Tampa Electric 10-Q 12 Aug 20 2020 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2020	Aug. 10, 2020
Cover [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2020
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Current Reporting Status	Yes
Entity Shell Company	false
Entity Registrant Name	TAMPA ELECTRIC COMPANY
Entity Interactive Data Current	Yes
Entity File Number	1-5007
Entity Address, Address Line One	TECO Plaza
Entity Address, Address Line Two	702 N. Franklin Street
Entity Address, City or Town	Tampa
Entity Address, State or Province	FL
Entity Tax Identification Number	59-0475140
Entity Incorporation, State or Country Code	FL
Entity Address, Postal Zip Code	33602
City Area Code	813
Local Phone Number	228-1111
Document Quarterly Report	true
Document Transition Report	false
Entity Central Index Key	0000096271
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		10

Consolidated Condensed Balance

Consolidated Condensed Balance Sheets (Unaudited) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Property, plant and equipment
Utility plant, at original costs	$ 13,143	$ 12,590
Accumulated depreciation	(3,579)	(3,472)
Utility plant, net	9,564	9,118
Other property	14	13
Total property, plant and equipment, net	9,578	9,131
Current assets
Cash and cash equivalents	10	14
Receivables, less allowance for uncollectibles of $6 and $2 at June 30, 2020 and December 31, 2019, respectively	231	206
Due from affiliates	25	14
Inventories, at average cost
Regulatory assets	39	41
Prepayments and other current assets	19	10
Total current assets	466	425
Deferred debits
Regulatory assets	389	396
Other	56	55
Total deferred debits	445	451
Total assets	10,489	10,007
Capitalization
Common stock	3,650	3,385
Accumulated other comprehensive loss	(1)	(1)
Retained earnings	354	311
Total capital	4,003	3,695
Long-term debt	2,592	2,869
Total capitalization	6,595	6,564
Current liabilities
Long-term debt due within one year	278	0
Notes payable	494	348
Accounts payable	245	296
Due to affiliates	17	20
Customer deposits	131	132
Regulatory liabilities	110	93
Accrued interest	15	13
Accrued taxes	52	14
Other	40	44
Total current liabilities	1,382	960
Long-term liabilities
Deferred income taxes	760	758
Regulatory liabilities	1,207	1,210
Investment tax credits	218	164
Deferred credits and other liabilities	327	351
Total long-term liabilities	2,512	2,483
Commitments and Contingencies (see Note 8)
Total liabilities and capitalization	10,489	10,007
Fuel [Member]
Inventories, at average cost
Utility inventories	35	36
Materials and Supplies [Member]
Inventories, at average cost
Utility inventories	107	104
Electric [Member]
Property, plant and equipment
Utility plant, at original costs	10,992	10,578
Gas [Member]
Property, plant and equipment
Utility plant, at original costs	$ 2,151	$ 2,012

Consolidated Condensed Balanc_2

Consolidated Condensed Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Statement Of Financial Position [Abstract]
Allowance for uncollectibles	$ 6	$ 2

Consolidated Condensed Statemen

Consolidated Condensed Statements of Income and Comprehensive Income (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Revenues
Electric	$ 453	$ 520	$ 873	$ 931
Gas	96	107	223	235
Total revenues	549	627	1,096	1,166
Expenses
Fuel	67	139	168	246
Purchased power	25	13	27	17
Cost of natural gas sold	25	38	67	85
Operations and maintenance	126	132	260	262
Depreciation and amortization	92	94	189	186
Taxes, other than income	50	52	101	102
Total expenses	385	468	812	898
Income from operations	164	159	284	268
Other income
Allowance for equity funds used during construction	7	2	13	4
Other income, net	2	3	3	5
Total other income	9	5	16	9
Interest charges
Interest expense	35	34	72	68
Allowance for borrowed funds used during construction	(3)	(1)	(6)	(2)
Total interest charges	32	33	66	66
Income before provision for income taxes	141	131	234	211
Provision for income taxes	24	24	40	40
Net income	117	107	194	171
Comprehensive income	$ 117	$ 107	$ 194	$ 171

Consolidated Condensed Statem_2

Consolidated Condensed Statements of Cash Flows (Unaudited) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Cash flows from operating activities
Net income	$ 194	$ 171
Adjustments to reconcile net income to cash from operating activities:
Depreciation and amortization	189	186
Deferred income taxes and investment tax credits	43	31
Deferred recovery clauses	37	1
Receivables, less allowance for uncollectibles	(22)	1
Prepayments and other deposits	(9)	(6)
Taxes accrued	20	25
Accounts payable	(41)	(54)
Regulatory assets and liabilities	(12)	5
Other	(17)	(29)
Cash flows from operating activities	382	331
Cash flows used in investing activities
Capital expenditures	(653)	(581)
Net proceeds from sale of assets	6	0
Cash flows used in investing activities	(647)	(581)
Cash flows from financing activities
Equity contributions from Parent	265	220
Net increase (decrease) in short-term debt (maturities of 90 days or less)	(154)	165
Proceeds from other short-term debt (maturities over 90 days)	300	0
Dividends to Parent	(150)	(140)
Cash flows from financing activities	261	245
Net decrease in cash and cash equivalents	(4)	(5)
Cash and cash equivalents at beginning of period	14	15
Cash and cash equivalents at end of period	10	10
Supplemental disclosure of non-cash activities
Change in accrued capital expenditures	$ (12)	$ (4)

Consolidated Condensed Statem_3

Consolidated Condensed Statements of Capital (Unaudited) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Beginning balance	$ 3,845	$ 3,401	$ 3,695	$ 3,303
Net income	117	107	194	171
Equity contributions from Parent	120	110	265	220
Dividends to Parent	(77)	(64)	(150)	(140)
Other	(2)		(1)
Ending balance	4,003	3,554	4,003	3,554
Common Stock [Member]
Beginning balance	$ 3,530	$ 3,100	$ 3,385	$ 2,990
Beginning balance	10	10	10	10
Equity contributions from Parent	$ 120	$ 110	$ 265	$ 220
Ending balance	$ 3,650	$ 3,210	$ 3,650	$ 3,210
Ending balance	10	10	10	10
Retained Earnings [Member]
Beginning balance	$ 316	$ 302	$ 311	$ 314
Net income	117	107	194	171
Dividends to Parent	(77)	(64)	(150)	(140)
Other	(2)		(1)
Ending balance	354	345	354	345
Accumulated Other Comprehensive Loss [Member]
Beginning balance	(1)	(1)	(1)	(1)
Ending balance	$ (1)	$ (1)	$ (1)	$ (1)

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	1. Summary of Significant Accounting Policies See TEC’s Annual Report on Form 10-K for the year ended December 31, 2019 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, which is an indirect, wholly owned subsidiary of Emera. TEC is comprised of the electric division, referred to as Tampa Electric, and the natural gas division, referred to as PGS. Intercompany balances and transactions within the divisions 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, 2020 and December 31, 2019, and the results of operations and cash flows for the periods ended June 30, 2020 and June 30, 2019. The results of operations for the three and six months ended June 30, 2020 are not necessarily indicative of the results that can be expected for the entire fiscal year ending December 31, 2020. 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 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. Since December 31, 2019, the outbreak of the novel strain of coronavirus, specifically identified as COVID-19, has resulted in governments worldwide enacting emergency measures to combat the spread of the virus. While management considered the impact of COVID-19 in TEC’s estimates and results, the financial statements as of and for the three and six months ended June 30, 2020 were not significantly impacted by COVID-19. However, it is not possible to reliably estimate the length and severity of the COVID-19 pandemic and the impact on the financial results and condition of TEC in future periods. See Note 5 Receivables and Allowance for Uncollectible Accounts Receivables from contracts with customers, which consist of services to residential, commercial, industrial and other customers, were $230 million and $205 million as of June 30, 2020 and December 31, 2019, respectively. An allowance for uncollectible accounts is established based on TEC’s collection experience and reasonable and supportable forecasts that affect the collectibility of the reported amount. Circumstances that could affect Tampa Electric’s and PGS’s estimates of uncollectible receivables include, but are not limited to, customer credit issues, fuel prices, customer deposits and general economic conditions, including the impacts of the COVID-19 pandemic. Accounts are reserved in the allowance or written off once they are deemed to be uncollectible. As of June 30, 2020 and December 31, 2019, unbilled revenues of $84 million and $61 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets. Accounting for Franchise Fees and Gross Receipts Tampa Electric and PGS are allowed to recover certain costs from customers on a dollar-for-dollar basis through rates 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 $26 million and $29 million for the three months ended June 30, 2020 and 2019, respectively, and $53 million and $56 million for the six months ended June 30, 2020 and 2019, respectively.

New Accounting Pronouncements

New Accounting Pronouncements	6 Months Ended
	Jun. 30, 2020
Accounting Changes And Error Corrections [Abstract]
New Accounting Pronouncements	2. New Accounting Pronouncements Change in Accounting Policy The new U.S. GAAP accounting policies that are applicable to and adopted by TEC in 2020 are described as follows: Measurement of Credit Losses on Financial Instruments TEC adopted Accounting Standard Update (ASU) 2016-13, Measurement of Credit Losses on Financial Instruments Future Accounting Pronouncements TEC considers the applicability and impact of all ASUs issued by the FASB. The ASUs that have been issued, but that are not yet effective, are consistent with those disclosed in TEC’s Annual Report on Form 10-K for the year ended December 31, 2019, with updates noted below. Facilitation of the Effects of Reference Rate Reform on Financial Reporting In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform (Topic 848): Facilitation of the Effects of Reference Rate Reform on Financial Reporting

Regulatory

Regulatory	6 Months Ended
	Jun. 30, 2020
Regulated Operations [Abstract]
Regulatory	3. Regulatory Tampa Electric Base Rates On September 27, 2017, Tampa Electric filed with the FPSC an amended and restated settlement agreement that replaced the existing 2013 base rate settlement agreement and extended it another four years through December 31, 2021. The FPSC approved the agreement on November 6, 2017. The amended agreement provides for SoBRAs for TEC’s investments in up to 600 MW of cost-effective solar generation. Tampa Electric is investing approximately $850 million during 2017 through 2021 related to 600 MW of solar projects recoverable under the SoBRAs. On December 12, 2017, TEC filed its first petition regarding the SoBRAs along with supporting tariffs demonstrating the cost-effectiveness of the September 1, 2018 tranche representing 145 MW and $24 million annually in estimated revenue requirements. The FPSC approved the tariffs on the first SoBRA filing on May 8, 2018 and TEC began receiving these revenues in September 2018 requirements. The FPSC approved the tariffs on the second SoBRA filing on October 29, 2018 and TEC began receiving these revenues in January 2019. On June 28, 2019, TEC filed its third SoBRA petition along with supporting tariffs demonstrating the cost-effectiveness of the January 1, 2020 tranche representing 149 MW and $26 million annually in estimated revenue requirements. On December 10, 2019, the FPSC approved the tariffs on this SoBRA filing, including an adjustment to reflect the reduction in the state corporate income tax discussed below, and TEC began receiving these revenues in January 2020. The 2017 settlement agreement provides for a potential revenue adjustment of an additional $10 million for 50 MWs effective on January 1, 2021. TEC expects to file its final SoBRA petition for the January 1, 2021 tranche in 2020 The true-up filing for SoBRA tranche 1 and 2 revenue requirement estimates that were included in base rates as of September 2018 and January 2019, respectively, was submitted on April 30, 2020. Once approved, the final net true-up amount is expected to be a refund of $5 million, which will be returned to customers in 2020. On November 13, 2019, as required by the 2017 settlement agreement, TEC filed its petition to reduce base rates and charges to reflect the impact of the temporary reduction of the state corporate income tax from 5.5% to 4.5%. The tax rate reduction was issued on September 12, 2019 and is effective retroactive from January 1, 2019 through December 31, 2021. The estimated base rate reduction due to customers of $5 million is subject to true-up, and the actual rate reduction may vary from year to year. The base rate reduction was approved on December 10, 2019 for rates effective January 2020. Tampa Electric Big Bend Modernization Project Tampa Electric expects to invest approximately $850 million during 2018 through 2023 to modernize the Big Bend Power Station, of which approximately $414 million has been invested through June 30, 2020. The Big Bend modernization project will repower Big Bend Unit 1 with natural gas combined-cycle technology and eliminate coal as this unit’s fuel. Tampa Electric Storm Protection Cost Recovery Clause and Settlement Agreement On October 3, 2019, the FPSC issued a rule to implement a Storm Protection Plan (SPP) Cost Recovery Clause. This new clause provides a process for Florida investor-owned utilities, including Tampa Electric, to recover transmission and distribution storm hardening costs for incremental activities not already included in base rates. Tampa Electric submitted its storm protection plan with the FPSC on April 10, 2020. On April 27, 2020, Tampa Electric submitted a settlement agreement with the FPSC which specified a $15 million base rate reduction for costs previously recovered in base rates related to SPP programs beginning January 1, 2021. On June 9, 2020, the FPSC approved this settlement agreement. On August 3, 2020, Tampa Electric submitted another settlement agreement to the FPSC for approval, including cost recovery of approximately $39 million in proposed storm protection project costs for 2020 and 2021. This cost recovery includes the $15 million of costs reduced from base rates. This settlement agreement was approved on August 10, 2020 and Tampa Electric’s cost recovery will begin in January 2021. Tampa Electric will file a new plan in 2022 to determine cost recovery in 2023, 2024, and 2025. The June 9, 2020 settlement agreement approved by the FPSC disclosed above also included approval of Tampa Electric’s petition to eliminate its $16 million accumulated amortization reserve surplus for intangible software assets through a credit to amortization expense in 2020. As stipulated in the settlement, $8 million of this credit was recognized in the second quarter of 2020 with the remaining $8 million to be recognized over the remainder of 2020. Tampa Electric Mid-Course Adjustment to Fuel Recovery In March 2020, Tampa Electric requested a mid-course adjustment to its fuel and capacity charges, effective with June 2020 customer bills, due to a decline in expected fuel commodity and capacity costs in 2020. The FPSC approved the request on April 28, 2020. This will result in lower fuel and capacity clause rates to customers for the remainder of 2020, including an acceleration of the return of these savings in the three months starting June 2020 through customer bill credits Tampa Electric Storm Restoration Cost Recovery As a result of Tampa Electric’s 2013 rate case settlement, in the event of a named storm that results in damage to its system, Tampa Electric can petition the FPSC to seek recovery of those costs over a 12-month period or longer as determined by the FPSC, as well as replenish its reserve to $56 million, the level of the reserve as of October 31, 2013. In the third quarter of 2017, Tampa Electric was impacted by Hurricane Irma and incurred storm restoration costs of approximately $102 million. Tampa Electric petitioned the FPSC on December 28, 2017 for recovery of estimated storm costs and to replenish the balance in the reserve to the level that existed as of October 31, 2013. On March 1, 2018, the FPSC approved a settlement agreement filed by Tampa Electric that addressed both the recovery of storm costs and the return of U.S. tax reform benefits to customers while keeping customer rates stable in 2018. Beginning on April 1, 2018, the agreement authorized Tampa Electric to net the estimated amount of storm cost recovery against Tampa Electric’s estimated 2018 tax reform benefits of $103 million. On August 20, 2018, the FPSC approved lowering base rates by $103 million annually beginning on January 1, 2019 as a result of lower tax expense. On April 9, 2019, Tampa Electric reached a settlement agreement with consumer parties regarding eligible storm costs, which was approved by the FPSC on May 21, 2019. As a result, In 2019, Tampa Electric incurred storm restoration preparation costs for Hurricane Dorian estimated to be approximately $8 million, which was charged to the storm reserve regulatory liability. PGS Base Rates PGS’s base rates were established in 2009. In accordance with its 2018 settlement agreement, PGS reduced its base rates by $12 million for the impact of tax reform and reduced depreciation rates by $10 million on an annual basis beginning in January 2019. PGS is permitted to initiate a general base rate proceeding during 2020 regardless of its earned ROE at the time, provided the new rates do not become effective before January 1, 2021. As a result of increased forecasted revenue requirements, on June 8, 2020, PGS filed a petition for an increase in rates and service charges effective January 2021. The new rates would be expected to result in an increase in revenue of approximately $62 million annually. Regulatory Assets and Liabilities Tampa Electric and PGS apply the FASB’s accounting standards for regulated operations. Regulatory assets generally represent incurred costs that have been deferred, as their future recovery in customer rates is probable. Regulatory liabilities generally represent obligations to make refunds to customers from previous collections for costs that are not likely to be incurred or the advance recovery of expenditures for approved costs. Details of the regulatory assets and liabilities are presented in the following table: Regulatory Assets and Liabilities (millions) June 30, 2020 December 31, 2019 Regulatory assets: Regulatory tax asset (1) $ 87 $ 74 Cost-recovery clauses (2) 7 12 Environmental remediation (3) 21 20 Postretirement benefits (4) 287 295 Asset retirement obligation (5) 16 25 Other 10 11 Total regulatory assets 428 437 Less: Current portion 39 41 Long-term regulatory assets $ 389 $ 396 Regulatory liabilities: Regulatory tax liability (6) $ 698 $ 699 Cost-recovery clauses (2) 70 37 Accumulated reserve - cost of removal (7) 500 506 Storm reserve (8) 48 48 Other 1 13 Total regulatory liabilities 1,317 1,303 Less: Current portion 110 93 Long-term regulatory liabilities $ 1,207 $ 1,210 (1) The regulatory tax asset is primarily associated with the depreciation and recovery of AFUDC-equity. This asset does not earn a return but rather is included in the capital structure, which is used in the calculation of the weighted cost of capital used to determine revenue requirements. It will be recovered over the expected life of the related assets. The regulatory tax asset balance reflects the impact of the federal tax rate reduction. (2) These assets and liabilities are related to FPSC clauses and riders. They are recovered or refunded through cost-recovery mechanisms approved by the FPSC on a dollar-for-dollar basis in the next year. (3) This asset is related to costs associated with environmental remediation primarily at MGP sites. The balance is included in rate base, partially offsetting the related liability, and earns a rate of return as permitted by the FPSC. The timing of recovery is based on a settlement agreement approved by the FPSC. (4) This asset is related to the deferred costs of postretirement benefits and it is amortized over the remaining service life of plan participants. Deferred costs of postretirement benefits that are included in expense are recognized as cost of service for rate-making purposes as permitted by the FPSC. (5) This asset is related to costs associated with an asset retirement obligation, which is a legal obligation for the future retirement of certain tangible, long-lived assets. This regulatory asset does not earn a return because it is offset with related assets and liabilities within rate base. It is recovered and removed as the obligation is settled and removed as the activities for the retirement of the related assets have been completed. (6) The regulatory tax liability is primarily related to the revaluation of TEC’s deferred income tax balances recorded on December 31, 2017 at the lower income tax rate due to U.S. tax reform. The liability related to the revaluation of the deferred income tax balances is amortized and returned to customers through rate reductions or other revenue offsets based on IRS regulations and the settlement agreement for tax reform benefits approved by the FPSC. (7) This item represents the non-ARO cost of removal in the accumulated reserve for depreciation. AROs are costs for legally required removal of property, plant and equipment. Non-ARO cost of removal represents estimated funds received from customers through depreciation rates to cover future non-legally required cost of removal of property, plant and equipment, net of salvage value upon retirement, which reduces rate base for ratemaking purposes. This liability is reduced as costs of removal are incurred. (1) See “Tampa Electric Storm Restoration Cost Recovery” discussion above for information regarding this reserve.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	4. Income Taxes CARES Act On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security (CARES) Act (the Act) was signed into legislation. The Act includes several business provisions including deferral in employer payroll taxes and an employee retention payroll tax credit. TEC is continuing to evaluate the impact of the Act but does not expect any material impacts. Income Tax Expense TEC is included in a consolidated U.S. federal income tax return with EUSHI and its subsidiaries. TEC’s income tax expense is based upon a separate return method, modified for the benefits-for-loss allocation in accordance with respective tax sharing agreements with TECO Energy and EUSHI. To the extent that TEC’s cash tax positions are settled differently than the amount reported as realized under the tax sharing agreement, the difference is reflected in common stock. TEC’s effective tax rates for the six months ended June 30, 2020 and 2019 were 17.1% and 19.0%, respectively. The June 30, 2020 and 2019 effective tax rates are an estimate of the annual effective income tax rate. TEC’s effective tax rate for the six months ended June 30, 2020 and 2019 differed from the statutory rate principally due to the amortization of the regulatory tax liability resulting from tax reform. See Note 3 Unrecognized Tax Benefits As of June 30, 2020 and December 31, 2019, the amount of unrecognized tax benefits was $9 million, all of which was recorded as a reduction of deferred income tax assets for tax credit carryforwards. TEC believes that it is reasonably possible the total unrecognized tax benefits could decrease and be recognized within the next twelve months due to the ongoing audit examination of TECO Energy’s consolidated federal income tax return for the short tax year ending June 30, 2016. However, the impact of the COVID-19 pandemic on the timing of audit examinations cannot be reliably predicted at this time. TEC had $9 million of unrecognized tax benefits at June 30, 2020 and December 31, 2019, that, if recognized, would reduce TEC’s effective tax rate.

Employee Postretirement Benefit

Employee Postretirement Benefits	6 Months Ended
	Jun. 30, 2020
Compensation And Retirement Disclosure [Abstract]
Employee Postretirement Benefits	5. Employee Postretirement Benefits TEC is a participant in the comprehensive retirement plans of TECO Energy. The following table presents detail related to TECO Energy’s periodic benefit cost for pension and other postretirement benefits. Amounts disclosed for TECO Energy’s pension benefits include the amounts related to its qualified pension plan and non-qualified, non-contributory SERP and Restoration Plan. TECO Energy Benefit Cost (millions) Pension Benefits Other Postretirement Benefits Three months ended June 30, 2020 2019 2020 2019 Components of net periodic benefit cost Service cost $ 5 $ 5 $ 0 $ 0 Interest cost 6 8 2 1 Expected return on assets (12 ) (14 ) 0 0 Amortization of: Actuarial loss 5 5 0 0 Net periodic benefit cost $ 4 $ 4 $ 2 $ 1 Six months ended June 30, Components of net periodic benefit cost Service cost $ 10 $ 10 $ 0 $ 0 Interest cost 13 16 3 3 Expected return on assets (25 ) (26 ) 0 0 Amortization of: Actuarial loss 10 8 0 0 Settlement cost 0 1 (1) 0 0 Net periodic benefit cost $ 8 $ 9 $ 3 $ 3 (1) Represents TECO Energy’s SERP and Restoration Plan settlement charges as a result of the prior retirements of certain executives. TEC’s portion of the net periodic benefit cost for the three months ended June 30, 2020 and 2019, respectively, was $3 million and $3 million for pension benefits, and $1 million and $1 million for other postretirement benefits. TEC’s portion of the net periodic benefit cost for the six months ended June 30, 2020 and 2019, respectively, was $6 million and $7 million for pension benefits, and $3 million and $3 million for other postretirement benefits. TECO Energy assumed a long-term EROA of 7.00% and a discount rate of 3.22% for pension benefits under its qualified pension plan for 2020. For TECO Energy’s other postretirement benefits, TECO Energy used a discount rate of 3.32% for 2020. TECO Energy made contributions of $10 million and $7 million to its qualified pension plan in the six months ended June 30, 2020 and 2019, respectively. TEC’s portion of these contributions was $8 million and $5 million, respectively. TECO Energy expects to make contributions to the pension plan of $10 million for the remainder of 2020, of which TEC estimates its portion to be $8 million. Included in the benefit cost discussed above, for the three and six months ended June 30, 2020, $4 million and $9 million of unamortized prior service benefits and costs and actuarial gains and losses were reclassified by TEC from regulatory assets to the Consolidated Condensed Statement of Income, compared with $3 million and $6 million for the three and six months ended June 30, 2019. The COVID-19 pandemic could impact key actuarial assumptions used to account for employee post-retirement benefits including the anticipated rates of return on plan assets and discount rates used in determining the accrued benefit obligation, benefit costs and annual pension funding requirements. Fluctuations in actual equity market returns and changes in interest rates as a result of the COVID-19 pandemic may also result in changes to pension costs and funding in future periods. The extent of the future impact of COVID-19 on TEC’s financial results and business operations cannot be predicted at this time and will depend on future developments, including the duration and severity of the pandemic, further potential government actions, future economic activity and energy usage. Actual results may differ significantly from these estimates.

Short-Term Debt

Short-Term Debt	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Short-Term Debt	6. Short-Term Debt Details of TEC’s credit facilities and related borrowings are presented in the following table: June 30, 2020 December 31, 2019 Letters Letters Credit Borrowings of Credit Credit Borrowings of Credit (millions) Facilities Outstanding (1) Outstanding Facilities Outstanding (1) Outstanding 5-year facility (2) $ 400 $ 194 $ 1 $ 400 $ 295 $ 1 3-year accounts receivable facility (3) 150 0 0 150 53 0 1-year term facility (4) 300 300 0 0 0 0 Total $ 850 $ 494 $ 1 $ 550 $ 348 $ 1 (1) Borrowings outstanding are reported as notes payable. (2) This 5-year facility matures March 22, 2022. (3) This 3-year facility matures March 22, 2021. (4) This 1-year term facility matures on February 4, 2021. At June 30, 2020, these credit facilities required commitment fees ranging from 12.5 to 35.0 basis points. The weighted-average interest rate on outstanding amounts payable under the credit facilities at June 30, 2020 and December 31, 2019 was 0.83% and 2.56%, respectively. Tampa Electric Company Accounts Receivable Facility On July 14, 2020, TEC amended its $150 million accounts receivable collateralized borrowing facility (Loan Agreement) in order to change certain performance ratios. The amended Loan Agreement was effective as of June 30, 2020. TEC was in compliance with the requirements of the Loan Agreement at June 30, 2020. There were no other changes made to the Loan Agreement. There were no amounts outstanding on this facility at June 30, 2020. Tampa Electric Company Non Revolving Term Loan On February 6, 2020, TEC entered into a 364-day, $300 million credit agreement with a group of banks. The credit agreement has a maturity date of February 4, 2021; contains customary representations and warranties, events of default, and financial and other covenants; and provides for interest to accrue at variable rates based on either the London interbank deposit rate, Wells Fargo Bank’s prime rate, or the federal funds rate, plus a margin.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Long-Term Debt	7. Long-Term Debt Fair Value of Long-Term Debt At June 30, 2020, TEC’s long-term debt had a carrying amount of $2,870 million and an estimated fair market value of $3,482 million. At December 31, 2019, TEC’s total long-term debt had a carrying amount of $2,869 million and an estimated fair market value of $3,335 million. The fair value of the debt securities is determined using Level 2 measurements Note 11

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2020
Commitments And Contingencies Disclosure [Abstract]
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 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. Superfund and Former Manufactured Gas Plant Sites TEC, through its Tampa Electric and PGS divisions, is a PRP for certain superfund sites and, through its PGS division, for certain former MGP sites. While the joint and several liability associated with these sites presents the potential for significant response costs, as of June 30, 2020, TEC has estimated its ultimate financial liability to be $21 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 are expected to be paid over many years. 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 currently assessed 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. See Note 3 Long-Term Commitments TEC has commitments for various purchases as disclosed below, including payment obligations under contractual agreements for fuel, fuel transportation and power purchases that are recovered from customers under regulatory clauses. The following is a schedule of future payments under PPAs, minimum lease payments with non-cancelable lease terms in excess of one year, and other net purchase obligations/commitments at June 30, 2020: Long-term Demand Purchased Capital Fuel and Service Operating Side (millions) Power Transportation Projects Gas Supply Agreements Leases Management Total 2020 $ 31 $ 108 $ 118 $ 101 $ 30 $ 1 $ 2 $ 391 2021 3 234 84 52 6 3 3 385 2022 0 236 79 2 9 3 3 332 2023 0 208 68 1 12 3 0 292 2024 0 197 0 0 19 3 0 219 Thereafter 0 1,915 0 0 41 51 0 2,007 Total future minimum payments $ 34 $ 2,898 $ 349 $ 156 $ 117 $ 64 $ 8 $ 3,626 Debt Covenants TEC must meet certain financial tests, including a debt to capital ratio, as defined in the applicable debt agreements and has certain restrictive covenants in specific agreements and debt instruments. At June 30, 2020, TEC was in compliance with all required covenants.

Segment Information

Segment Information	6 Months Ended
	Jun. 30, 2020
Segment Reporting [Abstract]
Segment Information	9. Segment Information (millions) Tampa Tampa Electric Three months ended June 30, Electric PGS Eliminations Company 2020 Revenues - external $ 453 $ 96 $ 0 $ 549 Intracompany sales 1 1 (2 ) 0 Total revenues 454 97 (2 ) 549 Total interest charges 28 4 0 32 Net income $ 106 $ 11 $ 0 $ 117 2019 Revenues - external $ 520 $ 107 $ 0 $ 627 Intracompany sales 1 4 (5 ) 0 Total revenues 521 111 (5 ) 627 Total interest charges 29 4 0 33 Net income $ 93 $ 14 $ 0 $ 107 Six months ended June 30, 2020 Revenues - external $ 873 $ 223 $ 0 $ 1,096 Intracompany sales 2 4 (6 ) 0 Total revenues 875 227 (6 ) 1,096 Total interest charges 58 8 0 66 Net income $ 165 $ 29 $ 0 $ 194 2019 Revenues - external $ 931 $ 235 $ 0 $ 1,166 Intracompany sales 2 8 (10 ) 0 Total revenues 933 243 (10 ) 1,166 Total interest charges 58 8 0 66 Net income $ 139 $ 32 $ 0 $ 171 Total assets at June 30, 2020 $ 9,409 $ 1,710 $ (630 ) (1) $ 10,489 Total assets at December 31, 2019 $ 9,007 $ 1,593 $ (593 ) (1) $ 10,007 (1) Amounts primarily relate to consolidated deferred tax reclassifications. Deferred tax assets are reclassified and netted with deferred tax liabilities upon consolidation.

Revenue

Revenue	6 Months Ended
	Jun. 30, 2020
Revenues [Abstract]
Revenue	10. Revenue The following disaggregates TEC’s revenue by major source: (millions) Tampa Tampa Electric Three months ended June 30, 2020 Electric PGS Eliminations Company Electric revenue Residential $ 254 $ 0 $ 0 $ 254 Commercial 121 0 0 121 Industrial 32 0 0 32 Regulatory deferrals and unbilled revenue (3 ) 0 0 (3 ) Other (1) 50 0 (1 ) 49 Total electric revenue 454 0 (1 ) 453 Gas revenue Residential 0 36 0 36 Commercial 0 28 0 28 Industrial (2) 0 5 0 5 Other (3) 0 28 (1 ) 27 Total gas revenue 0 97 (1 ) 96 Total revenue $ 454 $ 97 $ (2 ) $ 549 Three months ended June 30, 2019 Electric revenue Residential $ 261 $ 0 $ 0 $ 261 Commercial 141 0 0 141 Industrial 42 0 0 42 Regulatory deferrals and unbilled revenue 17 0 0 17 Other (1) 60 0 (1 ) 59 Total electric revenue 521 0 (1 ) 520 Gas revenue Residential 0 36 0 36 Commercial 0 35 0 35 Industrial (2) 0 6 0 6 Other (3) 0 34 (4 ) 30 Total gas revenue 0 111 (4 ) 107 Total revenue $ 521 $ 111 $ (5 ) $ 627 (millions) Tampa Tampa Electric Six months ended June 30, 2020 Electric PGS Eliminations Company Electric revenue Residential $ 459 $ 0 $ 0 $ 459 Commercial 246 0 0 246 Industrial 69 0 0 69 Regulatory deferrals and unbilled revenue (5 ) 0 0 (5 ) Other (1) 106 0 (2 ) 104 Total electric revenue 875 0 (2 ) 873 Gas revenue Residential 0 84 0 84 Commercial 0 69 0 69 Industrial (2) 0 11 0 11 Other (3) 0 63 (4 ) 59 Total gas revenue 0 227 (4 ) 223 Total revenue $ 875 $ 227 $ (6 ) $ 1,096 Six months ended June 30, 2019 Electric revenue Residential $ 467 $ 0 $ 0 $ 467 Commercial 261 0 0 261 Industrial 76 0 0 76 Regulatory deferrals and unbilled revenue 10 0 0 10 Other (1) 119 0 (2 ) 117 Total electric revenue 933 0 (2 ) 931 Gas revenue Residential 0 86 0 86 Commercial 0 77 0 77 Industrial (2) 0 11 0 11 Other (3) 0 69 (8 ) 61 Total gas revenue 0 243 (8 ) 235 Total revenue $ 933 $ 243 $ (10 ) $ 1,166 (1) Other electric revenue includes sales to public authorities, off-system sales to other utilities and various other items. (2) Industrial gas revenue includes sales to power generation customers. (3) Other gas revenue includes off-system sales to other utilities and various other items. Remaining performance obligations primarily represent lighting contracts and gas transportation contracts with fixed contract terms. As of June 30, 2020 and December 31, 2019, the aggregate amount of the transaction price allocated to remaining performance obligations was approximately $140 million. As allowed under ASC 606, this amount excludes contracts with an original expected length of one year or less and variable amounts for which TEC recognizes revenue at the amount to which it has the right to invoice for services performed. TEC expects to recognize revenue for the remaining performance obligations through 2033.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2020
Fair Value Disclosures [Abstract]
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 a basis for considering assumptions that market participants would use in pricing an asset or liability, 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. There were no Level 3 assets or liabilities for the periods presented. As of June 30, 2020 and December 31, 2019, the carrying value of TEC’s short-term debt was not materially different from the fair value due to the short-term nature of the instruments and because the stated rates approximate market rates. The fair value of TEC’s short-term debt is determined using Level 2 measurements. See Note 7

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Principles of Consolidation and Basis of Presentation	Principles of Consolidation and Basis of Presentation TEC is a wholly owned subsidiary of TECO Energy, which is an indirect, wholly owned subsidiary of Emera. TEC is comprised of the electric division, referred to as Tampa Electric, and the natural gas division, referred to as PGS. Intercompany balances and transactions within the divisions 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, 2020 and December 31, 2019, and the results of operations and cash flows for the periods ended June 30, 2020 and June 30, 2019. The results of operations for the three and six months ended June 30, 2020 are not necessarily indicative of the results that can be expected for the entire fiscal year ending December 31, 2020. 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 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. Since December 31, 2019, the outbreak of the novel strain of coronavirus, specifically identified as COVID-19, has resulted in governments worldwide enacting emergency measures to combat the spread of the virus. While management considered the impact of COVID-19 in TEC’s estimates and results, the financial statements as of and for the three and six months ended June 30, 2020 were not significantly impacted by COVID-19. However, it is not possible to reliably estimate the length and severity of the COVID-19 pandemic and the impact on the financial results and condition of TEC in future periods. See Note 5
Receivables and Allowance for Uncollectible Accounts	Receivables and Allowance for Uncollectible Accounts Receivables from contracts with customers, which consist of services to residential, commercial, industrial and other customers, were $230 million and $205 million as of June 30, 2020 and December 31, 2019, respectively. An allowance for uncollectible accounts is established based on TEC’s collection experience and reasonable and supportable forecasts that affect the collectibility of the reported amount. Circumstances that could affect Tampa Electric’s and PGS’s estimates of uncollectible receivables include, but are not limited to, customer credit issues, fuel prices, customer deposits and general economic conditions, including the impacts of the COVID-19 pandemic. Accounts are reserved in the allowance or written off once they are deemed to be uncollectible. As of June 30, 2020 and December 31, 2019, unbilled revenues of $84 million and $61 million, respectively, are included in the “Receivables” line item on the Consolidated Condensed Balance Sheets.
Accounting for Franchise Fees and Gross Receipts	Accounting for Franchise Fees and Gross Receipts Tampa Electric and PGS are allowed to recover certain costs from customers on a dollar-for-dollar basis through rates 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 $26 million and $29 million for the three months ended June 30, 2020 and 2019, respectively, and $53 million and $56 million for the six months ended June 30, 2020 and 2019, respectively.

Regulatory (Tables)

Regulatory (Tables)	6 Months Ended
	Jun. 30, 2020
Regulated Operations [Abstract]
Schedule of Regulatory Assets and Regulatory Liabilities	Details of the regulatory assets and liabilities are presented in the following table: Regulatory Assets and Liabilities (millions) June 30, 2020 December 31, 2019 Regulatory assets: Regulatory tax asset (1) $ 87 $ 74 Cost-recovery clauses (2) 7 12 Environmental remediation (3) 21 20 Postretirement benefits (4) 287 295 Asset retirement obligation (5) 16 25 Other 10 11 Total regulatory assets 428 437 Less: Current portion 39 41 Long-term regulatory assets $ 389 $ 396 Regulatory liabilities: Regulatory tax liability (6) $ 698 $ 699 Cost-recovery clauses (2) 70 37 Accumulated reserve - cost of removal (7) 500 506 Storm reserve (8) 48 48 Other 1 13 Total regulatory liabilities 1,317 1,303 Less: Current portion 110 93 Long-term regulatory liabilities $ 1,207 $ 1,210 (1) The regulatory tax asset is primarily associated with the depreciation and recovery of AFUDC-equity. This asset does not earn a return but rather is included in the capital structure, which is used in the calculation of the weighted cost of capital used to determine revenue requirements. It will be recovered over the expected life of the related assets. The regulatory tax asset balance reflects the impact of the federal tax rate reduction. (2) These assets and liabilities are related to FPSC clauses and riders. They are recovered or refunded through cost-recovery mechanisms approved by the FPSC on a dollar-for-dollar basis in the next year. (3) This asset is related to costs associated with environmental remediation primarily at MGP sites. The balance is included in rate base, partially offsetting the related liability, and earns a rate of return as permitted by the FPSC. The timing of recovery is based on a settlement agreement approved by the FPSC. (4) This asset is related to the deferred costs of postretirement benefits and it is amortized over the remaining service life of plan participants. Deferred costs of postretirement benefits that are included in expense are recognized as cost of service for rate-making purposes as permitted by the FPSC. (5) This asset is related to costs associated with an asset retirement obligation, which is a legal obligation for the future retirement of certain tangible, long-lived assets. This regulatory asset does not earn a return because it is offset with related assets and liabilities within rate base. It is recovered and removed as the obligation is settled and removed as the activities for the retirement of the related assets have been completed. (6) The regulatory tax liability is primarily related to the revaluation of TEC’s deferred income tax balances recorded on December 31, 2017 at the lower income tax rate due to U.S. tax reform. The liability related to the revaluation of the deferred income tax balances is amortized and returned to customers through rate reductions or other revenue offsets based on IRS regulations and the settlement agreement for tax reform benefits approved by the FPSC. (7) This item represents the non-ARO cost of removal in the accumulated reserve for depreciation. AROs are costs for legally required removal of property, plant and equipment. Non-ARO cost of removal represents estimated funds received from customers through depreciation rates to cover future non-legally required cost of removal of property, plant and equipment, net of salvage value upon retirement, which reduces rate base for ratemaking purposes. This liability is reduced as costs of removal are incurred. (1) See “Tampa Electric Storm Restoration Cost Recovery” discussion above for information regarding this reserve.

Employee Postretirement Benef_2

Employee Postretirement Benefits (Tables)	6 Months Ended
	Jun. 30, 2020
TECO Energy [Member]
Schedule of Net Periodic Benefit Cost	The following table presents detail related to TECO Energy’s periodic benefit cost for pension and other postretirement benefits. Amounts disclosed for TECO Energy’s pension benefits include the amounts related to its qualified pension plan and non-qualified, non-contributory SERP and Restoration Plan. TECO Energy Benefit Cost (millions) Pension Benefits Other Postretirement Benefits Three months ended June 30, 2020 2019 2020 2019 Components of net periodic benefit cost Service cost $ 5 $ 5 $ 0 $ 0 Interest cost 6 8 2 1 Expected return on assets (12 ) (14 ) 0 0 Amortization of: Actuarial loss 5 5 0 0 Net periodic benefit cost $ 4 $ 4 $ 2 $ 1 Six months ended June 30, Components of net periodic benefit cost Service cost $ 10 $ 10 $ 0 $ 0 Interest cost 13 16 3 3 Expected return on assets (25 ) (26 ) 0 0 Amortization of: Actuarial loss 10 8 0 0 Settlement cost 0 1 (1) 0 0 Net periodic benefit cost $ 8 $ 9 $ 3 $ 3 (1) Represents TECO Energy’s SERP and Restoration Plan settlement charges as a result of the prior retirements of certain executives.

Short-Term Debt (Tables)

Short-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Short-Term Debt Credit Facilities and Related Borrowings	Details of TEC’s credit facilities and related borrowings are presented in the following table: June 30, 2020 December 31, 2019 Letters Letters Credit Borrowings of Credit Credit Borrowings of Credit (millions) Facilities Outstanding (1) Outstanding Facilities Outstanding (1) Outstanding 5-year facility (2) $ 400 $ 194 $ 1 $ 400 $ 295 $ 1 3-year accounts receivable facility (3) 150 0 0 150 53 0 1-year term facility (4) 300 300 0 0 0 0 Total $ 850 $ 494 $ 1 $ 550 $ 348 $ 1 (1) Borrowings outstanding are reported as notes payable. (2) This 5-year facility matures March 22, 2022. (3) This 3-year facility matures March 22, 2021. (4) This 1-year term facility matures on February 4, 2021.

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2020
Commitments And Contingencies Disclosure [Abstract]
Schedule of Long-term Commitments	The following is a schedule of future payments under PPAs, minimum lease payments with non-cancelable lease terms in excess of one year, and other net purchase obligations/commitments at June 30, 2020: Long-term Demand Purchased Capital Fuel and Service Operating Side (millions) Power Transportation Projects Gas Supply Agreements Leases Management Total 2020 $ 31 $ 108 $ 118 $ 101 $ 30 $ 1 $ 2 $ 391 2021 3 234 84 52 6 3 3 385 2022 0 236 79 2 9 3 3 332 2023 0 208 68 1 12 3 0 292 2024 0 197 0 0 19 3 0 219 Thereafter 0 1,915 0 0 41 51 0 2,007 Total future minimum payments $ 34 $ 2,898 $ 349 $ 156 $ 117 $ 64 $ 8 $ 3,626

Segment Information (Tables)

Segment Information (Tables)	6 Months Ended
	Jun. 30, 2020
Segment Reporting [Abstract]
Schedule of Segment Information	(millions) Tampa Tampa Electric Three months ended June 30, Electric PGS Eliminations Company 2020 Revenues - external $ 453 $ 96 $ 0 $ 549 Intracompany sales 1 1 (2 ) 0 Total revenues 454 97 (2 ) 549 Total interest charges 28 4 0 32 Net income $ 106 $ 11 $ 0 $ 117 2019 Revenues - external $ 520 $ 107 $ 0 $ 627 Intracompany sales 1 4 (5 ) 0 Total revenues 521 111 (5 ) 627 Total interest charges 29 4 0 33 Net income $ 93 $ 14 $ 0 $ 107 Six months ended June 30, 2020 Revenues - external $ 873 $ 223 $ 0 $ 1,096 Intracompany sales 2 4 (6 ) 0 Total revenues 875 227 (6 ) 1,096 Total interest charges 58 8 0 66 Net income $ 165 $ 29 $ 0 $ 194 2019 Revenues - external $ 931 $ 235 $ 0 $ 1,166 Intracompany sales 2 8 (10 ) 0 Total revenues 933 243 (10 ) 1,166 Total interest charges 58 8 0 66 Net income $ 139 $ 32 $ 0 $ 171 Total assets at June 30, 2020 $ 9,409 $ 1,710 $ (630 ) (1) $ 10,489 Total assets at December 31, 2019 $ 9,007 $ 1,593 $ (593 ) (1) $ 10,007 (1) Amounts primarily relate to consolidated deferred tax reclassifications. Deferred tax assets are reclassified and netted with deferred tax liabilities upon consolidation.

Revenue (Tables)

Revenue (Tables)	6 Months Ended
	Jun. 30, 2020
Revenue Recognition [Abstract]
Summary of Disaggregates TEC Revenue by Major Source	The following disaggregates TEC’s revenue by major source: (millions) Tampa Tampa Electric Three months ended June 30, 2020 Electric PGS Eliminations Company Electric revenue Residential $ 254 $ 0 $ 0 $ 254 Commercial 121 0 0 121 Industrial 32 0 0 32 Regulatory deferrals and unbilled revenue (3 ) 0 0 (3 ) Other (1) 50 0 (1 ) 49 Total electric revenue 454 0 (1 ) 453 Gas revenue Residential 0 36 0 36 Commercial 0 28 0 28 Industrial (2) 0 5 0 5 Other (3) 0 28 (1 ) 27 Total gas revenue 0 97 (1 ) 96 Total revenue $ 454 $ 97 $ (2 ) $ 549 Three months ended June 30, 2019 Electric revenue Residential $ 261 $ 0 $ 0 $ 261 Commercial 141 0 0 141 Industrial 42 0 0 42 Regulatory deferrals and unbilled revenue 17 0 0 17 Other (1) 60 0 (1 ) 59 Total electric revenue 521 0 (1 ) 520 Gas revenue Residential 0 36 0 36 Commercial 0 35 0 35 Industrial (2) 0 6 0 6 Other (3) 0 34 (4 ) 30 Total gas revenue 0 111 (4 ) 107 Total revenue $ 521 $ 111 $ (5 ) $ 627 (millions) Tampa Tampa Electric Six months ended June 30, 2020 Electric PGS Eliminations Company Electric revenue Residential $ 459 $ 0 $ 0 $ 459 Commercial 246 0 0 246 Industrial 69 0 0 69 Regulatory deferrals and unbilled revenue (5 ) 0 0 (5 ) Other (1) 106 0 (2 ) 104 Total electric revenue 875 0 (2 ) 873 Gas revenue Residential 0 84 0 84 Commercial 0 69 0 69 Industrial (2) 0 11 0 11 Other (3) 0 63 (4 ) 59 Total gas revenue 0 227 (4 ) 223 Total revenue $ 875 $ 227 $ (6 ) $ 1,096 Six months ended June 30, 2019 Electric revenue Residential $ 467 $ 0 $ 0 $ 467 Commercial 261 0 0 261 Industrial 76 0 0 76 Regulatory deferrals and unbilled revenue 10 0 0 10 Other (1) 119 0 (2 ) 117 Total electric revenue 933 0 (2 ) 931 Gas revenue Residential 0 86 0 86 Commercial 0 77 0 77 Industrial (2) 0 11 0 11 Other (3) 0 69 (8 ) 61 Total gas revenue 0 243 (8 ) 235 Total revenue $ 933 $ 243 $ (10 ) $ 1,166 (1) Other electric revenue includes sales to public authorities, off-system sales to other utilities and various other items. (2) Industrial gas revenue includes sales to power generation customers. (3) Other gas revenue includes off-system sales to other utilities and various other items.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Accounting Policies [Abstract]
Receivables from contracts with customers	$ 230		$ 230		$ 205
Unbilled revenues	84		84		$ 61
Franchise fees and gross receipts taxes	$ 26	$ 29	$ 53	$ 56

Regulatory - Additional Informa

Regulatory - Additional Information (Detail) $ in Millions

Aug. 03, 2020USD ($)

Apr. 27, 2020USD ($)

Jun. 28, 2019USD ($)MW

Apr. 09, 2019USD ($)

Aug. 20, 2018USD ($)

Jun. 29, 2018USD ($)MW

Dec. 12, 2017USD ($)MW

Sep. 27, 2017USD ($)MW

Jun. 30, 2020USD ($)

Jun. 30, 2019USD ($)

Sep. 30, 2017USD ($)

Jun. 30, 2020USD ($)

Jun. 30, 2019USD ($)

Dec. 31, 2019USD ($)

Jun. 09, 2020USD ($)

Jun. 01, 2020USD ($)

Oct. 31, 2013USD ($)

Public Utilities General Disclosures [Line Items]

Federal statutory tax rate

4.50%

5.50%

Decrease in deferred income taxes offset to regulatory liability

$ 5

Utility plant, at original costs

$ 13,143

13,143

$ 12,590

Accumulated depreciation

3,579

3,579

3,472

Provision for income taxes

24

$ 24

40

$ 40

Amount refundable on settlement

$ 12

Hurricane Irma [Member]

Public Utilities General Disclosures [Line Items]

Storm restoration costs

$ 102

Hurricane Dorian [Member]

Public Utilities General Disclosures [Line Items]

Storm restoration preparation costs

8

Tax Reform and Storm Settlement [Member]

Public Utilities General Disclosures [Line Items]

Provision for income taxes

103

Annually approved lowering base rates, Amount

$ 103

Intangible Software Assets [Member]

Public Utilities General Disclosures [Line Items]

Accumulated amortization reserve surplus

8

8

$ 16

Recognition of accumulated amortization reserve surplus

8

Electric Utility Plant [Member]

Public Utilities General Disclosures [Line Items]

Utility plant, at original costs

10,992

10,992

$ 10,578

Peoples Gas System [Member]

Public Utilities General Disclosures [Line Items]

Reduction in annual base rates

12

Reduction in annual depreciation rates

10

Requested increase in revenue

62

Solar Project Cost Recovery [Member]

Public Utilities General Disclosures [Line Items]

Settlement agreement, extended terms

four years through December 31, 2021

Settlement agreement, approval date

Nov. 6, 2017

Solar energy capacity | MW

600

Solar generation capacity investments

$ 850

Solar Project Cost Recovery [Member] | Solar Base Rate Adjustments [Member]

Public Utilities General Disclosures [Line Items]

Final net true-up amount expected to be refunded to customers

5

Solar Project Cost Recovery [Member] | Effective September 1, 2018 [Member]

Public Utilities General Disclosures [Line Items]

Solar energy capacity | MW

145

Estimated annual revenue requirements

$ 24

Solar Project Cost Recovery [Member] | Effective January 1, 2019 [Member]

Public Utilities General Disclosures [Line Items]

Solar energy capacity | MW

260

Estimated annual revenue requirements

$ 46

Solar Project Cost Recovery [Member] | Effective January 1, 2020 [Member]

Public Utilities General Disclosures [Line Items]

Solar energy capacity | MW

149

Estimated annual revenue requirements

$ 26

Solar Project Cost Recovery [Member] | Effective Date January 1, 2021 [Member]

Public Utilities General Disclosures [Line Items]

Solar energy capacity | MW

50

Solar base rate adjustments

$ 10

Solar Project Cost Recovery [Member] | Minimum [Member]

Public Utilities General Disclosures [Line Items]

Solar project investment term

2017

Solar Project Cost Recovery [Member] | Maximum [Member]

Public Utilities General Disclosures [Line Items]

Solar project investment term

2021

Big Bend Modernization Project [Member]

Public Utilities General Disclosures [Line Items]

Energy generation capacity investments

850

850

Investments in energy projects till date

$ 414

$ 414

Accumulated depreciation

$ 90

Big Bend Modernization Project [Member] | Electric Utility Plant [Member]

Public Utilities General Disclosures [Line Items]

Utility plant, at original costs

$ 223

Big Bend Modernization Project [Member] | Minimum [Member]

Public Utilities General Disclosures [Line Items]

Energy project investment term

2018

Big Bend Modernization Project [Member] | Maximum [Member]

Public Utilities General Disclosures [Line Items]

Energy project investment term

2023

Storm Protection Plan [Member]

Public Utilities General Disclosures [Line Items]

Reduction in annual base rates

$ 15

Storm Protection Plan [Member] | Subsequent Event [Member]

Public Utilities General Disclosures [Line Items]

Cost recovery from settlement agreement

$ 39

Storm Restoration Cost Recovery [Member]

Public Utilities General Disclosures [Line Items]

Minimum cost recovery period

12 months

Replenishment reserve for recovery of cost

$ 56

Regulatory - Schedule of Regula

Regulatory - Schedule of Regulatory Assets and Regulatory Liabilities (Detail) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Regulatory assets:
Regulatory assets	$ 428	$ 437
Less: Current portion	39	41
Long-term regulatory assets	389	396
Regulatory liabilities:
Regulatory liabilities	1,317	1,303
Less: Current portion	110	93
Long-term regulatory liabilities	1,207	1,210
Regulatory Tax Asset [Member]
Regulatory assets:
Regulatory assets	87	74
Cost-Recovery Clauses [Member]
Regulatory assets:
Regulatory assets	7	12
Environmental Remediation [Member]
Regulatory assets:
Regulatory assets	21	20
Postretirement Benefits [Member]
Regulatory assets:
Regulatory assets	287	295
Asset Retirement Obligation [Member]
Regulatory assets:
Regulatory assets	16	25
Other [Member]
Regulatory assets:
Regulatory assets	10	11
Regulatory Tax Liability [Member] | Non-Current Liabilities [Member]
Regulatory liabilities:
Regulatory liabilities	698	699
Cost-Recovery Clauses [Member]
Regulatory liabilities:
Regulatory liabilities	70	37
Storm Reserve [Member]
Regulatory liabilities:
Regulatory liabilities	48	48
Accumulated Reserve - Cost of Removal [Member]
Regulatory liabilities:
Regulatory liabilities	500	506
Other [Member]
Regulatory liabilities:
Regulatory liabilities	$ 1	$ 13

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Income Taxes [Line Items]
Unrecognized tax benefits	$ 9		$ 9
Unrecognized tax benefit that would reduce effective tax rate	$ 9		$ 9
Tampa Electric [Member]
Income Taxes [Line Items]
Effective tax rate	17.10%	19.00%

Employee Postretirement Benef_3

Employee Postretirement Benefits - Schedule of Net Periodic Benefit Cost (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Pension Benefits [Member]
Amortization of:
Net periodic benefit cost	$ 3	$ 3	$ 6	$ 7
Other Postretirement Benefits [Member]
Amortization of:
Net periodic benefit cost	1	1	3	3
TECO Energy [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	5	5	10	10
Interest cost	6	8	13	16
Expected return on assets	(12)	(14)	(25)	(26)
Amortization of:
Actuarial loss	5	5	10	8
Settlement cost			0	1
Net periodic benefit cost	4	4	8	9
TECO Energy [Member] | Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	0	0	0	0
Interest cost	2	1	3	3
Expected return on assets	0	0	0	0
Amortization of:
Actuarial loss	0	0	0	0
Settlement cost			0	0
Net periodic benefit cost	$ 2	$ 1	$ 3	$ 3

Employee Postretirement Benef_4

Employee Postretirement Benefits - Additional Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Defined Benefit Plan Disclosure [Line Items]
Reclassification of regulatory assets to net income as part of periodic benefit cost	$ 4	$ 3	$ 9	$ 6
TECO Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Long-term EROA			7.00%
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	3	3	$ 6	7
Employer contributions			8	5
Employer contributions in remainder of year	8		8
Pension Benefits [Member] | TECO Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	4	4	$ 8	9
Discount rate			3.22%
Employer contributions			$ 10	7
Employer contributions in remainder of year	10		10
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	1	1	3	3
Other Postretirement Benefits [Member] | TECO Energy [Member]
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost	$ 2	$ 1	$ 3	$ 3
Discount rate			3.32%

Short-Term Debt - Credit Facili

Short-Term Debt - Credit Facilities and Related Borrowings (Detail) - USD ($)	Jun. 30, 2020	Dec. 31, 2019
Line Of Credit Facility [Line Items]
Credit Facilities	$ 850,000,000	$ 550,000,000
Borrowings Outstanding	494,000,000	348,000,000
Letters of Credit Outstanding	1,000,000	1,000,000
5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	400,000,000	400,000,000
Borrowings Outstanding	194,000,000	295,000,000
Letters of Credit Outstanding	1,000,000	1,000,000
1-year Term Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	300,000,000	0
Borrowings Outstanding	300,000,000	0
Letters of Credit Outstanding	0	0
3-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Credit Facilities	150,000,000	150,000,000
Borrowings Outstanding	0	53,000,000
Letters of Credit Outstanding	$ 0	$ 0

Short-Term Debt - Credit Faci_2

Short-Term Debt - Credit Facilities and Related Borrowings (Parenthetical) (Detail)	6 Months Ended	12 Months Ended
	Jun. 30, 2020	Dec. 31, 2019
5-year Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Mar. 22, 2022	Mar. 22, 2022
3-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Mar. 22, 2021	Mar. 22, 2021
1-year Term Facility [Member]
Line Of Credit Facility [Line Items]
Credit facility maturity date	Feb. 4, 2021	Feb. 4, 2021

Short-Term Debt - Additional In

Short-Term Debt - Additional Information (Detail) - USD ($)	Jul. 14, 2020	Feb. 06, 2020	Jun. 30, 2020	Dec. 31, 2019
Line Of Credit Facility [Line Items]
Weighted-average interest rate			0.83%	2.56%
Line of credit facility maximum borrowing capacity			$ 850,000,000	$ 550,000,000
Borrowings Outstanding			494,000,000	348,000,000
3-year Accounts Receivable Facility [Member]
Line Of Credit Facility [Line Items]
Line of credit facility maximum borrowing capacity			150,000,000	150,000,000
Borrowings Outstanding			$ 0	$ 53,000,000
Credit facility maturity date			Mar. 22, 2021	Mar. 22, 2021
3-year Accounts Receivable Facility [Member] | Subsequent Event [Member]
Line Of Credit Facility [Line Items]
Credit facility amendment date	Jul. 14, 2020
Line of credit facility maximum borrowing capacity	$ 150,000,000
364-day Credit Agreement [Member]
Line Of Credit Facility [Line Items]
Line of credit facility maximum borrowing capacity		$ 300,000,000
Credit facility maturity period		364 days
Credit facility maturity date		Feb. 4, 2021
Minimum [Member]
Line Of Credit Facility [Line Items]
Commitment fees, percentage			0.125%
Maximum [Member]
Line Of Credit Facility [Line Items]
Commitment fees, percentage			0.35%

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Debt Disclosure [Abstract]
Long-term debt	$ 2,870	$ 2,869
Estimated fair value	$ 3,482	$ 3,335

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) $ in Millions	Jun. 30, 2020USD ($)
PGS [Member]
Long Term Commitments [Line Items]
Ultimate financial liability to superfund sites and former MGP sites	$ 21

Commitments and Contingencies_2

Commitments and Contingencies - Schedule of Long-term Commitments (Detail) $ in Millions	Jun. 30, 2020USD ($)
Other Commitments [Line Items]
2020	$ 391
2021	385
2022	332
2023	292
2024	219
Thereafter	2,007
Total future minimum payments	3,626
Purchased Power [Member]
Other Commitments [Line Items]
2020	31
2021	3
2022	0
2023	0
2024	0
Thereafter	0
Total future minimum payments	34
Transportation [Member]
Other Commitments [Line Items]
2020	108
2021	234
2022	236
2023	208
2024	197
Thereafter	1,915
Total future minimum payments	2,898
Capital Projects [Member]
Other Commitments [Line Items]
2020	118
2021	84
2022	79
2023	68
2024	0
Thereafter	0
Total future minimum payments	349
Fuel and Gas Supply [Member]
Other Commitments [Line Items]
2020	101
2021	52
2022	2
2023	1
2024	0
Thereafter	0
Total future minimum payments	156
Long-term Service Agreements [Member]
Other Commitments [Line Items]
2020	30
2021	6
2022	9
2023	12
2024	19
Thereafter	41
Total future minimum payments	117
Operating Leases [Member]
Other Commitments [Line Items]
2020	1
2021	3
2022	3
2023	3
2024	3
Thereafter	51
Total future minimum payments	64
Demand Side Management [Member]
Other Commitments [Line Items]
2020	2
2021	3
2022	3
2023	0
2024	0
Thereafter	0
Total future minimum payments	$ 8

Segment Information - Schedule

Segment Information - Schedule of Segment Information (Detail) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Segment Reporting Information [Line Items]
Total revenues	$ 549	$ 627	$ 1,096	$ 1,166
Total interest charges	32	33	66	66
Net income	117	107	194	171
Total assets	10,489		10,489		$ 10,007
Revenues - External [Member]
Segment Reporting Information [Line Items]
Total revenues	549	627	1,096	1,166
Intracompany Sales [Member]
Segment Reporting Information [Line Items]
Intracompany sales	0	0	0	0
Eliminations [Member]
Segment Reporting Information [Line Items]
Total revenues	(2)	(5)	(6)	(10)
Total interest charges	0	0	0	0
Net income	0	0	0	0
Total assets	(630)		(630)		(593)
Eliminations [Member] | Revenues - External [Member]
Segment Reporting Information [Line Items]
Total revenues	0	0	0	0
Eliminations [Member] | Intracompany Sales [Member]
Segment Reporting Information [Line Items]
Intracompany sales	(2)	(5)	(6)	(10)
Tampa Electric [Member]
Segment Reporting Information [Line Items]
Total revenues	454	521	875	933
Tampa Electric [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	454	521	875	933
Total interest charges	28	29	58	58
Net income	106	93	165	139
Total assets	9,409		9,409		9,007
Tampa Electric [Member] | Operating Segments [Member] | Revenues - External [Member]
Segment Reporting Information [Line Items]
Total revenues	453	520	873	931
Tampa Electric [Member] | Operating Segments [Member] | Intracompany Sales [Member]
Segment Reporting Information [Line Items]
Intracompany sales	1	1	2	2
PGS [Member]
Segment Reporting Information [Line Items]
Total revenues	97	111	227	243
PGS [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total revenues	97	111	227	243
Total interest charges	4	4	8	8
Net income	11	14	29	32
Total assets	1,710		1,710		$ 1,593
PGS [Member] | Operating Segments [Member] | Revenues - External [Member]
Segment Reporting Information [Line Items]
Total revenues	96	107	223	235
PGS [Member] | Operating Segments [Member] | Intracompany Sales [Member]
Segment Reporting Information [Line Items]
Intracompany sales	$ 1	$ 4	$ 4	$ 8

Revenue - Summary of Disaggrega

Revenue - Summary of Disaggregates TEC Revenue by Major Source (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Disaggregation Of Revenue [Line Items]
Total electric revenue	$ 453	$ 520	$ 873	$ 931
Total gas revenue	96	107	223	235
Total revenue	549	627	1,096	1,166
Residential [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	254	261	459	467
Total gas revenue	36	36	84	86
Commercial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	121	141	246	261
Total gas revenue	28	35	69	77
Industrial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	32	42	69	76
Total gas revenue	5	6	11	11
Regulatory Deferrals and Unbilled Revenue [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	(3)	17	(5)	10
Other [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	49	59	104	117
Total gas revenue	27	30	59	61
Tampa Electric [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	454	521	875	933
Total gas revenue	0	0	0	0
Total revenue	454	521	875	933
Tampa Electric [Member] | Residential [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	254	261	459	467
Total gas revenue	0	0	0	0
Tampa Electric [Member] | Commercial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	121	141	246	261
Total gas revenue	0	0	0	0
Tampa Electric [Member] | Industrial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	32	42	69	76
Total gas revenue	0	0	0	0
Tampa Electric [Member] | Regulatory Deferrals and Unbilled Revenue [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	(3)	17	(5)	10
Tampa Electric [Member] | Other [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	50	60	106	119
Total gas revenue	0	0	0	0
PGS [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	97	111	227	243
Total revenue	97	111	227	243
PGS [Member] | Residential [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	36	36	84	86
PGS [Member] | Commercial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	28	35	69	77
PGS [Member] | Industrial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	5	6	11	11
PGS [Member] | Regulatory Deferrals and Unbilled Revenue [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
PGS [Member] | Other [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	28	34	63	69
Eliminations [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	(1)	(1)	(2)	(2)
Total gas revenue	(1)	(4)	(4)	(8)
Total revenue	(2)	(5)	(6)	(10)
Eliminations [Member] | Residential [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	0	0	0	0
Eliminations [Member] | Commercial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	0	0	0	0
Eliminations [Member] | Industrial [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Total gas revenue	0	0	0	0
Eliminations [Member] | Regulatory Deferrals and Unbilled Revenue [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	0	0	0	0
Eliminations [Member] | Other [Member]
Disaggregation Of Revenue [Line Items]
Total electric revenue	(1)	(1)	(2)	(2)
Total gas revenue	$ (1)	$ (4)	$ (4)	$ (8)

Revenue - Additional Informatio

Revenue - Additional Information (Details) - USD ($) $ in Millions	Jun. 30, 2020	Dec. 31, 2019
Regulated Operating Revenue [Abstract]
Remaining performance obligations, transaction price	$ 140	$ 140
Remaining performance obligations, expected year of revenue recognition	2033