.1 Deferred gain on property sales (4) 0.2 0.8 Accumulated reserve - cost of removal 572.3 591.5 Provision for stipulation and other 0.6 1.1 Total other regulatory liabilities 649.4 673.0 Total regulatory liabilities 654.0 678.1 Less: Current portion 49.5 54.7 Long-term regulatory liabilities $ 604.5 $ 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 June 30, Dec. 31, (millions) 2015 2014 Clause recoverable (1) $ 29.5 $ 46.4 Components of rate base (2) 186.5 191.0 Regulatory tax assets (3) 71.7 69.2 Capital structure and other (3) 68.5 65.1 Total $ 356.2 $ 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 Benef25

Employee Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2015 2014 2015 2014 Components of net periodic benefit expense Service cost $ 6.4 $ 4.2 $ 0.5 $ 0.6 Interest cost 8.7 8.2 2.1 2.6 Expected return on assets (12.5 ) (10.4 ) (0.2 ) 0.0 Amortization of: Prior service (benefit) cost 0.0 (0.1 ) (0.6 ) (0.1 ) Actuarial loss 4.8 3.5 0.0 0.1 Regulatory asset 0.0 0.0 0.2 0.0 Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income $ 7.4 $ 5.4 $ 2.0 $ 3.2 Six months ended June 30, Components of net periodic benefit expense Service cost $ 10.9 $ 8.3 $ 1.1 $ 1.2 Interest cost 16.1 16.4 4.1 5.2 Expected return on assets (23.3 ) (20.7 ) (0.5 ) 0.0 Amortization of: Prior service (benefit) cost (0.1 ) (0.2 ) (1.2 ) (0.1 ) Actuarial loss 8.2 6.7 0.0 0.1 Regulatory asset 0.0 0.0 0.5 0.0 Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income $ 11.8 $ 10.5 $ 4.0 $ 6.4

Short-Term Debt (Tables)

Short-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2015
Short-Term Debt Credit Facilities	At June 30, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed: Credit Facilities June 30, 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) $ 325.0 $ 0.0 $ 0.6 $ 325.0 $ 12.0 $ 0.6 3-year accounts receivable facility (3) 150.0 0.0 0.0 150.0 46.0 0.0 TECO Energy/TECO Finance: 5-year facility (2)(4) 300.0 75.0 0.0 300.0 50.0 0.0 New Mexico Gas Company: 5-year facility (2) 125.0 10.5 1.7 125.0 31.0 1.7 Total $ 900.0 $ 85.5 $ 2.3 $ 900.0 $ 139.0 $ 2.3 (1) Borrowings outstanding are reported as notes payable. (2) This 5-year facility matures Dec. 17, 2018. (3) Prior to Mar. 24, 2015, this was a 1-year facility. This 3-year facility matures Mar. 23, 2018. (4) TECO Finance is the borrower and TECO Energy is the guarantor of this facility.
Tampa Electric Company [Member]
Short-Term Debt Credit Facilities	At June 30, 2015 and Dec. 31, 2014, the following credit facilities and related borrowings existed: Credit Facilities June 30, 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) $ 325.0 $ 0.0 $ 0.6 $ 325.0 $ 12.0 $ 0.6 3-year accounts receivable facility (3) 150.0 0.0 0.0 150.0 46.0 0.0 Total $ 475.0 $ 0.0 $ 0.6 $ 475.0 $ 58.0 $ 0.6 (1) Borrowings outstanding are reported as notes payable. (2) This 5-year facility matures Dec. 17, 2018. (3) Prior to Mar. 24, 2015, this was a 1-year facility. This 3-year facility matures Mar. 23, 2018.

Other Comprehensive Income (Tab

Other Comprehensive Income (Tables)	6 Months Ended
	Jun. 30, 2015
Other Comprehensive Income	TECO Energy reported the following OCI for the three and six months ended June 30, 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 June 30, Six months ended June 30, (millions) Gross Tax Net Gross Tax Net 2015 Unrealized gain on cash flow hedges $ 4.0 $ (1.4 ) $ 2.6 $ 4.3 $ (1.5 ) $ 2.8 Reclassification from AOCI to net income (1) 0.3 (0.1 ) 0.2 0.7 (0.4 ) 0.3 Gain on cash flow hedges 4.3 (1.5 ) 2.8 5.0 (1.9 ) 3.1 Amortization of unrecognized benefit costs (2) 1.6 (0.6 ) 1.0 2.5 (0.9 ) 1.6 Total other comprehensive income (loss) $ 5.9 $ (2.1 ) $ 3.8 $ 7.5 $ (2.8 ) $ 4.7 2014 Unrealized gain on cash flow hedges $ 0.1 $ 0.0 $ 0.1 $ 0.0 $ 0.0 $ 0.0 Reclassification from AOCI to net income (1) 0.1 (0.1 ) 0.0 0.5 (0.2 ) 0.3 Gain on cash flow hedges 0.2 (0.1 ) 0.1 0.5 (0.2 ) 0.3 Amortization of unrecognized benefit costs (2) 0.8 (0.3 ) 0.5 1.6 (0.6 ) 1.0 Decrease (increase) in unrecognized postemployment costs (3) 0.0 0.0 0.0 (12.9 ) 4.7 (8.2 ) Total other comprehensive income (loss) $ 1.0 $ (0.4 ) $ 0.6 $ (10.8 ) $ 3.9 $ (6.9 ) (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 (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) June 30, 2015 Dec. 31, 2014 Unamortized pension loss and prior service credit (1) $ (21.0 ) $ (22.5 ) Unamortized other benefit gains, prior service costs and transition obligations (2) 14.0 13.9 Net unrealized gains (losses) from cash flow hedges (3) (4.0 ) (7.1 ) Total accumulated other comprehensive loss $ (11.0 ) $ (15.7 ) (1) Net of tax benefit of $12.9 million and $13.8 million as of June 30, 2015 and Dec. 31, 2014, respectively. (2) Net of tax expense of $8.3 million and $8.3 million as of June 30, 2015 and Dec. 31, 2014, respectively. Balance includes a $7.7 million loss as of June 30, 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 $2.5 million and $4.5 million as of June 30, 2015 and Dec. 31, 2014, respectively.
Tampa Electric Company [Member]
Other Comprehensive Income	Other Comprehensive Income Three months ended June 30, Six months ended June 30, (millions) Gross Tax Net Gross Tax Net 2015 Unrealized gain on cash flow hedges $ 4.0 $ (1.4 ) $ 2.6 $ 4.3 $ (1.5 ) $ 2.8 Reclassification from AOCI to net income 0.3 (0.1 ) 0.2 0.7 (0.4 ) 0.3 Gain on cash flow hedges 4.3 (1.5 ) 2.8 5.0 (1.9 ) 3.1 Total other comprehensive income $ 4.3 $ (1.5 ) $ 2.8 $ 5.0 $ (1.9 ) $ 3.1 2014 Unrealized gain on cash flow hedges $ 0.0 $ 0.0 $ 0.0 $ 0.0 $ 0.0 $ 0.0 Reclassification from AOCI to net income 0.0 0.0 0.0 0.4 (0.2 ) 0.2 Gain on cash flow hedges 0.0 0.0 0.0 0.4 (0.2 ) 0.2 Total other comprehensive income $ 0.0 $ 0.0 $ 0.0 $ 0.4 $ (0.2 ) $ 0.2
Accumulated Other Comprehensive Loss	Accumulated Other Comprehensive Loss (millions) June 30, 2015 Dec. 31, 2014 Net unrealized losses from cash flow hedges (1) $ (4.0 ) $ (7.1 ) Total accumulated other comprehensive loss $ (4.0 ) $ (7.1 ) (1) Net of tax benefit of $2.5 million and $4.5 million as of June 30, 2015 and Dec. 31, 2014, respectively.

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
Schedule of Earnings Per Share	For the three months ended June 30, For the six months ended June 30, (millions, except per share amounts) 2015 2014 (1) 2015 2014 (1) Basic earnings per share Net income from continuing operations $ 61.5 $ 57.6 $ 125.3 $ 106.0 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Income before discontinued operations available to common shareholders - Basic $ 61.3 $ 57.4 $ 124.9 $ 105.6 Income (loss) from discontinued operations, net $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Amount allocated to nonvested participating shareholders 0.0 0.0 0.0 0.0 Income (loss) from discontinued operations available to common shareholders - Basic $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Net income $ 11.8 $ 58.4 $ 69.8 $ 108.5 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Net income available to common shareholders - Basic $ 11.6 $ 58.2 $ 69.4 $ 108.1 Average common shares outstanding - Basic 233.0 215.4 232.9 215.3 Earnings per share from continuing operations available to common shareholders - Basic $ 0.26 $ 0.27 $ 0.53 $ 0.49 Earnings per share from discontinued operations available to common shareholders - Basic $ (0.21 ) $ 0.0 $ (0.23 ) $ 0.01 Earnings per share available to common shareholders - Basic $ 0.05 $ 0.27 $ 0.30 $ 0.50 Diluted earnings per share Net income from continuing operations $ 61.5 $ 57.6 $ 125.3 $ 106.0 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Income before discontinued operations available to common shareholders - Diluted $ 61.3 $ 57.4 $ 124.9 $ 105.6 Income (loss) from discontinued operations, net $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Amount allocated to nonvested participating shareholders 0.0 0.0 0.0 0.0 Income (loss) from discontinued operations available to common shareholders - Diluted $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5 Net income $ 11.8 $ 58.4 $ 69.8 $ 108.5 Amount allocated to nonvested participating shareholders (0.2 ) (0.2 ) (0.4 ) (0.4 ) Net income available to common shareholders - Diluted $ 11.6 $ 58.2 $ 69.4 $ 108.1 Unadjusted average common shares outstanding - Diluted 233.0 215.4 232.9 215.3 Assumed conversion of stock options, unvested restricted stock and contingent performance shares, net 0.6 0.5 0.6 0.5 Average common shares outstanding - Diluted 233.6 215.9 233.5 215.8 Earnings per share from continuing operations available to common shareholders - Diluted $ 0.26 $ 0.27 $ 0.53 $ 0.49 Earnings per share from discontinued operations available to common shareholders - Diluted $ (0.21 ) $ 0.0 $ (0.23 ) $ 0.01 Earnings per share available to common shareholders - Diluted $ 0.05 $ 0.27 $ 0.30 $ 0.50 Anti-dilutive shares 0.4 0.0 0.3 0.0 (1) All prior periods presented reflect the classification of TECO Coal as discontinued operations (see Note 15

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 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 June 30, 2015 (2) TECO Energy Fuel sales and transportation $ 0.0 $ 0.0 $ 92.9 $ 92.9 $ 0.0 Maximum (millions) After (1) Theoretical Liabilities Recognized Letters of Credit for the Benefit of: 2015 2016-2019 2019 Obligation at June 30, 2015 (3) TEC $ 0.0 $ 0.0 $ 0.6 $ 0.6 $ 0.1 NMGC $ 0.0 $ 0.0 $ 1.7 $ 1.7 $ 0.0 (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 represent the maximum theoretical amounts of cash collateral that TECO Energy would be required to post in the event of a downgrade below investment grade for its long term debt ratings by the major credit rating agencies. Liabilities recognized represent the associated potential obligation related to net derivative liabilities under these agreements at June 30, 2015. See Note 12 (3) 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 June 30, 2015. The obligations under these letters of credit include certain accrued injuries and damages when a letter of credit covers the failure to pay these claims.
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 June 30, 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 June 30, 2015 TEC (2) $ 0.0 $ 0.0 $ 0.6 $ 0.6 $ 0.1 (1) (2) The amounts shown are the maximum theoretical amounts guaranteed under current agreements. Liabilities recognized represent the associated obligation under these agreements at June 30, 2015. The obligations under these letters of credit include certain accrued injuries and damages when a letter of credit covers the failure to pay these claims.

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2015
Schedule of Segment Information	Segment Information (1) (millions) Tampa Peoples New Mexico TECO TECO Three months ended June 30, Electric Gas Gas Co. (2) Coal (1) Other (2) (3) Eliminations (3) Energy 2015 Revenues - external $ 531.6 $ 92.2 $ 54.0 $ 0.0 $ 2.8 $ 0.0 $ 680.6 Sales to affiliates 0.8 1.3 0.0 0.0 0.1 (2.2 ) 0.0 Total revenues 532.4 93.5 54.0 0.0 2.9 (2.2 ) 680.6 Depreciation and amortization 64.0 14.0 8.4 0.0 0.6 0.0 87.0 Total interest charges 23.6 3.6 3.3 0.0 16.3 (0.4 ) 46.4 Internally allocated interest 0.0 0.0 0.0 0.0 0.4 (0.4 ) 0.0 Provision (benefit) for income taxes 38.9 4.8 0.0 0.0 (3.2 ) 0.0 40.5 Net income (loss) from continuing operations 67.7 7.6 (0.1 ) 0.0 (13.7 ) 0.0 61.5 Income (loss) from discontinued operations, net (1) 0.0 0.0 0.0 (51.5 ) 1.8 0.0 (49.7 ) Net income (loss) $ 67.7 $ 7.6 $ (0.1 ) $ (51.5 ) $ (11.9 ) $ 0.0 $ 11.8 2014 Revenues - external $ 512.5 $ 90.7 $ 0.0 $ 0.0 $ 2.5 $ 0.0 $ 605.7 Sales to affiliates 0.2 0.4 0.0 0.0 0.1 (0.7 ) 0.0 Total revenues 512.7 91.1 0.0 0.0 2.6 (0.7 ) 605.7 Depreciation and amortization 61.7 13.4 0.0 0.0 0.4 0.0 75.5 Total interest charges 23.3 3.4 0.0 0.0 15.9 (1.9 ) 40.7 Internally allocated interest 0.0 0.0 0.0 0.0 1.9 (1.9 ) 0.0 Provision (benefit) for income taxes 37.1 4.8 0.0 0.0 (6.7 ) 0.0 35.2 Net income (loss) from continuing operations 62.2 7.5 0.0 0.0 (12.1 ) 0.0 57.6 Income (loss) from discontinued operations, net (1) 0.0 0.0 0.0 0.8 0.0 0.0 0.8 Net income (loss) $ 62.2 $ 7.5 $ 0.0 $ 0.8 $ (12.1 ) $ 0.0 58.4 (millions) Tampa Peoples New Mexico TECO TECO Six months ended June 30, Electric Gas Gas Co. (2) Coal (1) Other (2) (3) Eliminations (3) Energy 2015 Revenues - external $ 981.4 $ 213.9 $ 173.0 $ 0.0 $ 5.3 $ 0.0 $ 1,373.6 Sales to affiliates 1.6 2.5 0.0 0.0 0.1 (4.2 ) 0.0 Total revenues 983.0 216.4 173.0 0.0 5.4 (4.2 ) 1,373.6 Depreciation and amortization 126.9 27.9 16.8 0.0 0.9 0.0 172.5 Total interest charges 47.1 7.1 6.6 0.0 34.2 (0.7 ) 94.3 Internally allocated interest 0.0 0.0 0.0 0.0 0.7 (0.7 ) 0.0 Provision (benefit) for income taxes 66.3 14.0 9.0 0.0 (8.9 ) 0.0 80.4 Net income (loss) from continuing operations 115.9 22.2 13.8 0.0 (26.6 ) 0.0 125.3 Income from discontinued operations, net (1) 0.0 0.0 0.0 (57.5 ) 2.0 0.0 (55.5 ) Net income (loss) $ 115.9 $ 22.2 $ 13.8 $ (57.5 ) $ (24.6 ) $ 0.0 $ 69.8 2014 Revenues - external $ 965.4 $ 213.1 $ 0.0 $ 0.0 $ 5.2 $ 0.0 $ 1,183.7 Sales to affiliates 0.5 0.6 0.0 0.0 0.1 (1.2 ) 0.0 Total revenues 965.9 213.7 0.0 0.0 5.3 (1.2 ) 1,183.7 Depreciation and amortization 123.8 26.7 0.0 0.0 0.9 0.0 151.4 Total interest charges 45.3 6.8 0.0 0.0 31.9 (3.7 ) 80.3 Internally allocated interest 0.0 0.0 0.0 0.0 3.7 (3.7 ) 0.0 Provision (benefit) for income taxes 63.7 14.0 0.0 0.0 (13.4 ) 0.0 64.3 Net income (loss) from continuing operations 107.4 22.1 0.0 0.0 (23.5 ) 0.0 106.0 Income (loss) from discontinued operations, net (1) 0.0 0.0 0.0 (0.8 ) 3.3 0.0 2.5 Net income (loss) $ 107.4 $ 22.1 $ 0.0 $ (0.8 ) $ (20.2 ) $ 0.0 $ 108.5 At June 30, 2015 Total assets $ 6,739.5 $ 1,089.2 $ 1,180.2 $ 173.0 $ 1,701.7 $ (2,045.2 ) $ 8,838.4 At Dec. 31, 2014 Total assets $ 6,565.4 $ 1,082.8 $ 1,237.2 $ 227.7 $ 1,611.6 $ (1,998.5 ) 8,726.2 (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 and TECO Guatemala. See Note 15 (2) NMGI is included in the Other segment. (3) Certain prior year amounts have been reclassified to conform to current year presentation.
Tampa Electric Company [Member]
Schedule of Segment Information	(millions) Tampa Peoples Tampa Electric Three months ended June 30, Electric Gas Eliminations Company 2015 Revenues - external $ 532.4 $ 92.2 $ 0.0 $ 624.6 Sales to affiliates 0.0 1.3 (1.3 ) 0.0 Total revenues 532.4 93.5 (1.3 ) 624.6 Depreciation and amortization 64.0 14.0 0.0 78.0 Total interest charges 23.6 3.6 0.0 27.2 Provision for income taxes 38.9 4.8 0.0 43.7 Net income 67.7 7.6 0.0 75.3 2014 Revenues - external $ 512.6 $ 90.7 $ 0.0 $ 603.3 Sales to affiliates 0.1 0.4 (0.5 ) 0.0 Total revenues 512.7 91.1 (0.5 ) 603.3 Depreciation and amortization 61.7 13.4 0.0 75.1 Total interest charges 23.3 3.4 0.0 26.7 Provision for income taxes 37.1 4.8 0.0 41.9 Net income $ 62.2 $ 7.5 $ 0.0 $ 69.7 Six months ended June 30, 2015 Revenues - external $ 982.8 $ 213.9 $ 0.0 $ 1,196.7 Sales to affiliates 0.2 2.5 (2.7 ) 0.0 Total revenues 983.0 216.4 (2.7 ) 1,196.7 Depreciation and amortization 126.9 27.9 0.0 154.8 Total interest charges 47.1 7.1 0.0 54.2 Provision for income taxes 66.3 14.0 0.0 80.3 Net income $ 115.9 $ 22.2 $ 0.0 $ 138.1 2014 Revenues - external $ 965.7 $ 213.1 $ 0.0 $ 1,178.8 Sales to affiliates 0.2 0.6 (0.8 ) 0.0 Total revenues 965.9 213.7 (0.8 ) 1,178.8 Depreciation and amortization 123.8 26.7 0.0 150.5 Total interest charges 45.3 6.8 0.0 52.1 Provision for income taxes 63.7 14.0 0.0 77.7 Net income $ 107.4 $ 22.1 $ 0.0 $ 129.5 Total assets at June 30, 2015 $ 6,406.3 $ 1,055.7 $ (5.7 ) $ 7,456.3 Total assets at Dec. 31, 2014 6,234.4 1,047.0 (7.1 ) 7,274.3

Accounting for Derivative Ins31

Accounting for Derivative Instruments and Hedging Activities (Tables)	6 Months Ended
	Jun. 30, 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 June 30, 2017 for financial natural gas contracts. The following table presents the company’s derivative volumes that, as of June 30, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years: Derivative Volumes Natural Gas Contracts (millions) (MMBTUs) Year Physical Financial 2015 0.0 21.3 2016 0.0 15.7 2017 0.0 1.8 Total 0.0 38.8
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 June 30, 2017 for financial natural gas contracts. The following table presents TEC’s derivative volumes that, as of June 30, 2015, are expected to settle during the 2015, 2016 and 2017 fiscal years: Natural Gas Contracts (millions) (MMBTUs) Year Physical Financial 2015 0.0 18.8 2016 0.0 11.3 2017 0.0 1.8 Total 0.0 31.9

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2015
Schedule of Recurring Fair Value Measurements	Recurring Fair Value Measures As of June 30, 2015 (millions) Level 1 Level 2 Level 3 Total Assets Natural gas derivatives $ 0.0 $ 0.6 $ 0.0 $ 0.6 Liabilities Natural gas derivatives $ 0.0 $ 26.3 $ 0.0 $ 26.3 As of Dec. 31, 2014 (millions) Level 1 Level 2 Level 3 Total Liabilities Natural gas derivatives $ 0.0 $ 42.7 $ 0.0 $ 42.7
Tampa Electric Company [Member]
Schedule of Recurring Fair Value Measurements	Recurring Derivative Fair Value Measures As of June 30, 2015 (millions) Level 1 Level 2 Level 3 Total Liabilities Natural gas swaps $ 0.0 $ 26.3 $ 0.0 $ 26.3 As of Dec. 31, 2014 (millions) Level 1 Level 2 Level 3 Total Liabilities Natural gas swaps $ 0.0 $ 42.7 $ 0.0 $ 42.7

Discontinued Operations, Asse33

Discontinued Operations, Assets Held for Sale and Asset Impairments (Tables)	6 Months Ended
	Jun. 30, 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) June 30, 2015 Dec. 31, 2014 Current assets $ 96.5 $ 109.6 Property, plant and equipment, net and other long-term assets 0.0 59.8 Total assets held for sale $ 96.5 $ 169.4 Liabilities associated with assets held for sale (millions) June 30, 2015 Dec. 31, 2014 Current liabilities $ 30.2 $ 39.4 Long-term liabilities 66.3 65.4 Total liabilities associated with assets held for sale $ 96.5 $ 104.8
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 Six months ended June 30, June 30, (millions) 2015 2014 2015 2014 Revenues—TECO Coal $ 76.1 $ 120.6 $ 148.8 $ 226.7 Income (loss) from operations—TECO Coal 0.5 0.0 (9.0 ) (3.8 ) Loss on impairment—TECO Coal (78.6 ) 0.0 (78.6 ) 0.0 Income (loss) from operations—TECO Guatemala 0.0 0.0 (0.1 ) 5.0 Loss from discontinued operations—TECO Coal (78.1 ) 0.0 (87.6 ) (3.8 ) Income (loss) from discontinued operations—TECO Guatemala 0.0 0.0 (0.1 ) 5.0 Income (loss) from discontinued operations (78.1 ) 0.0 (87.7 ) 1.2 Benefit from income taxes (28.4 ) (0.8 ) (32.2 ) (1.3 ) Income (loss) from discontinued operations, net $ (49.7 ) $ 0.8 $ (55.5 ) $ 2.5

Summary of Significant Accoun34

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Summary Of Significant Accounting Policies [Line Items]
Unbilled revenues	$ 66.7		$ 66.7		$ 86.6
Franchise fees and gross receipts taxes	29.3	$ 27.8	56.6	$ 55
Tampa Electric Company [Member]
Summary Of Significant Accounting Policies [Line Items]
Unbilled revenues	60.3		60.3		$ 49.3
Franchise fees and gross receipts taxes	$ 29.3	$ 27.8	$ 56.6	$ 55

New Accounting Pronouncements -

New Accounting Pronouncements - Additional Information (Detail) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Tampa Electric Company [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Debt issuance cost	$ 18.7	$ 16.8
Deferred Charges And Other Assets [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Debt issuance cost	30.5
Deferred Charges And Other Assets [Member] | Tampa Electric Company [Member]
New Accounting Pronouncements Or Change In Accounting Principle [Line Items]
Debt issuance cost	$ 18.7

Regulatory - Schedule of Regula

Regulatory - Schedule of Regulatory Assets and Regulatory Liabilities (Detail) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Regulatory assets:
Regulatory assets	$ 382.7	$ 402.1
Less: Current portion	39.4	53.6
Long-term regulatory assets	343.3	348.5
Regulatory liabilities:
Regulatory liabilities	763.1	786
Less: Current portion	49.9	57
Long-term regulatory liabilities	713.2	729
Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	356.2	371.7
Less: Current portion	39.3	52.1
Long-term regulatory assets	316.9	319.6
Regulatory liabilities:
Regulatory liabilities	654	678.1
Less: Current portion	49.5	54.7
Long-term regulatory liabilities	604.5	623.4
Regulatory Tax Asset [Member]
Regulatory assets:
Regulatory assets	71.7	69.2
Regulatory Tax Asset [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	71.7	69.2
Cost-Recovery Clauses [Member]
Regulatory assets:
Regulatory assets	27	45.1
Cost-Recovery Clauses [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	27	43.6
Postretirement Benefit Asset [Member]
Regulatory assets:
Regulatory assets	188.8	194
Postretirement Benefit Asset [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	183.1	187.8
Deferred Bond Refinancing Costs [Member]
Regulatory assets:
Regulatory assets	6.8	7.2
Deferred Bond Refinancing Costs [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	6.8	7.2
Debt Basis Adjustment [Member]
Regulatory assets:
Regulatory assets	19.2	20.9
Environmental Remediation [Member]
Regulatory assets:
Regulatory assets	52.5	53.1
Environmental Remediation [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	52.5	53.1
Competitive Rate Adjustment [Member]
Regulatory assets:
Regulatory assets	2.5	2.8
Competitive Rate Adjustment [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	2.5	2.8
Other [Member]
Regulatory assets:
Regulatory assets	14.2	9.8
Other [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	12.6	8
Total Other Regulatory Assets [Member]
Regulatory assets:
Regulatory assets	311	332.9
Total Other Regulatory Assets [Member] | Tampa Electric Company [Member]
Regulatory assets:
Regulatory assets	284.5	302.5
Regulatory Tax Liability [Member]
Regulatory liabilities:
Regulatory liabilities	6.3	6.9
Regulatory Tax Liability [Member] | Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	4.6	5.1
Cost-Recovery Clauses [Member]
Regulatory liabilities:
Regulatory liabilities	20.6	25.9
Cost-Recovery Clauses [Member] | Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	20.2	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	0.2	0.8
Deferred Gain on Property Sales [Member] | Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	0.2	0.8
Accumulated Reserve - Cost of Removal [Member]
Regulatory liabilities:
Regulatory liabilities	679.1	695.2
Accumulated Reserve - Cost of Removal [Member] | Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	572.3	591.5
Other [Member]
Regulatory liabilities:
Regulatory liabilities	0.8	1.1
Other [Member] | Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	0.6	1.1
Total Other Regulatory Liabilities [Member]
Regulatory liabilities:
Regulatory liabilities	756.8	779.1
Total Other Regulatory Liabilities [Member] | Tampa Electric Company [Member]
Regulatory liabilities:
Regulatory liabilities	$ 649.4	$ 673

Regulatory - Schedule of Regu37

Regulatory - Schedule of Regulatory Assets and Regulatory Liabilities (Parenthetical) (Detail)	6 Months Ended
	Jun. 30, 2015
Schedule Of Regulatory Assets And Liabilities [Line Items]
Amortization period	5 years
Tampa Electric Company [Member]
Schedule Of Regulatory Assets And Liabilities [Line Items]
Amortization period	5 years

Regulatory - Regulatory Assets

Regulatory - Regulatory Assets and Related Recovery Periods (Detail) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Regulatory Asset [Line Items]
Regulatory assets	$ 382.7	$ 402.1
Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	356.2	371.7
Components of Rate Base [Member]
Regulatory Asset [Line Items]
Regulatory assets	193.8	199
Components of Rate Base [Member] | Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	186.5	191
Clause Recoverable [Member]
Regulatory Asset [Line Items]
Regulatory assets	29.5	47.9
Clause Recoverable [Member] | Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	29.5	46.4
Regulatory Tax Asset [Member]
Regulatory Asset [Line Items]
Regulatory assets	71.7	69.2
Regulatory Tax Asset [Member] | Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	71.7	69.2
Capital Structure and Other [Member]
Regulatory Asset [Line Items]
Regulatory assets	87.7	86
Capital Structure and Other [Member] | Tampa Electric Company [Member]
Regulatory Asset [Line Items]
Regulatory assets	$ 68.5	$ 65.1

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Income Taxes [Line Items]
Effective tax rate	39.09%	37.76%
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 Benef40

Employee Postretirement Benefits - Schedule of Net Periodic Benefit Cost (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 6.4	$ 4.2	$ 10.9	$ 8.3
Interest cost	8.7	8.2	16.1	16.4
Expected return on assets	(12.5)	(10.4)	(23.3)	(20.7)
Amortization of:
Prior service (benefit) cost	0	(0.1)	(0.1)	(0.2)
Actuarial loss	4.8	3.5	8.2	6.7
Regulatory asset	0	0	0	0
Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income	7.4	5.4	11.8	10.5
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0.5	0.6	1.1	1.2
Interest cost	2.1	2.6	4.1	5.2
Expected return on assets	(0.2)	0	(0.5)	0
Amortization of:
Prior service (benefit) cost	(0.6)	(0.1)	(1.2)	(0.1)
Actuarial loss	0	0.1	0	0.1
Regulatory asset	0.2	0	0.5	0
Net pension expense recognized in the TECO Energy Consolidated Condensed Statements of Income	$ 2	$ 3.2	$ 4	$ 6.4

Employee Postretirement Benef41

Employee Postretirement Benefits - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Jan. 01, 2015	Dec. 31, 2014
Defined Benefit Plan Disclosure [Line Items]
Reclassification of AOCI to net income as part of periodic benefit expense	$ 1.4		$ 2.2
Reclassification of regulatory assets to net income as part of periodic benefit expense	3	$ 2.7	5.2	$ 5.2
Accumulated Other Comprehensive Income Defined Benefit Plans Amortization Period Increase Decrease		0.7		1.3
TECO Coal [Member]
Defined Benefit Plan Disclosure [Line Items]
Black lung liability	25		25			$ 24.7
Expenses related to black lung liability	$ 0	0	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%
Reclassification of regulatory assets to net income as part of periodic benefit expense	$ 2.8	2.7	$ 4.7	5.2
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term EROA			7.00%
Discount rate	4.256%		4.256%
Employer contributions			$ 24.5	26.5
Net pension expense	$ 7.4	5.4	$ 11.8	10.5
Pension Benefits [Member] | Tampa Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate	4.256%		4.256%
Employer contributions			$ 18.5	21.5
Net pension expense	$ 4.2	3.9	6.8	7.7
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate					4.206%
Net pension expense	2	3.2	4	6.4
Other Postretirement Benefits [Member] | Tampa Electric Company [Member]
Defined Benefit Plan Disclosure [Line Items]
Discount rate					4.206%
Net pension expense	$ 1.5	$ 2.6	$ 2.9	$ 5.2

Short-Term Debt - Credit Facili

Short-Term Debt - Credit Facilities (Detail) - USD ($)	Jun. 30, 2015	Dec. 31, 2014
Line Of Credit Facility [Line Items]
Credit Facilities	$ 900,000,000	$ 900,000,000
Borrowings Outstanding	85,500,000	139,000,000
Letters of Credit Outstanding	2,300,000	2,300,000
Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	475,000,000	475,000,000
Borrowings Outstanding	0	58,000,000
Letters of Credit Outstanding	600,000	600,000
Tampa Electric Company [Member] | 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	325,000,000	325,000,000
Borrowings Outstanding	0	12,000,000
Letters of Credit Outstanding	600,000	600,000
Tampa Electric Company [Member] | 3-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	150,000,000	150,000,000
Borrowings Outstanding	0	46,000,000
Letters of Credit Outstanding	0	0
TECO Energy [Member] | 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	300,000,000	300,000,000
Borrowings Outstanding	75,000,000	50,000,000
Letters of Credit Outstanding	0	0
New Mexico Gas Company [Member] | 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	125,000,000	125,000,000
Borrowings Outstanding	10,500,000	31,000,000
Letters of Credit Outstanding	$ 1,700,000	$ 1,700,000

Short-Term Debt - Credit Faci43

Short-Term Debt - Credit Facilities (Parenthetical) (Detail)	6 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Tampa Electric Company [Member] | 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Dec. 17, 2018	Dec. 17, 2018
Tampa Electric Company [Member] | 3-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Mar. 23, 2018	Mar. 23, 2018
TECO Energy [Member] | 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Dec. 17, 2018	Dec. 17, 2018
New Mexico Gas Company [Member] | 5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Dec. 17, 2018	Dec. 17, 2018

Short-Term Debt - Additional In

Short-Term Debt - Additional Information (Detail) - USD ($)	Mar. 24, 2015	Jun. 30, 2015	Dec. 31, 2014
Line Of Credit Facility [Line Items]
Line of Credit Facility maximum borrowing capacity		$ 900,000,000	$ 900,000,000
Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate		0.60%	0.70%
Line of Credit Facility maximum borrowing capacity		$ 475,000,000	$ 475,000,000
Tampa Electric Company [Member] | 1-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Line of Credit Facility maximum borrowing capacity		$ 150,000,000
Credit facility maturity date	Mar. 23, 2018
Credit Facility amendment date	Mar. 24, 2015
Tampa Electric Company [Member] | 1-year Accounts Receivable Facility [Member] | Before Amendment and Restatement
Line Of Credit Facility [Line Items]
Credit facility maturity date	Apr. 14, 2015
TECO Energy [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate		1.23%	1.16%
TECO Finance [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate		1.23%	1.16%
New Mexico Gas Company [Member]
Line Of Credit Facility [Line Items]
Weighted-average interest rate		1.23%	1.16%
Minimum [Member] | Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Commitment fees, percentage		0.125%
Maximum [Member] | Tampa Electric Company [Member]
Line Of Credit Facility [Line Items]
Commitment fees, percentage		0.30%

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Millions	May. 20, 2015	Apr. 10, 2015	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Long-term debt, carrying amount			$ 3,851.8	$ 3,628.5
Estimated fair value			4,136.2	3,987.8
Tampa Electric Company [Member]
Debt Instrument [Line Items]
Long-term debt, carrying amount			2,263.2	2,097.1
Estimated fair value			$ 2,479.6	$ 2,372.2
TECO Finance [Member] | Floating Rate Notes Due 2018 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued		$ 250
Net proceeds from offering		$ 248.6
Debt instrument, offering date		Apr. 10, 2015
Basis spread on federal funds rate		0.60%
Debt instrument maturity date		Apr. 10, 2018
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.
TECO Finance [Member] | Notes Due in May 2015 [Member]
Debt Instrument [Line Items]
Payment of notes		$ 191
The Notes | Tampa Electric Company [Member] | 4.20% Notes Due 2045 [Member]
Debt Instrument [Line Items]
Aggregate principal amount issued	$ 250
Interest at the initial term rate per annum	4.20%
Debt instrument principal amount market price percentage	99.814%
Net proceeds from offering	$ 246.8
Redeemable principal amount percentage	100.00%
Debt instrument, offering date	May 20, 2015
Debt instrument, start date of redemption	Nov. 15, 2044
Debt instrument, maturity year	2,045
Redeemable principal amount percentage	100.00%
Basis spread on federal funds rate	0.20%
Debt instrument maturity date	May 15, 2045

Other Comprehensive Income - Ac

Other Comprehensive Income - Accumulated Other Comprehensive Loss (Income) (Detail) - USD ($) $ in Millions		3 Months Ended			6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014		Jun. 30, 2015	Jun. 30, 2014		Dec. 31, 2014
Other Comprehensive Income Loss [Line Items]
Unrealized gain on cash flow hedges, Gross		$ 4	$ 0.1		$ 4.3	$ 0
Reclassification from AOCI to net income, Gross	[1]	0.3	0.1		0.7	0.5
Gain on cash flow hedges, Gross		4.3	0.2		5	0.5
Amortization of unrecognized benefit costs, Gross	[2]	1.6	0.8		2.5	1.6
Decrease (increase) in unrecognized postemployment costs, Gross	[3]		0			(12.9)
Total other comprehensive income (loss), Gross		5.9	1		7.5	(10.8)
Unrealized gain on cash flow hedges, Tax		(1.4)	0		(1.5)	0
Reclassification from AOCI to net income, Tax	[1]	(0.1)	(0.1)		(0.4)	(0.2)
Gain on cash flow hedges, Tax		(1.5)	(0.1)		(1.9)	(0.2)
Amortization of unrecognized benefit costs, Tax	[2]	(0.6)	(0.3)		(0.9)	(0.6)
Decrease (increase) in unrecognized postemployment costs, Tax	[3]		0			4.7
Total other comprehensive income (loss), Tax		(2.1)	(0.4)		(2.8)	3.9
Unrealized gain on cash flow hedges, Net		2.6	0.1		2.8	0
Reclassification from AOCI to net income, Net	[1]	0.2	0		0.3	0.3
Gain on cash flow hedges, Net		2.8	0.1		3.1	0.3
Amortization of unrecognized benefit costs, Net	[2]	1	0.5		1.6	1
Increase in unrecognized postemployment costs		0	0	[3]	0	(8.2)	[3]
Other comprehensive income (loss), net of tax		3.8	0.6		4.7	(6.9)
Unamortized pension loss and prior service credit	[4]	(21)			(21)			$ (22.5)
Unamortized other benefit gains, prior service costs and transition obligations	[5]	14			14			13.9
Net unrealized gains (losses) from cash flow hedges	[6]	(4)			(4)			(7.1)
Total accumulated other comprehensive loss		(11)			(11)			(15.7)
Tampa Electric Company [Member]
Other Comprehensive Income Loss [Line Items]
Unrealized gain on cash flow hedges, Gross		4	0		4.3	0
Reclassification from AOCI to net income, Gross		0.3	0		0.7	0.4
Gain on cash flow hedges, Gross		4.3	0		5	0.4
Total other comprehensive income (loss), Gross		4.3	0		5	0.4
Unrealized gain on cash flow hedges, Tax		(1.4)	0		(1.5)	0
Reclassification from AOCI to net income, Tax		(0.1)	0		(0.4)	(0.2)
Gain on cash flow hedges, Tax		(1.5)	0		(1.9)	(0.2)
Total other comprehensive income (loss), Tax		(1.5)	0		(1.9)	(0.2)
Unrealized gain on cash flow hedges, Net		2.6	0		2.8	0
Reclassification from AOCI to net income, Net		0.2	0		0.3	0.2
Gain on cash flow hedges, Net		2.8	0		3.1	0.2
Other comprehensive income (loss), net of tax		2.8	$ 0		3.1	$ 0.2
Net unrealized gains (losses) from cash flow hedges	[6]	(4)			(4)			(7.1)
Total accumulated other comprehensive loss		$ (4)			$ (4)			$ (7.1)
[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 $12.9 million and $13.8 million as of June 30, 2015 and Dec. 31, 2014, respectively.
[5]	Net of tax expense of $8.3 million and $8.3 million as of June 30, 2015 and Dec. 31, 2014, respectively. Balance includes a $7.7 million loss as of June 30, 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.
[6]	Net of tax benefit of $2.5 million and $4.5 million as of June 30, 2015 and Dec. 31, 2014, respectively.

Other Comprehensive Income - 47

Other Comprehensive Income - Accumulated Other Comprehensive Loss (Parenthetical) (Detail) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Accumulated Other Comprehensive Income Loss [Line Items]
Net income discontinued operations settlement	$ 7.7
Net unrealized losses from cash flow hedges, tax benefit	2.5	$ 4.5
Tampa Electric Company [Member]
Accumulated Other Comprehensive Income Loss [Line Items]
Net unrealized losses from cash flow hedges, tax benefit	2.5	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)	12.9	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)	$ 8.3	$ 8.3

Earnings Per Share - Schedule o

Earnings Per Share - Schedule of Earnings Per Share (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Basic earnings per share
Net income from continuing operations	$ 61.5	$ 57.6	$ 125.3	$ 106
Amount allocated to nonvested participating shareholders	(0.2)	(0.2)	(0.4)	(0.4)
Income before discontinued operations available to common shareholders - Basic	61.3	57.4	124.9	105.6
Income (loss) from discontinued operations, net	(49.7)	0.8	(55.5)	2.5
Amount allocated to nonvested participating shareholders	0	0	0	0
Income (loss) from discontinued operations available to common shareholders - Basic	(49.7)	0.8	(55.5)	2.5
Net income	11.8	58.4	69.8	108.5
Amount allocated to nonvested participating shareholders	(0.2)	(0.2)	(0.4)	(0.4)
Net income available to common shareholders - Basic	$ 11.6	$ 58.2	$ 69.4	$ 108.1
Average common shares outstanding - Basic	233	215.4	232.9	215.3
Earnings per share from continuing operations available to common shareholders - Basic	$ 0.26	$ 0.27	$ 0.53	$ 0.49
Earnings per share from discontinued operations available to common shareholders - Basic	(0.21)	0	(0.23)	0.01
Earnings per share - Basic	$ 0.05	$ 0.27	$ 0.30	$ 0.50
Diluted earnings per share
Net income from continuing operations	$ 61.5	$ 57.6	$ 125.3	$ 106
Amount allocated to nonvested participating shareholders	(0.2)	(0.2)	(0.4)	(0.4)
Income before discontinued operations available to common shareholders - Diluted	61.3	57.4	124.9	105.6
Income (loss) from discontinued operations, net	(49.7)	0.8	(55.5)	2.5
Amount allocated to nonvested participating shareholders	0	0	0	0
Income (loss) from discontinued operations available to common shareholders - Diluted	(49.7)	0.8	(55.5)	2.5
Net income	11.8	58.4	69.8	108.5
Amount allocated to nonvested participating shareholders	(0.2)	(0.2)	(0.4)	(0.4)
Net income available to common shareholders - Diluted	$ 11.6	$ 58.2	$ 69.4	$ 108.1
Average common shares outstanding - Basic	233	215.4	232.9	215.3
Assumed conversion of stock options, unvested restricted stock and contingent performance shares, net	0.6	0.5	0.6	0.5
Average common shares outstanding - Diluted	233.6	215.9	233.5	215.8
Earnings per share from continuing operations available to common shareholders - Diluted	$ 0.26	$ 0.27	$ 0.53	$ 0.49
Earnings per share from discontinued operations available to common shareholders - Diluted	(0.21)	0	(0.23)	0.01
Earnings per share - Diluted	$ 0.05	$ 0.27	$ 0.30	$ 0.50
Anti-dilutive shares	0.4	0	0.3	0

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) $ in Millions	Dec. 19, 2013USD ($)	Feb. 08, 2011CustomerLawsuitInsuranceCarrier	Jun. 30, 2015USD ($)Claims	Mar. 31, 2011Customer
Long Term Commitments [Line Items]
Gas supply disruption of high utility customers | Customer				32,000
Number of claims dismissed | Claims			2
Number of lawsuits for insurance carriers | Lawsuit		2
Number of insurance carriers | InsuranceCarrier		18
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
TECO Guatemala Holdings, LLC v. The Republic of Guatemala [Member]
Long Term Commitments [Line Items]
Litigation settlement amount	$ 7.5
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 | Customer		28,700

Commitments and Contingencies50

Commitments and Contingencies - Letters of Credit and Guarantees (Detail)	Jun. 30, 2015USD ($)
Tampa Electric Company [Member] | Letters Of Credit [Member]
Guarantee Obligations [Line Items]
Year of Expiration 2015	$ 0
Year of expiration 2016-2019	0
Year of expiration After 2019	600,000
Maximum Theoretical Obligation	600,000
Liabilities Recognized at June 30, 2015	100,000
New Mexico Gas Company [Member] | Letters Of Credit [Member]
Guarantee Obligations [Line Items]
Year of Expiration 2015	0
Year of expiration 2016-2019	0
Year of expiration After 2019	1,700,000
Maximum Theoretical Obligation	1,700,000
Liabilities Recognized at June 30, 2015	0
Fuel Sales and Transportation [Member]
Guarantee Obligations [Line Items]
Year of Expiration 2015	0
Year of expiration 2016-2019	0
Year of expiration After 2019	92,900,000
Maximum Theoretical Obligation	92,900,000
Liabilities Recognized at June 30, 2015	$ 0

Segment Information - Schedule

Segment Information - Schedule of Segment Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Segment Reporting Information [Line Items]
Total revenues	$ 680.6	$ 605.7	$ 1,373.6	$ 1,183.7
Depreciation and amortization	87	75.5	172.5	151.4
Total interest charges	46.4	40.7	94.3	80.3
Internally allocated interest	0	0	0	0
Provision (benefit) for income taxes	40.5	35.2	80.4	64.3
Net income from continuing operations	61.5	57.6	125.3	106
Income (loss) from discontinued operations, net	(49.7)	0.8	(55.5)	2.5
Net income	11.8	58.4	69.8	108.5
Total assets	8,838.4		8,838.4		$ 8,726.2
Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	624.6	603.3	1,196.7	1,178.8
Depreciation and amortization	78	75.1	154.8	150.5
Total interest charges	27.2	26.7	54.2	52.1
Provision (benefit) for income taxes	43.7	41.9	80.3	77.7
Net income	75.3	69.7	138.1	129.5
Total assets	7,456.3		7,456.3		7,274.3
Eliminations [Member]
Segment Reporting Information [Line Items]
Total revenues	(2.2)	(0.7)	(4.2)	(1.2)
Depreciation and amortization	0	0	0	0
Total interest charges	(0.4)	(1.9)	(0.7)	(3.7)
Internally allocated interest	(0.4)	(1.9)	(0.7)	(3.7)
Provision (benefit) for income taxes	0	0	0	0
Net income from continuing operations	0	0	0	0
Income (loss) from discontinued operations, net	0	0	0	0
Net income	0	0	0	0
Total assets	(2,045.2)		(2,045.2)		(1,998.5)
Eliminations | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	(1.3)	(0.5)	(2.7)	(0.8)
Depreciation and amortization	0	0	0	0
Total interest charges	0	0	0	0
Provision (benefit) for income taxes	0	0	0	0
Net income	0	0	0	0
Total assets	(5.7)		(5.7)		(7.1)
Revenues - External [Member]
Segment Reporting Information [Line Items]
Total revenues	680.6	605.7	1,373.6	1,183.7
Revenues - External [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	624.6	603.3	1,196.7	1,178.8
Revenues - External [Member] | Eliminations [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Revenues - External [Member] | Eliminations | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Sales to Affiliates [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0	0	0
Sales to Affiliates [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0	0	0
Sales to Affiliates [Member] | Eliminations [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	(2.2)	(0.7)	(4.2)	(1.2)
Sales to Affiliates [Member] | Eliminations | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	(1.3)	(0.5)	(2.7)	(0.8)
Tampa Electric [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	532.4	512.7	983	965.9
Depreciation and amortization	64	61.7	126.9	123.8
Total interest charges	23.6	23.3	47.1	45.3
Internally allocated interest	0	0	0	0
Provision (benefit) for income taxes	38.9	37.1	66.3	63.7
Net income from continuing operations	67.7	62.2	115.9	107.4
Income (loss) from discontinued operations, net	0	0	0	0
Net income	67.7	62.2	115.9	107.4
Total assets	6,739.5		6,739.5		6,565.4
Tampa Electric [Member] | Operating Segments [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	532.4	512.7	983	965.9
Depreciation and amortization	64	61.7	126.9	123.8
Total interest charges	23.6	23.3	47.1	45.3
Provision (benefit) for income taxes	38.9	37.1	66.3	63.7
Net income	67.7	62.2	115.9	107.4
Total assets	6,406.3		6,406.3		6,234.4
Tampa Electric [Member] | Revenues - External [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	531.6	512.5	981.4	965.4
Tampa Electric [Member] | Revenues - External [Member] | Operating Segments [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	532.4	512.6	982.8	965.7
Tampa Electric [Member] | Sales to Affiliates [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0.8	0.2	1.6	0.5
Tampa Electric [Member] | Sales to Affiliates [Member] | Operating Segments [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0.1	0.2	0.2
PGS [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	93.5	91.1	216.4	213.7
Depreciation and amortization	14	13.4	27.9	26.7
Total interest charges	3.6	3.4	7.1	6.8
Internally allocated interest	0	0	0	0
Provision (benefit) for income taxes	4.8	4.8	14	14
Net income from continuing operations	7.6	7.5	22.2	22.1
Income (loss) from discontinued operations, net	0	0	0	0
Net income	7.6	7.5	22.2	22.1
Total assets	1,089.2		1,089.2		1,082.8
PGS [Member] | Operating Segments [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	93.5	91.1	216.4	213.7
Depreciation and amortization	14	13.4	27.9	26.7
Total interest charges	3.6	3.4	7.1	6.8
Provision (benefit) for income taxes	4.8	4.8	14	14
Net income	7.6	7.5	22.2	22.1
Total assets	1,055.7		1,055.7		1,047
PGS [Member] | Revenues - External [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	92.2	90.7	213.9	213.1
PGS [Member] | Revenues - External [Member] | Operating Segments [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Total revenues	92.2	90.7	213.9	213.1
PGS [Member] | Sales to Affiliates [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	1.3	0.4	2.5	0.6
PGS [Member] | Sales to Affiliates [Member] | Operating Segments [Member] | Tampa Electric Company [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	1.3	0.4	2.5	0.6
NMGC [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	54	0	173	0
Depreciation and amortization	8.4	0	16.8	0
Total interest charges	3.3	0	6.6	0
Internally allocated interest	0	0	0	0
Provision (benefit) for income taxes	0	0	9	0
Net income from continuing operations	(0.1)	0	13.8	0
Income (loss) from discontinued operations, net	0	0	0	0
Net income	(0.1)	0	13.8	0
Total assets	1,180.2		1,180.2		1,237.2
NMGC [Member] | Revenues - External [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	54	0	173	0
NMGC [Member] | Sales to Affiliates [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0	0	0
TECO Coal [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Depreciation and amortization	0	0	0	0
Total interest charges	0	0	0	0
Internally allocated interest	0	0	0	0
Provision (benefit) for income taxes	0	0	0	0
Net income from continuing operations	0	0	0	0
Income (loss) from discontinued operations, net	(51.5)	0.8	(57.5)	(0.8)
Net income	(51.5)	0.8	(57.5)	(0.8)
Total assets	173		173		227.7
TECO Coal [Member] | Revenues - External [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
TECO Coal [Member] | Sales to Affiliates [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	0	0	0	0
Other [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	2.9	2.6	5.4	5.3
Depreciation and amortization	0.6	0.4	0.9	0.9
Total interest charges	16.3	15.9	34.2	31.9
Internally allocated interest	0.4	1.9	0.7	3.7
Provision (benefit) for income taxes	(3.2)	(6.7)	(8.9)	(13.4)
Net income from continuing operations	(13.7)	(12.1)	(26.6)	(23.5)
Income (loss) from discontinued operations, net	1.8	0	2	3.3
Net income	(11.9)	(12.1)	(24.6)	(20.2)
Total assets	1,701.7		1,701.7		$ 1,611.6
Other [Member] | Revenues - External [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	2.8	2.5	5.3	5.2
Other [Member] | Sales to Affiliates [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales to affiliates	$ 0.1	$ 0.1	$ 0.1	$ 0.1

Accounting for Derivative Ins52

Accounting for Derivative Instruments and Hedging Activities - Additional Information (Detail) - USD ($)	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative assets	$ 600,000	$ 0
Derivative liabilities	26,300,000	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	(23,800,000)
Tampa Electric Company [Member]
Derivative [Line Items]
Derivative assets	0	0
Derivative liabilities	26,300,000	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	$ (24,400,000)
Natural Gas Contracts [Member]
Derivative [Line Items]
Maximum length of time hedging in future cash flow	Jun. 30, 2017
Natural Gas Contracts [Member] | Tampa Electric Company [Member]
Derivative [Line Items]
Maximum length of time hedging in future cash flow	Jun. 30, 2017

Accounting for Derivative Ins53

Accounting for Derivative Instruments and Hedging Activities - Derivative Volumes Expected to Settle (Detail) - Natural Gas Contracts [Member] MMBTU in Millions	Jun. 30, 2015MMBTU
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	38.8
Financial [Member] | Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	31.9
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	21.3
2015 [Member] | Financial [Member] | Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	18.8
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	15.7
2016 [Member] | Financial [Member] | Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	11.3
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	1.8
2017 [Member] | Financial [Member] | Tampa Electric Company [Member]
Derivative [Line Items]
Derivative, Nonmonetary Notional Amount	1.8

Fair Value Measurements - Sched

Fair Value Measurements - Schedule of Recurring Fair Value Measurements (Detail) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Natural gas derivative assets	$ 0.6	$ 0
Natural gas derivative liabilities	26.3	42.7
Tampa Electric Company [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Natural gas derivative assets	0	0
Natural gas derivative liabilities	26.3	42.7
Fair Value, Measurements, Recurring [Member] | Natural Gas Derivatives [Member]
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Natural gas derivative assets	0.6
Natural gas derivative liabilities	26.3	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]
Natural gas derivative liabilities	26.3	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]
Natural gas derivative assets	0
Natural gas derivative 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]
Natural gas derivative 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]
Natural gas derivative assets	0.6
Natural gas derivative liabilities	26.3	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]
Natural gas derivative liabilities	26.3	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]
Natural gas derivative assets	0
Natural gas derivative 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]
Natural gas derivative liabilities	$ 0	$ 0

Variable Interest Entities - Ad

Variable Interest Entities - Additional Information (Detail) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015USD ($)	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)MW	Jun. 30, 2014USD ($)
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	$ 19.6	$ 19.9	$ 36.7	$ 38.1
Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	19.6	19.9	36.7	38.1
Power Purchase Agreements [Member] | Variable Interest Entities [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	9.9	7	15.3	12.8
Power Purchase Agreements [Member] | Variable Interest Entities [Member] | Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Purchased power	$ 9.9	$ 7	$ 15.3	$ 12.8
Minimum [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range | MW			117
Minimum [Member] | Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range | MW			117
Maximum [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range | MW			159
Maximum [Member] | Tampa Electric Company [Member]
Long Term Contract For Purchase Of Electric Power [Line Items]
Multiple PPAs range | MW			159

Discontinued Operations, Asse56

Discontinued Operations, Assets Held for Sale and Asset Impairments - Additional Information (Detail) - TECO Coal [Member] - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2014	Feb. 05, 2015
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Contingent Payments			$ 60
Purchase price			$ 80
Total pretax impairment charges	$ 78.6	$ 115.9

Discontinued Operations, Asse57

Discontinued Operations, Assets Held for Sale and Asset Impairments - Carrying Amount of Assets and Liabilities Held for Sale (Detail) - USD ($) $ in Millions	Jun. 30, 2015	Dec. 31, 2014
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Current assets	$ 96.5	$ 109.6
Property, plant and equipment, net and other long-term assets	0	59.8
Current liabilities	30.2	39.4
Long-term liabilities	66.3	65.4
TECO Coal [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Current assets	96.5	109.6
Property, plant and equipment, net and other long-term assets	0	59.8
Total assets held for sale	96.5	169.4
Current liabilities	30.2	39.4
Long-term liabilities	66.3	65.4
Total liabilities associated with assets held for sale	$ 96.5	$ 104.8

Discontinued Operations, Asse58

Discontinued Operations, Assets Held for Sale and Asset Impairments - Components of Discontinued Operations (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (loss) from discontinued operations	$ (78.1)	$ 0	$ (87.7)	$ 1.2
Benefit from income taxes	(28.4)	(0.8)	(32.2)	(1.3)
Income (loss) on discontinued operations, net	(49.7)	0.8	(55.5)	2.5
TECO Coal [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Revenues	76.1	120.6	148.8	226.7
Income (loss) from operations	0.5	0	(9)	(3.8)
Loss on impairment	(78.6)	0	(78.6)	0
Income (loss) from discontinued operations	(78.1)	0	(87.6)	(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	0	(0.1)	5
Income (loss) from discontinued operations	0	0	(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	(78.1)	0	(87.7)	1.2
Benefit from income taxes	(28.4)	(0.8)	(32.2)	(1.3)
Income (loss) on discontinued operations, net	$ (49.7)	$ 0.8	$ (55.5)	$ 2.5