Kentucky Utilities 10-K 17 Feb 23 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2022	Jan. 31, 2023	Jun. 30, 2022
Document Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Document Transition Report	false
Entity File Number	1-11459
Entity Registrant Name	PPL Corporation
Entity Tax Identification Number	23-2758192
Entity Incorporation State Country Code	PA
Entity Address, Address Line One	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
Title of 12(g) Security	Common Stock of PPL Electric Utilities Corporation
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		736,677,854
Entity Public Float			$ 19,971,944,185
Amendment Flag	false
Entity Central Index Key	0000922224
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Document Fiscal Period Focus	2021
Document Fiscal Period Focus	FY
Documents Incorporated by Reference	PPL Corporation has incorporated herein by reference certain sections of PPL Corporation's 2023 Notice of Annual Meeting and Proxy Statement, which will be filed with the Securities and Exchange Commission not later than 120 days after December 31, 2022 and which will provide the information required by Part III of this Report.
ICFR Auditor Attestation Flag	true
Auditor Name	Deloitte & Touche LLP
Auditor Location	Morristown, New Jersey
Auditor Firm ID	34
2007 Series A Due 2067 [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	2007 Series A due 2067
Trading Symbol	PPL/67
Security Exchange Name	NYSE
Common Stock [Member]
Document Entity Information [Line Items]
Title of 12(b) Security	Common Stock of PPL Corporation
Trading Symbol	PPL
Security Exchange Name	NYSE
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Entity File Number	1-905
Entity Registrant Name	PPL Electric Utilities Corporation
Entity Tax Identification Number	23-0959590
Entity Incorporation State Country Code	PA
Entity Address, Address Line One	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		66,368,056
Amendment Flag	false
Entity Central Index Key	0000317187
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
Auditor Name	Deloitte & Touche LLP
Auditor Location	Morristown, New Jersey
Auditor Firm ID	34
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Entity File Number	1-2893
Entity Registrant Name	Louisville Gas and Electric Company
Entity Tax Identification Number	61-0264150
Entity Incorporation State Country Code	KY
Entity Address, Address Line One	220 West Main Street
Entity Address, City or Town	Louisville,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40202-1377
City Area Code	(502)
Local Phone Number	627-2000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		21,294,223
Amendment Flag	false
Entity Central Index Key	0000060549
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	false
Auditor Name	Deloitte & Touche LLP
Auditor Location	Louisville, Kentucky
Auditor Firm ID	34
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Entity File Number	1-3464
Entity Registrant Name	Kentucky Utilities Company
Entity Tax Identification Number	61-0247570
Entity Incorporation State Country Code	KY
Entity Address, Address Line One	One Quality Street
Entity Address, City or Town	Lexington,
Entity Address, State or Province	KY
Entity Address, Postal Zip Code	40507-1462
City Area Code	(502)
Local Phone Number	627-2000
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		37,817,878
Amendment Flag	false
Entity Central Index Key	0000055387
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Incorporation State Country Code	Virginia
ICFR Auditor Attestation Flag	false
Auditor Name	Deloitte & Touche LLP
Auditor Location	Louisville, Kentucky
Auditor Firm ID	34

CONSOLIDATED STATEMENTS OF INCO

CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Thousands, $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating Revenues
Operating Revenues		$ 7,902	$ 5,783	$ 5,474
Operation
Fuel		931	710	632
Energy purchases		1,686	752	634
Other operation and maintenance		2,398	1,608	1,420
Depreciation		1,181	1,082	1,022
Taxes, other than income		332	207	180
Total Operating Expenses		6,528	4,359	3,888
Operating Income		1,374	1,424	1,586
Other Income (Expense) - net		54	15	2
Interest Expense		513	918	634
Income from Continuing Operations Before Income Taxes		915	521	954
Income Taxes		201	503	314
Income from Continuing Operations After Income Taxes		714	18	640
Income (Loss) from Discontinued Operations (net of income taxes)		42	(1,498)	829
Net income (Loss)		$ 756	$ (1,480)	$ 1,469
Earnings per Share of Common Stock [Abstract]
Income from Continuing Operations After Income Taxes, Per Basic Share		$ 0.97	$ 0.03	$ 0.83
Income (Loss) from Discontinued Operation ( net of income taxes), Per Basic Shares		0.06	(1.96)	1.08
Net Income (Loss) Available to PPL Common , Per Basic shares		1.03	(1.93)	1.91
Income from Continuing Operations After Income Taxes, Per Diluted Share		0.96	0.03	0.83
Net Income (Loss) Available to PPL Common Shareowners, Per Diluted Shares		1.02	(1.93)	1.91
Income (Loss) from Discontinued Operations (net of income taxes), Per Diluted Shares		$ 0.06	$ (1.96)	$ 1.08
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		736,027	762,902	768,590
Diluted		736,902	764,819	769,384
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 3,030	$ 2,402	$ 2,331
Operation
Energy purchases		1,048	566	491
Other operation and maintenance		605	557	513
Depreciation		393	424	403
Taxes, other than income		149	120	107
Total Operating Expenses		2,195	1,667	1,514
Operating Income		835	735	817
Interest Income from Affiliate		5	5	2
Other Income (Expense) - net		30	21	18
Interest Expense		171	162	173
Income from Continuing Operations Before Income Taxes		699	599	664
Income Taxes		174	154	167
Net income (Loss)	[1]	525	445	497
Louisville Gas And Electric Co [Member]
Operating Revenues
Retail and wholesale		1,762	1,545	1,435
Electric revenue from affiliates		36	24	21
Operating Revenues		1,798	1,569	1,456
Operation
Fuel		346	265	246
Energy purchases		245	167	125
Energy purchases from affiliate		25	23	19
Other operation and maintenance		416	400	373
Depreciation		298	279	259
Taxes, other than income		48	46	40
Total Operating Expenses		1,378	1,180	1,062
Operating Income		420	389	394
Other Income (Expense) - net		4	(5)	(1)
Interest Expense		89	81	87
Income from Continuing Operations Before Income Taxes		335	303	306
Income Taxes		63	54	62
Net income (Loss)	[2]	272	249	244
Kentucky Utilities Co [Member]
Operating Revenues
Retail and wholesale		2,049	1,803	1,671
Electric revenue from affiliates		25	23	19
Operating Revenues		2,074	1,826	1,690
Operation
Fuel		585	445	386
Energy purchases		28	19	18
Energy purchases from affiliate		36	24	21
Other operation and maintenance		487	463	429
Depreciation		386	366	346
Taxes, other than income		45	41	37
Total Operating Expenses		1,567	1,358	1,237
Operating Income		507	468	453
Other Income (Expense) - net		8	4	3
Interest Expense		117	109	113
Income from Continuing Operations Before Income Taxes		398	363	343
Income Taxes		76	67	63
Net income (Loss)	[3]	$ 322	$ 296	$ 280
[1]Net income equals comprehensive income.[2]Net income equals comprehensive income.[3]Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Net income (loss)	$ 756	$ (1,480)	$ 1,469
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Foreign currency translation adjustments, net of tax	0	372	267
Qualifying derivatives, net of tax	0	(39)	(19)
Equity investee's other comprehensive income after tax	2	0	0
Defined benefit plans:
Prior service costs, net of tax	(1)	0	(1)
Net actuarial gain (loss), net of tax	11	(1)	(341)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	2	25	24
Defined benefit plans:
Prior service costs, net of tax	2	2	3
Net actuarial (gain) loss, net of tax	17	126	205
Foreign currency translation adjustments, net of tax (UK Sale Reclassification)	0	786	0
Qualifying derivatives, net of tax (UK Sale Reclassification)	0	15	0
Total other comprehensive income (loss)	33	4,063	138
Comprehensive income	789	2,583	1,607
Net actuarial (gain) loss, net of tax (UK Sale Reclassification)	0	2,769	0
Prior service costs, net of tax (UK Sale Reclassification)	$ 0	$ 8	$ 0

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Tax effect of foreign currency translation adjustments arising during the period	$ 0	$ (123)	$ 0
Tax effect of qualifying derivatives arising during the period	0	11	5
Tax effect of defined benefit plans - prior service costs arising during period	0	0	0
Tax effect of defined benefit plans - net actuarial gain (loss) arising during period	(2)	1	74
Tax effect of qualifying derivatives reclassified from AOCI	(1)	(5)	(8)
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	(1)	(1)	(1)
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	(7)	(33)	(51)
Other Comprehensive Income (Loss), Foreign Currency Translation Gain (Loss), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	0	140	0
Other Comprehensive Income (Loss), Cash Flow Hedge, Gain (Loss), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	0	0	0
Other Comprehensive (Income) Loss, Defined Benefit Plan, Prior Service Cost (Credit), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	0	(2)	0
Other Comprehensive Income (Loss), Defined Benefit Plan, Gain (Loss), Reclassification Adjustment from AOCI, Realized upon Sale or Liquidation, Tax	0	(798)	0
OCI, Equity Method Investment, Tax	$ 0	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Cash Flows from Operating Activities
Net income (loss)		$ 756	$ (1,480)	$ 1,469
Loss (income) from discontinued operations (net of income taxes)		(42)	1,498	(829)
Income from Continuing Operations After Income Taxes		714	18	640
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		1,181	1,082	1,022
Amortization		52	39	58
Deferred income taxes and investment tax credits		179	87	169
Loss on sale of Safari Holdings		60	0	0
Impairment of solar panels		0	37	0
Loss on Extinguishment of Debt		0	395	0
Other		35	20	67
Change in current assets and current liabilities
Accounts receivable		(176)	(14)	(70)
Accounts payable		358	24	(1)
Unbilled Revenues		(197)	(5)	3
Fuel, materials and supplies		(90)	(21)	(9)
Taxes payable		(80)	27	131
Regulatory assets and liabilities, net		(119)	52	(63)
Other		(88)	(41)	124
Other operating activities
Defined benefit plans - funding		(12)	(53)	(119)
Other assets		(126)	(111)	(59)
Other liabilities		39	8	(21)
Net cash provided by operating activities - continuing operations		1,730	1,544	1,872
Net cash provided by operating activities - discontinued operations		0	726	874
Net cash provided by operating activities		1,730	2,270	2,746
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(2,155)	(1,973)	(2,270)
Proceeds from sale of Safari Holdings, net of cash divested		146	0	0
Proceeds from sale of U.K. utility business, net of cash divested		0	10,560	0
Acquisition of Narragansett Electric, net of cash acquired		(3,660)	0	0
Other investing activities		15	(23)	4
Net cash provided by (used in) investing activities - continuing operations		(5,654)	8,564	(2,266)
Net cash provided by (used in) investing activities - discontinued operations		0	(607)	(992)
Net cash provided by (used in) investing activities		(5,654)	7,957	(3,258)
Cash Flows from Financing Activities
Issuance of long-term debt		850	650	1,848
Retirement of long-term debt		(264)	(4,606)	(975)
Payment of common stock dividends		(787)	(1,279)	(1,275)
Purchase of treasury stock		0	(1,003)	0
Issuance of term loan		0	0	300
Issuance of commercial paper		0	0	73
Retirement of term loan		0	(300)	0
Retirement of commercial paper		0	(73)	0
Net increase (decrease) in short-term debt		916	(726)	(43)
Other investing activities		(6)	(7)	171
Net cash provided by (used in) financing activities - continuing operations		709	(7,344)	99
Net cash provided by (used in) financing activities - discontinued operations		0	(411)	209
Contributions from discontinued operations		0	365	78
Net cash provided by (used in) financing activities		709	(7,390)	386
Effect of Exchange Rates on Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations		0	8	17
Net (Increase) Decrease in Cash, Cash Equivalents and Restricted Cash included in Discontinued Operations		0	284	(108)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(3,215)	3,129	(217)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		3,572	443	660
Cash, Cash Equivalents and Restricted Cash at End of Period		357	3,572	443
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		462	191	586
Income taxes - net		163	284	4
Accrued expenditures for property, plant and equipment at December 31,		269	245	257
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	525	445	497
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		393	424	403
Amortization		22	19	26
Defined benefit plans - expense (income)		(23)	(10)	(1)
Deferred income taxes and investment tax credits		91	79	83
Other		(11)	(19)	(5)
Change in current assets and current liabilities
Accounts receivable		(47)	(9)	(47)
Accounts payable		46	(3)	21
Unbilled Revenues		(95)	(8)	13
Fuel, materials and supplies		(11)	(5)	(18)
Prepayments		(2)	(4)	(3)
Taxes payable		5	14	4
Regulatory assets and liabilities, net		(59)	96	(40)
Other		(19)	(1)	(10)
Other operating activities
Defined benefit plans - funding		0	(21)	(21)
Other assets		(47)	(12)	(28)
Other liabilities		(11)	(16)	10
Net cash provided by operating activities		757	969	884
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(886)	(898)	(1,145)
Expenditures for intangible assets		(2)	(6)	(9)
Net (increase) decrease in notes receivable from affiliate		499	(499)	0
Other investing activities		2	3	3
Net cash provided by (used in) investing activities		(387)	(1,400)	(1,151)
Cash Flows from Financing Activities
Issuance of long-term debt		250	650	250
Retirement of long-term debt		(250)	(400)	0
Contributions from parent		0	1,075	940
Payment of common stock dividends to parent		(340)	(334)	(400)
Return of Capital to Parent		(170)	(574)	(745)
Net increase (decrease) in short-term debt		145	0	0
Other investing activities		(1)	(5)	(2)
Net cash provided by (used in) financing activities		(366)	412	43
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		4	(19)	(224)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		21	40	264
Cash, Cash Equivalents and Restricted Cash at End of Period		25	21	40
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		164	156	158
Income taxes - net		111	64	67
Accrued expenditures for property, plant and equipment at December 31,		133	118	156
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[2]	272	249	244
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		298	279	259
Amortization		5	2	9
Defined benefit plans - expense (income)		0	1	3
Deferred income taxes and investment tax credits		(6)	8	3
Other		4	0	0
Change in current assets and current liabilities
Accounts receivable		(19)	(11)	(3)
Accounts receivable from affiliates		(5)	(13)	4
Accounts payable		22	32	(18)
Accounts payable to affiliates		30	(4)	(5)
Unbilled Revenues		(32)	(1)	(3)
Fuel, materials and supplies		(28)	(17)	4
Taxes payable		7	2	(1)
Regulatory assets and liabilities, net		17	(23)	0
Other		5	(18)	(3)
Other operating activities
Defined benefit plans - funding		(2)	(3)	(11)
Expenditures for asset retirement obligations		(13)	(27)	(20)
Other assets		(8)	2	(2)
Other liabilities		(4)	0	23
Net cash provided by operating activities		543	458	483
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(371)	(466)	(456)
Other investing activities		(11)	0	0
Net cash provided by (used in) investing activities		(360)	(466)	(456)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliates		(324)	324	0
Issuance of long-term debt		300	0	0
Issuance of commercial paper		0	0	41
Retirement of commercial paper		0	(41)	0
Net increase (decrease) in short-term debt		110	(152)	(17)
Contributions from parent		90	74	103
Payment of common stock dividends to parent		(275)	(192)	(161)
Other investing activities		0	(3)	(1)
Net cash provided by (used in) financing activities		(99)	10	(35)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		84	2	(8)
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		83	77	82
Income taxes - net		57	52	63
Accrued expenditures for property, plant and equipment at December 31,		43	60	60
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	322	296	280
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		386	366	346
Amortization		18	12	8
Defined benefit plans - expense (income)		(4)	(3)	0
Deferred income taxes and investment tax credits		2	1	20
Other		3	(3)	(1)
Change in current assets and current liabilities
Accounts receivable		(16)	6	(13)
Accounts receivable from affiliates		0	1	(1)
Accounts payable		26	(12)	9
Accounts payable to affiliates		37	15	(16)
Unbilled Revenues		(23)	6	(9)
Fuel, materials and supplies		(41)	1	6
Taxes payable		7	(10)	2
Regulatory assets and liabilities, net		(19)	(22)	(26)
Other		(3)	(18)	(5)
Other operating activities
Defined benefit plans - funding		(1)	(1)	(3)
Expenditures for asset retirement obligations		(29)	(36)	(64)
Other assets		(1)	9	(2)
Other liabilities		(4)	0	12
Net cash provided by operating activities		661	608	543
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(547)	(560)	(510)
Other investing activities		0	4	3
Net cash provided by (used in) investing activities		(547)	(556)	(507)
Cash Flows from Financing Activities
Net increase (decrease) in notes payable with affiliates		(294)	294	0
Issuance of long-term debt		300	0	498
Retirement of long-term debt		0	0	(500)
Issuance of commercial paper		0	0	32
Retirement of commercial paper		0	(32)	0
Net increase (decrease) in short-term debt		101	(171)	21
Contributions from parent		84	100	128
Payment of common stock dividends to parent		(296)	(250)	(200)
Other investing activities		(1)	(2)	(5)
Net cash provided by (used in) financing activities		(106)	(61)	(26)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		8	(9)	10
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		112	105	109
Income taxes - net		78	72	44
Accrued expenditures for property, plant and equipment at December 31,		56	67	40
Accrued interest		$ 1	$ 0	$ 0
[1]Net income equals comprehensive income.[2]Net income equals comprehensive income.[3]Net income equals comprehensive income.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions		Dec. 31, 2022	Dec. 31, 2021
Current Assets
Cash and cash equivalents		$ 356	$ 3,571
Accounts receivable (less reserve:)
Customer		896	583
Other		150	58
Unbilled revenues		552	307
Fuel, materials and supplies		443	322
Prepayments		92	60
Regulatory assets		258	64
Other current assets		77	42
Total Current Assets		2,824	5,007
Property, Plant and Equipment
Regulated utility plant		36,961	30,477
Less: accumulated depreciation - regulated utility plant		8,352	6,488
Regulated utility plant, net		28,609	23,989
Non-regulated property, plant and equipment		92	266
Less: accumulated depreciation - non-regulated property, plant and equipment		46	41
Non-regulated property, plant and equipment, net		46	225
Construction work in progress		1,583	1,256
Property, Plant and Equipment, net		30,238	25,470
Other Noncurrent Assets
Regulatory assets		1,819	1,236
Goodwill		2,248	716
Other intangibles		313	343
Other noncurrent assets		395	451
Total Other Noncurrent Assets		4,775	2,746
Total Assets		37,837	33,223
Current Liabilities
Short-term debt		985	69
Long-term debt due within one year		354	474
Accounts payable		1,201	679
Taxes		124	96
Interest		97	81
Dividends		166	305
Regulatory liabilities		238	182
Other current liabilities		624	437
Total Current Liabilities		3,789	2,323
Long-term Debt [Abstract]
Long-term Debt		12,889	10,666
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,007	3,151
Investment tax credits		117	119
Accrued pension obligations		206	183
Asset retirement obligations		138	157
Regulatory liabilities		3,412	2,422
Other deferred credits and noncurrent liabilities		361	479
Total Deferred Credits and Other Noncurrent Liabilities		7,241	6,511
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,317	12,303
Earnings reinvested		2,681	2,572
Accumulated other comprehensive loss		(124)	(157)
Total Shareowners' Common Equity		13,915	13,723
Noncontrolling interests		3	0
Total Equity		13,918	13,723
Total Liabilities and Equity		$ 37,837	$ 33,223
Common stock par value		$ 0.01	$ 0.01
Treasury Stock		$ (967)	$ (1,003)
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		25	21
Accounts receivable (less reserve:)
Customer		357	305
Other		12	22
Accounts receivable from affiliates		3	11
Notes Receivable, Related Parties, Current		0	499
Unbilled revenues		224	129
Fuel, materials and supplies		69	61
Prepayments		34	13
Regulatory assets		13	22
Other current assets		22	21
Total Current Assets		759	1,104
Property, Plant and Equipment
Regulated utility plant		14,794	14,082
Less: accumulated depreciation - regulated utility plant		3,544	3,386
Regulated utility plant, net		11,250	10,696
Construction work in progress		593	581
Property, Plant and Equipment, net		11,843	11,277
Other Noncurrent Assets
Regulatory assets		568	488
Other intangibles		269	270
Assets for Plan Benefits, Defined Benefit Plan		0	50
Other noncurrent assets		126	113
Total Other Noncurrent Assets		963	921
Total Assets		13,565	13,302
Current Liabilities
Short-term debt		145	0
Long-term debt due within one year		340	474
Accounts payable		480	367
Accounts payable to affiliates		16	56
Taxes		36	31
Interest		35	35
Regulatory liabilities		85	153
Other current liabilities		86	108
Total Current Liabilities		1,223	1,224
Long-term Debt [Abstract]
Long-term Debt		4,146	4,010
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,514	1,668
Regulatory liabilities		820	559
Other deferred credits and noncurrent liabilities		111	105
Total Deferred Credits and Other Noncurrent Liabilities		2,445	2,332
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,084	4,254
Earnings reinvested		1,303	1,118
Total Shareowners' Common Equity		5,751	5,736
Total Liabilities and Equity		$ 13,565	$ 13,302
Common stock no par value		$ 0	$ 0
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		$ 93	$ 9
Accounts receivable (less reserve:)
Customer		157	130
Other		13	25
Accounts receivable from affiliates		37	31
Unbilled revenues		112	80
Fuel, materials and supplies		166	137
Prepayments		13	14
Regulatory assets		23	33
Other current assets		2	2
Total Current Assets		616	461
Property, Plant and Equipment
Regulated utility plant		7,429	7,192
Less: accumulated depreciation - regulated utility plant		1,355	1,172
Regulated utility plant, net		6,074	6,020
Construction work in progress		268	242
Property, Plant and Equipment, net		6,342	6,262
Other Noncurrent Assets
Regulatory assets		373	337
Goodwill		389	389
Other intangibles		24	30
Other noncurrent assets		66	113
Total Other Noncurrent Assets		852	869
Total Assets		7,810	7,592
Current Liabilities
Short-term debt		179	69
Long-term debt due within one year		0	0
Notes payable with affiliates		0	324
Accounts payable		165	163
Accounts payable to affiliates		60	31
Taxes		41	34
Interest		15	15
Asset Retirement Obligations		13	10
Price risk management liabilities		1	1
Customer deposits		32	32
Regulatory liabilities		7	21
Other current liabilities		46	37
Total Current Liabilities		559	737
Long-term Debt [Abstract]
Long-term Debt		2,307	2,006
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		771	751
Investment tax credits		31	32
Price risk management liabilities		6	17
Asset retirement obligations		73	74
Regulatory liabilities		833	818
Other deferred credits and noncurrent liabilities		64	78
Total Deferred Credits and Other Noncurrent Liabilities		1,778	1,770
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		2,087	1,997
Earnings reinvested		655	658
Total Shareowners' Common Equity		3,166	3,079
Total Liabilities and Equity		$ 7,810	$ 7,592
Common stock no par value		$ 0	$ 0
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		$ 21	$ 13
Accounts receivable (less reserve:)
Customer		158	144
Other		13	12
Unbilled revenues		114	91
Fuel, materials and supplies		167	124
Prepayments		14	15
Regulatory assets		32	9
Other current assets		1	2
Total Current Assets		520	410
Property, Plant and Equipment
Regulated utility plant		9,515	9,219
Less: accumulated depreciation - regulated utility plant		2,201	1,929
Regulated utility plant, net		7,314	7,290
Construction work in progress		522	378
Property, Plant and Equipment, net		7,836	7,668
Other Noncurrent Assets
Regulatory assets		442	411
Goodwill		607	607
Other intangibles		21	23
Other noncurrent assets		116	153
Total Other Noncurrent Assets		1,186	1,194
Total Assets		9,542	9,272
Current Liabilities
Short-term debt		101	0
Long-term debt due within one year		13	0
Notes payable with affiliates		0	294
Accounts payable		123	108
Accounts payable to affiliates		101	64
Taxes		26	19
Interest		19	18
Asset Retirement Obligations		26	22
Customer deposits		33	32
Regulatory liabilities		6	8
Other current liabilities		51	47
Total Current Liabilities		499	612
Long-term Debt [Abstract]
Long-term Debt		2,907	2,618
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		896	865
Investment tax credits		85	87
Asset retirement obligations		56	83
Regulatory liabilities		1,029	1,045
Other deferred credits and noncurrent liabilities		32	34
Total Deferred Credits and Other Noncurrent Liabilities		2,098	2,114
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		3,041	2,957
Earnings reinvested		689	663
Total Shareowners' Common Equity		4,038	3,928
Total Liabilities and Equity		$ 9,542	$ 9,272
Common stock no par value		$ 0	$ 0
[1]1,560,000 shares authorized; 770,013 shares issued and 736,487 shares outstanding at December 31, 2022. 1,560,000 shares authorized; 769,890 shares issued and 735,112 shares outstanding at December 31, 2021.[2]170,000 shares authorized; 66,368 shares issued and outstanding at December 31, 2022 and December 31, 2021[3]75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2022 and December 31, 2021.[4]80,000 shares authorized; 37,818 shares issued and outstanding at December 31, 2022 and December 31, 2021.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 87	$ 65
Unbilled Revenues, Reserve	6	2
Other Noncurrent Assets [Abstract]
Accounts Receivable, Allowance for Credit Loss, Noncurrent	$ 2	$ 2
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	1,560,000	1,560,000
Common stock shares issued	770,013	769,890
Common stock shares outstanding	736,487	735,112
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 28	$ 31
Unbilled Revenues, Reserve	2	2
Other Noncurrent Assets [Abstract]
Accounts Receivable, Allowance for Credit Loss, Noncurrent	$ 2	$ 2
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	170,000	170,000
Common stock shares issued	66,368	66,368
Common stock shares outstanding	66,368	66,368
Louisville Gas And Electric Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 4	$ 3
Unbilled Revenues, Reserve	$ 0	$ 0
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	75,000	75,000
Common stock shares issued	21,294	21,294
Common stock shares outstanding	21,294	21,294
Kentucky Utilities Co [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 3	$ 3
Unbilled Revenues, Reserve	$ 0	$ 0
Equity
Common stock no par value	$ 0	$ 0
Common stock shares authorized	80,000	80,000
Common stock shares issued	37,818	37,818
Common stock shares outstanding	37,818	37,818

CONSOLIDATED STATEMENTS OF EQUI

CONSOLIDATED STATEMENTS OF EQUITY - USD ($) shares in Thousands, $ in Millions		Total	Cumulative Effect, Period of Adoption, Adjustment	Common Stock [Member]		Additional Paid-in Capital	Earnings Reinvested	Earnings Reinvested Cumulative Effect, Period of Adoption, Adjustment	Accumulated Other Comprehensive Loss	Treasury Stock	Noncontrolling Interest	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member] Common Stock [Member]		PPL Electric Utilities Corp [Member] Additional Paid-in Capital	PPL Electric Utilities Corp [Member] Earnings Reinvested	Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member] Common Stock [Member]		Louisville Gas And Electric Co [Member] Additional Paid-in Capital	Louisville Gas And Electric Co [Member] Earnings Reinvested	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member] Common Stock [Member]		Kentucky Utilities Co [Member] Additional Paid-in Capital	Kentucky Utilities Co [Member] Earnings Reinvested
Total Equity		$ 12,991		$ 8		$ 12,214	$ 5,127		$ (4,358)	$ 0	$ 0
Dividends Declared Per Share of Common Stock		$ 1.660
Balance at beginning of period - shares at Dec. 31, 2019				767,233	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2019												$ 4,832		$ 364		$ 3,558	$ 910	$ 2,762		$ 424		$ 1,820	$ 518	$ 3,574		$ 308		$ 2,729	$ 537
Common stock shares issued	[1]			1,674
Net income (loss)		$ 1,469					1,469					497	[5]				497	244	[6]				244	280	[7]				280
Capital contributions from parent												940				940		103				103		128				128
Return of Capital to Parent												(745)				(745)
Cash dividends declared on common stock												(400)					(400)	(161)					(161)	(200)					(200)
Other comprehensive income (loss)		138							138
Balance at end of period - shares at Dec. 31, 2020				768,907	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2020												5,124		$ 364		3,753	1,007	2,948		$ 424		1,923	601	3,782		$ 308		2,857	617
Common stock issued		51				51
Stock-based compensation		5				5
Dividends		(1,279)					(1,279)
Total Equity		$ 13,373	$ (2)	$ 8		12,270	5,315	$ (2)	(4,220)	$ 0	0
Dividends Declared Per Share of Common Stock		$ 1.660
Common stock shares issued	[1]			983
Net income (loss)		$ (1,480)					(1,480)					445	[5]				445	249	[6]				249	296	[7]				296
Capital contributions from parent												1,075				1,075		74				74		100				100
Return of Capital to Parent												(574)				(574)
Cash dividends declared on common stock												$ (334)					(334)	$ (192)					(192)	$ (250)					(250)
Other comprehensive income (loss)		$ 4,063							4,063
Balance at end of period - shares at Dec. 31, 2021		735,112		735,112	[1]							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2021		$ 13,723										$ 5,736		$ 364		4,254	1,118	$ 3,079		$ 424		1,997	658	$ 3,928		$ 308		2,957	663
Common stock issued		29				29
Stock-based compensation		4				4
Dividends		(1,263)					(1,263)
Stock Issued During Period, Value, Reissued Treasury Stock		(1,003)
Stock Issued During Period, Shares, Treasury Stock Reissued										(34,778)
Total Equity		$ 13,723		$ 8		12,303	2,572		(157)	$ (1,003)	0
Dividends Declared Per Share of Common Stock		$ 0.875
Common stock shares issued	[1]			123
Treasury stock				1,252
Net income (loss)		$ 756					756					525	[5]				525	272	[6]				272	322	[7]				322
Capital contributions from parent																		90				90		84				84
Return of Capital to Parent												(170)				(170)
Cash dividends declared on common stock												$ (340)					(340)	$ (275)					(275)	$ (296)					(296)
Other comprehensive income (loss)		$ 33							33
Balance at end of period - shares at Dec. 31, 2022		736,487		736,487	[1]							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2022		$ 13,915										$ 5,751		$ 364		$ 4,084	$ 1,303	$ 3,166		$ 424		$ 2,087	$ 655	$ 4,038		$ 308		$ 3,041	$ 689
Noncontrolling Interest, Increase from Business Combination		3									3
Common stock issued		5				5
Stock-based compensation		9				9
Dividends		(647)					(647)
Stock Issued During Period, Value, Reissued Treasury Stock		36								36
Total Equity		$ 13,918		$ 8		$ 12,317	$ 2,681		$ (124)	$ (967)	$ 3
[1]Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.[2]Shares in thousands. All common shares of PPL Electric stock are owned by PPL.[3]Shares in thousands. All common shares of LG&E stock are owned by LKE.[4]Shares in thousands. All common shares of KU stock are owned by LKE.[5]Net income equals comprehensive income.[6]Net income equals comprehensive income.[7]Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical)	12 Months Ended
	Dec. 31, 2022 vote $ / shares	Dec. 31, 2021 vote $ / shares	Dec. 31, 2020 vote $ / shares
Vote per share of PPL's common stock | vote	1	1	1
Current quarterly common stock dividend (in dollars per share) | $ / shares	$ 0.875	$ 1.660	$ 1.660

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ in Millions	1 Months Ended	12 Months Ended
	Nov. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 7,902	$ 5,783	$ 5,474
Operating income		$ 1,374	$ 1,424	$ 1,586
Net income (loss) available to PPL common shareowners: [Abstract]
Net Income (Loss) Available to PPL Common , Per Basic shares		$ 1.03	$ (1.93)	$ 1.91
Net Income (Loss) Available to PPL Common Shareowners, Per Diluted Shares		1.02	(1.93)	1.91
Dividends declared per share of common stock (in dollars per share)	$ 0.225	$ 0.875	$ 1.660	$ 1.660
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 3,030	$ 2,402	$ 2,331
Operating income		$ 835	$ 735	$ 817

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	(All Registrants) General Capitalized terms and abbreviations appearing in the combined notes to financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrants' related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant. Business and Consolidation (PPL) PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; 2) the transmission, distribution and sale of electricity in Pennsylvania; and 3) the transmission, distribution and sale of electricity and the distribution and sale of natural gas in Rhode Island. Headquartered in Allentown, PA, PPL's principal subsidiaries are LG&E, KU, RIE and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. On March 17, 2021, PPL WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which prior to its sale substantially represented PPL's U.K. Regulated segment, to a subsidiary of National Grid plc. The sale was completed on June 14, 2021. The results of operations of the U.K. utility business are classified as Discontinued Operations on PPL's Statements of Income for all periods presented. PPL has elected to separately report the cash flows of continuing and discontinued operations on the Statements of Cash Flows for all periods presented. Unless otherwise noted, the notes to these financial statements exclude amounts related to discontinued operations. See Note 9 for additional information. On May 25, 2022, PPL Rhode Island Holdings, a wholly owned subsidiary of PPL, acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid U.S., a subsidiary of National Grid plc. Narragansett Electric, whose service area covers substantially all of Rhode Island, is primarily engaged in the transmission, distribution and sale of electricity and the distribution and sale of natural gas. The results of Narragansett Electric are included in the consolidated results of PPL from the date of the acquisition. Following the closing of the acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). See Note 9 for additional information. (PPL and PPL Electric) PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR. (PPL, LG&E and KU) LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name. (All Registrants) The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Variable Interest Entities (VIEs). The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE and, as a result, are the primary beneficiary of the entity. Amounts consolidated under the VIE guidance are not material to the Registrants. All significant intercompany transactions have been eliminated. The financial statements of PPL, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 13 for additional information. Regulation (All Registrants) PPL Electric, RIE, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, RIE, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover expected future costs, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 7 for additional details regarding regulatory matters. Accounting Records The system of accounts for regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. Loss Accruals Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of uncertain future events and (2) the amount of loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other events. Loss accruals for environmental remediation are discounted when appropriate. The accrual of contingencies that might result in gains is not recorded, unless realization is assured. Earnings Per Share (PPL) EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-based payment awards that provide recipients a non-forfeitable right to dividends or dividend equivalents are considered participating securities. Price Risk Management (All Registrants) Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Derivative instruments pursuant to regulator approved plans to manage commodity price risk associated with natural gas purchases to reduce fluctuations in natural gas prices and costs associated with these derivatives instruments are generally recoverable through approved cost recovery mechanism. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved to facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. (PPL) Processes exist that allow for subsequent review and validation of contract information as it relates to interest rate derivatives and commodity gas contracts. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to: • Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring. • Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges. • Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. (All Registrants) Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, RIE, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps or commodity gas contracts that are included in customer rates. (PPL and PPL Electric) To meet their obligations as last resort providers to their customers, PPL Electric and RIE have entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. (All Registrants) See Notes 17 and 18 for additional information on derivatives. Revenue (All Registrants) Operating revenues are primarily recorded based on energy deliveries through the end of each calendar month. Unbilled retail revenues result because customers' bills are rendered throughout the month, rather than at the end of the month. For RIE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled volumes by the price per tariff. In the fourth quarter of 2022, PPL Electric estimated deliveries to customers due to a temporary technical system issue. The issue has been resolved and unbilled revenues are expected to resume being calculated by multiplying the actual unbilled volumes by the price per tariff in the first quarter of 2023. PPL Electric's, RIE's, LG&E's and KU's base rates are determined based on cost of service. Some regulators have also authorized the use of additional alternative revenue programs, which enable PPL Electric, RIE, LG&E and KU to adjust future rates based on past activities or completed events. Revenues from alternative revenue programs are recognized when the specific events permitting future billings have occurred. Revenues from alternative revenue programs are required to be presented separately from revenues from contracts with customers. These amounts are, however, presented as revenues from contracts with customers, with an offsetting adjustment to alternative revenue program revenue, when they are billed to customers in future periods. See Note 3 for additional information. Financing and Other Receivables (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Financing receivables include accounts receivable, with the exception of those items within accounts receivable that are not subject to the current expected credit loss model. Financing receivable collectability is evaluated using a current expected credit loss model, consisting of a combination of factors, including past due status based on contractual terms, trends in write-offs and the age of the receivable. Specific events, such as bankruptcies, are also considered when applicable. The Registrants also evaluate the impact of observable external factors on the collectability of the financing receivables to determine if adjustments to the allowance for doubtful accounts should be made based on current conditions or reasonable and supportable forecasts. Adjustments to the allowance for doubtful accounts are made based on the results of these analyses. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. PPL Electric, RIE, LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other. (PPL and PPL Electric) Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation. (All Registrants) The changes in the allowance for doubtful accounts are included in the following table. Amounts relate to financing receivables, except as noted. Additions Balance at Charged to Income Deductions (b) Balance at PPL 2022 $ 69 $ 78 $ 52 $ 95 (d) 2021 73 26 30 69 (d) 2020 (a) 58 (a) 28 13 73 (d) PPL Electric 2022 $ 35 $ 27 $ 29 $ 33 (c) 2021 41 13 19 35 (c) 2020 30 (a) 19 8 41 (c) LG&E 2022 $ 3 $ 6 $ 5 $ 4 2021 3 4 4 3 2020 1 4 2 3 KU 2022 $ 3 $ 6 $ 6 $ 3 2021 2 8 7 3 2020 1 4 3 2 (a) Adjusted for $2 million cumulative-effect adjustment upon adoption of current expected credit loss guidance. (b) Primarily related to uncollectible accounts written off. (c) Includes $3 million related to other accounts receivables at December 31, 2022, 2021 and 2020. (d) Includes $36 million, $32 million and $30 million related to other accounts receivables at December 31, 2022, 2021 and 2020. Cash (All Registrants) Cash Equivalents All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. (PPL) Restricted Cash and Cash Equivalents Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets." See Note 17 for a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets to the amounts shown on the Statements of Cash Flows. (All Registrants) Fair Value Measurements The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securities in defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows: • Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. • Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability. • Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value. Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy. Investments Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term. Investments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. These investments are included in "Other noncurrent assets" on the Balance Sheets. Earnings from these investments are recorded in "Other Income (Expense) - net" on the Statements of Income. Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets. Long-Lived and Intangible Assets Property, Plant and Equipment (All Registrants) PP&E is recorded at original cost, unless impaired. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. PP&E acquired in business combinations is recorded at fair value at the time of acquisition. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. Included in PP&E are capitalized costs of software projects that were developed or obtained for internal use. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which work is performed and costs are incurred. AFUDC is capitalized at PPL Electric and RIE as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. AFUDC capitalized at LG&E and KU is generally not significant because a return is provided on construction work in progress. (PPL and PPL Electric) RIE and PPL Electric capitalize interest costs as part of construction costs. Capitalized interest, including the debt component of AFUDC, for the years ended December 31 is as follows: 2022 2021 2020 PPL $ 7 $ 6 $ 7 PPL Electric 5 6 7 Depreciation (All Registrants) Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators. RIE, LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. For LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset or regulatory liability. See "Asset Retirement Obligations" below and Note 7 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices. Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2022 2021 2020 PPL 3.21 % 3.61 % 3.53 % PPL Electric 2.75 % 3.05 % 2.99 % LG&E 4.16 % 3.99 % 4.00 % KU 4.01 % 4.17 % 4.00 % Goodwill and Other Intangible Assets ( All Registrants) Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination. Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets. When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider: • the expected use of the asset; • the expected useful life of other assets to which the useful life of the intangible asset may relate; • legal, regulatory, or contractual provisions that may limit the useful life; • the company's historical experience as evidence of its ability to support renewal or extension; • the effects of obsolescence, demand, competition, and other economic factors; and, • the level of maintenance expenditures required to obtain the expected future cash flows from the asset. Asset Impairment (Excluding Investments) (All Registrants) The Registrants review long-lived assets that are subject to depreciation or amortization, including finite-lived intangibles, for impairment when events or circumstances indicate carrying amounts may not be recoverable. A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's carrying value is written down to its fair value. A long-lived asset classified as held for sale is impaired when the carrying amount of the asset (disposal group) exceeds its fair value less cost to sell. If impaired, the asset's (disposal group's) carrying value is written down to its fair value less cost to sell. PPL, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, LG&E's and KU's reporting units are primarily at the operating segment level. Goodwill recognized upon the acquisition of Narragansett Electric was assigned for impairment testing by PPL to its reporting units expected to benefit from the acquisition, which were the Rhode Island Regulated reporting unit, the Pennsylvania Regulated reporting unit and the Kentucky Regulated reporting unit. See Note 9 for additional information regarding the acquisition. PPL, for its reporting units, and individually LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a quantitative test. If the qualitative evaluation (referred to as step zero) is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a reporting unit is less than the carrying amount based on the step zero assessment. If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. As of October 1, 2022, PPL, for its reporting units, and individually, LG&E and KU, elected to perform quantitative annual goodwill impairment tests. There were no indicators of impairment for any of the reporting units as the fair value of each of the reporting units significantly exceeded their carrying values. ( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs. Compensation and Benefits Defined Benefits (All Registrants) Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU, RIE and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value. PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the required amortization period. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the full required amortization period. See Note 7 for a discussion of the regulatory treatment of defined benefit costs and Note 12 for a discussion of defined benefits. Stock-Based Compensation (PPL and PPL Electric) PPL has several stock-based compensation plans for purposes of granting stock options, restricted stock, restricted stock units and performance units to certain employees as well as stock units and restricted stock units to directors. PPL grants most stock-based compensation awards in the first quarter of each year. PPL and its subsidiaries recognize compensation expense for stock-based compensation awards based on the fair value method. Forfeitures of awards are recognized when they occur. See Note 11 for a discussion of stock-based compensation. All awards are recorded as equity or a liability on the Balance Sheets. Stock-based compensation expense is primarily included in "Other operation and maintenance" on the Statements of Income. Taxes Income Taxes (All Registrants) PPL and its domestic subsidiaries file a consolidated U.S. federal income tax return. Significant management judgment is required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken on tax returns and valuation allowances on deferred tax assets. The Registrants use a two-step process to evaluate tax positions. The first step requires an entity to determine whether, based on the technical merits supporting a particular tax position, it is more likely than not (greater than a 50% chance) that the tax position will be sustained. This determination assumes that the relevant taxing authority will examine the tax position and is aware of all the relevant facts surrounding the tax position. The second step requires an entity to recognize in its financial statements the benefit of a tax position that meets the more-likely-than-not recognition criterion. The benefit recognized is measured at the largest amount of benefit that has a likelihood of realization upon settlement that exceeds 50%. Unrecognized tax benefits are classified as current to the extent management expects to settle the uncertain tax position by payment or receipt of cash within one year of the reporting date. The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements of the Registrants in future periods. At December 31, 2022, no significant changes in unrecognized tax benefits were projected over the next 12 months. Deferred income taxes reflect the

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Segment and Related Information	(PPL) PPL is organized into three segments: Kentucky Regulated, Pennsylvania Regulated, and Rhode Island Regulated. PPL's segments are segmented by geographic location. The Kentucky Regulated segment consists primarily of LG&E's and KU's regulated electricity generation, transmission and distribution operations, as well as LG&E's regulated distribution and sale of natural gas. In addition, the Kentucky Regulated segment includes certain financing and other costs at LKE. The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. The Rhode Island Regulated segment includes the regulated electricity transmission and distribution and natural gas distribution operations of RIE, which was acquired on May 25, 2022. "Corporate and Other" primarily includes financing and other costs incurred at the corporate level that have not been allocated or assigned to the segments, as well as certain non-recoverable costs resulting from commitments made to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island in conjunction with the acquisition of Narragansett Electric. As a result of the June 14, 2021 sale of the U.K. utility business, PPL determined segment information for the U.K. Regulated segment would no longer be provided beginning with the March 31, 2021 Form 10-Q. See Note 9 for additional information. Income Statement data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2022 2021 2020 Operating Revenues from external customers (a) Kentucky Regulated $ 3,811 $ 3,348 $ 3,106 Pennsylvania Regulated 3,030 2,402 2,330 Rhode Island Regulated 1,038 — — Corporate and Other 23 33 38 Total $ 7,902 $ 5,783 $ 5,474 Depreciation Kentucky Regulated $ 685 $ 647 $ 606 Pennsylvania Regulated 393 424 403 Rhode Island Regulated 92 — — Corporate and Other 11 11 13 Total $ 1,181 $ 1,082 $ 1,022 Amortization (b) Kentucky Regulated $ 23 $ 15 $ 19 Pennsylvania Regulated 22 19 26 Rhode Island Regulated 2 — — Corporate and Other 5 5 13 Total $ 52 $ 39 $ 58 2022 2021 2020 Interest Expense (c) Kentucky Regulated $ 262 $ 249 $ 300 Pennsylvania Regulated 171 162 172 Rhode Island Regulated 39 — — Corporate and Other (d) 41 507 162 Total $ 513 $ 918 $ 634 Income Before Income Taxes Kentucky Regulated $ 621 $ 562 $ 516 Pennsylvania Regulated 699 599 664 Rhode Island Regulated (58) — — Corporate and Other (347) (640) (226) Total $ 915 $ 521 $ 954 Income Taxes (e) Kentucky Regulated $ 114 $ 94 $ 98 Pennsylvania Regulated 174 154 167 Rhode Island Regulated (14) — — Corporate and Other (73) 255 49 Total $ 201 $ 503 $ 314 Deferred income taxes and investment tax credits (f) Kentucky Regulated $ 6 $ 272 $ 64 Pennsylvania Regulated 91 79 82 Rhode Island Regulated 39 — — Corporate and Other 43 (264) 23 Total $ 179 $ 87 $ 169 Net Income Kentucky Regulated $ 507 $ 468 $ 418 Pennsylvania Regulated 525 445 497 Rhode Island Regulated (44) — — Corporate and Other (d) (274) (895) (275) Discontinued Operations 42 (1,498) 829 Total $ 756 $ (1,480) $ 1,469 (a) See Note 1 and Note 3 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs. (c) Beginning in 2021, corporate level financing costs are no longer allocated to the reportable segments and are being reported in Corporate and Other. For the year ended December 31, 2020, corporate level financing costs of $32 million, net of $8 million of income taxes, were allocated to the Kentucky Regulated segment. For the year ended December 31, 2020, an immaterial amount of financing costs was allocated to the Pennsylvania Regulated segment. (d) 2021 includes losses from the extinguishment of PPL Capital Funding debt. See Note 8 for additional information. (e) Represents both current and deferred income taxes, including investment tax credits. (f) Represents a non-cash expense item that is also included in "Income Taxes." Cash Flow data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2022 2021 2020 Expenditures for long-lived assets Kentucky Regulated $ 917 $ 1,026 $ 966 Pennsylvania Regulated 889 904 1,154 Rhode Island Regulated 268 — — Corporate and Other 84 49 158 Total $ 2,158 $ 1,979 $ 2,278 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2022 2021 Total Assets Kentucky Regulated $ 16,904 $ 16,360 Pennsylvania Regulated 13,565 13,336 Rhode Island Regulated 6,081 — Corporate and Other (a) 1,287 3,527 Total $ 37,837 $ 33,223 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill, and the elimination of inter-segment transactions. Beginning on January 1, 2023, the Kentucky Regulated segment will consist primarily of the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. Prior to January 1, 2023, the Kentucky Regulated segment also included the financing activities of LKE. The financing activity of LKE will be presented in Corporate and Other beginning on January 1, 2023. As a result of this change, beginning on January 1, 2023, PPL’s segments will consist of the regulated operations of Kentucky, Pennsylvania and Rhode Island and will exclude any incremental financing activities of holding companies, which Management believes is a more meaningful presentation as it provides information on the core regulated operations of PPL. (PPL Electric, LG&E and KU) PPL Electric has two operating segments, distribution and transmission, which are aggregated into a single reportable segment. LG&E and KU are individually single operating and reportable segments.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	(All Registrants) The following is a description of the principal activities from which the Registrants and PPL’s segments generate their revenues. (PPL and PPL Electric) Pennsylvania Regulated Segment Revenue The Pennsylvania Regulated segment generates substantially all of its revenues from contracts with customers from PPL Electric’s tariff-based distribution and transmission of electricity. Distribution Revenue PPL Electric provides distribution services to residential, commercial, industrial, municipal and governmental end users of energy. PPL Electric satisfies its performance obligation to its distribution customers and revenue is recognized over-time as electricity is delivered and simultaneously consumed by the customer. The amount of revenue recognized is the volume of electricity delivered during the period multiplied by the price per tariff, plus a monthly fixed charge. This method of recognition fairly presents PPL Electric's transfer of electric service to the customer as the calculation is based on volumes delivered, and the price per tariff and the monthly fixed charge are set by the PAPUC. Customers are typically billed monthly and outstanding amounts are normally due within 21 days of the date of the bill. Distribution customers are "at will" customers of PPL Electric with no term contract and no minimum purchase commitment. Performance obligations are limited to the service requested and received to date. Accordingly, there is no unsatisfied performance obligation associated with PPL Electric’s retail account contracts. Certain customers have the option to obtain electricity or natural gas from other suppliers. In those circumstances, revenue is only recognized for providing delivery of the commodity to the customer. Transmission Revenue PPL Electric generates transmission revenues from a FERC-approved PJM Open Access Transmission Tariff. An annual revenue requirement for PPL Electric to provide transmission services is calculated using a formula-based rate. This revenue requirement is converted into a daily rate (dollars per day). PPL Electric satisfies its performance obligation to provide transmission services and revenue is recognized over-time as transmission services are provided and consumed. This method of recognition fairly presents PPL Electric's transfer of transmission services as the daily rate is set by a FERC approved formula-based rate. PJM remits payment on a weekly basis. PPL Electric's agreement to provide transmission services contains no minimum purchase commitment. The performance obligation is limited to the service requested and received to date. Accordingly, PPL Electric has no unsatisfied performance obligations. (PPL) Rhode Island Regulated Segment Revenues The Rhode Island Regulated segment generates substantially all of its revenues from contracts with customers from RIE’s regulated tariff-based transmission and distribution of electricity and regulated tariff-based distribution of natural gas. Distribution Revenue Distribution revenues are primarily from the sale of electricity, natural gas, and related services to retail customers. Distribution sales are regulated by the RIPUC, which is responsible for approving the rates and other terms of services as part of the rate making process. Natural gas and electric distribution revenues are derived from the regulated sale and distribution of electricity and natural gas to residential, commercial, and industrial customers within RIE’s service territory under the tariff rates. The performance obligation related to distribution sales is to provide electricity and natural gas to customers on demand. The performance obligation is satisfied over time because the customer simultaneously receives and consumes the electricity or natural gas as services are provided. RIE records revenues related to the distribution sales based upon the approved tariff rate and the volume delivered to the customers, which corresponds with the amount RIE has the right to invoice. Distribution revenue also includes estimated unbilled amounts, which represent the estimated amounts due from retail customers as a result of customer's bills rendered throughout the month, rather than bills being rendered at the end of the month. Unbilled revenues are determined based on estimated unbilled sales volumes and then applying tariff rates to those volumes. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. This method of recognition fairly presents RIE's transfer of electricity and natural gas to the customer as the amount recognized is based on actual and estimated volumes delivered and the tariff rate per unit of energy and any applicable fixed charges or regulatory mechanisms as approved by the respective regulatory body. Certain customers have the option to obtain electricity or natural gas from other suppliers. In those circumstances, revenue is only recognized for providing delivery of the commodity to the customer. Transmission Revenue RIE’s transmission services are regulated by the FERC and coordinated with ISO – New England (ISO-NE). Additionally, RIE makes available its transmission facilities to NEP, for operation and control pursuant to an integrated facilities agreement, Service Agreement No. 23 (Integrated Facilities Agreement or IFA). As of December 31, 2022 these integrated facilities agreements have concluded as RIE is a transmission operator. These revenues arise under tariff/rate agreements and are collected primarily from RIE’s distribution customers. The revenue is recognized over-time as transmission services are provided and consumed. This method of recognition fairly presents RIE’s transfer of transmission services as the daily rate is set by a FERC-approved formula-based rate. (PPL, LG&E and KU) Kentucky Regulated Segment Revenue The Kentucky Regulated Segment generates substantially all of its revenues from contracts with customers from LG&E's and KU's regulated tariff-based sales of electricity and LG&E's regulated tariff-based sales of natural gas. LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity in Kentucky and, in KU's case, Virginia. LG&E also engages in the distribution and sale of natural gas in Kentucky. Revenue from these activities is generated from tariffs approved by applicable regulatory authorities including the FERC, KPSC and VSCC. LG&E and KU satisfy their performance obligations upon LG&E's and KU's delivery of electricity and LG&E's delivery of natural gas to customers. This revenue is recognized over-time as the customer simultaneously receives and consumes the benefits provided by LG&E and KU. The amount of revenue recognized is the billed volume of electricity or natural gas delivered multiplied by a tariff rate per-unit of energy, plus any applicable fixed charges or additional regulatory mechanisms. Customers are billed monthly and outstanding amounts are typically due within 22 days of the date of the bill. Additionally, unbilled revenues are recognized as a result of customers' bills rendered throughout the month, rather than bills being rendered at the end of the month. Unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf delivered but not yet billed by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. This method of recognition fairly presents LG&E's and KU's transfer of electricity and LG&E's transfer of natural gas to the customer as the amount recognized is based on actual and estimated volumes delivered and the tariff rate per-unit of energy and any applicable fixed charges or regulatory mechanisms as set by the respective regulatory body. LG&E's and KU's customers generally have no minimum purchase commitment. Performance obligations are limited to the service requested and received to date. Accordingly, there is no unsatisfied performance obligation associated with these customers. (All Registrants) The following table reconciles "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the years ended December 31: 2022 PPL PPL Electric LG&E KU Operating Revenues (a) $ 7,902 $ 3,030 $ 1,798 $ 2,074 Revenues derived from: Alternative revenue programs (b) (92) (56) 9 5 Other (c) (24) (14) (6) (4) Revenues from Contracts with Customers $ 7,786 $ 2,960 $ 1,801 $ 2,075 2021 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,783 $ 2,402 $ 1,569 $ 1,826 Revenues derived from: Alternative revenue programs (b) 77 83 (3) (3) Other (c) (22) (3) (8) (9) Revenues from Contracts with Customers $ 5,838 $ 2,482 $ 1,558 $ 1,814 2020 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,474 $ 2,331 $ 1,456 $ 1,690 Revenues derived from: Alternative revenue programs (b) (24) (12) (8) (4) Other (c) (21) (3) (7) (10) Revenues from Contracts with Customers $ 5,429 $ 2,316 $ 1,441 $ 1,676 (a) PPL includes $1,038 million for the twelve months ended December 31, 2022 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information. (b) This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under collections as negative amounts. For PPL Electric, revenue in 2022 includes $74 million related to the amortization of the regulatory liability primarily recorded in 2021 for a reduction in the transmission formula rate return on equity that is reflected in rates in 2022. Revenue in 2021 was reduced by $78 million for a reduction in the transmission formula rate return on equity. See Note 7 for additional information. (c) Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues. The following table shows revenues from contracts with customers disaggregated by customer class for the years ended December 31: Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 2022 PA Regulated $ 1,647 $ 491 $ 85 $ 54 $ — $ — $ 683 $ 2,960 RI Regulated 299 101 9 478 — — 101 988 KY Regulated 1,637 1,068 662 323 28 97 — 3,815 Corp and Other — — — 23 — — — 23 Total PPL $ 3,583 $ 1,660 $ 756 $ 878 $ 28 $ 97 $ 784 $ 7,786 2021 PA Regulated $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 RI Regulated — — — — — — — — KY Regulated 1,416 928 586 305 24 66 — 3,325 Corp and Other — — — 31 — — — 31 Total PPL $ 2,715 $ 1,278 $ 639 $ 386 $ 24 $ 66 $ 730 $ 5,838 2020 PA Regulated $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 RI Regulated — — — — — — — — KY Regulated 1,347 871 538 261 20 40 — 3,077 Corp and Other — — — 36 — — — 36 Total PPL $ 2,585 $ 1,185 $ 582 $ 347 $ 20 $ 40 $ 670 $ 5,429 PPL Electric 2022 $ 1,647 $ 491 $ 85 $ 54 $ — $ — $ 683 $ 2,960 2021 $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 2020 $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 LG&E 2022 $ 835 $ 551 $ 199 $ 141 $ — $ 75 $ — $ 1,801 2021 $ 711 $ 473 $ 180 $ 145 $ — $ 49 $ — $ 1,558 2020 $ 676 $ 444 $ 173 $ 114 $ — $ 34 $ — $ 1,441 KU 2022 $ 802 $ 517 $ 463 $ 182 $ 28 $ 83 $ — $ 2,075 2021 $ 705 $ 455 $ 406 $ 160 $ 24 $ 64 $ — $ 1,814 2020 $ 671 $ 427 $ 365 $ 147 $ 20 $ 46 $ — $ 1,676 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. (b) Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at PPL. As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the footnotes to the tables above. PPL Electric's revenues from contracts with customers are further disaggregated by distribution and transmission as indicated in the above tables. Contract receivables from customers are primarily included in "Accounts receivable - Customer" and "Unbilled revenues" on the Balance Sheets. The following table shows the accounts receivable and unbilled revenues balances that were impaired for the year ended December 31: 2022 2021 2020 PPL(a) $ 70 $ 22 $ 25 PPL Electric 21 10 17 LG&E 6 4 4 KU 6 8 4 (a) Includes $23 million for the twelve months ended December 31, 2022 related to the commitment to forgive customer arrearages for low-income and protected residential customers at RIE. See Note 9 for additional information. The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers: PPL PPL Electric LG&E KU Contract liabilities as of December 31, 2022 $ 34 $ 23 $ 5 $ 6 Contract liabilities as of December 31, 2021 42 25 6 6 Revenue recognized during the year ended December 31, 2022 that was included in the contract liability balance at December 31, 2021 25 12 6 6 Contract liabilities as of December 31, 2021 $ 42 $ 25 $ 6 $ 6 Contract liabilities as of December 31, 2020 40 23 5 6 Revenue recognized during the year ended December 31, 2021 that was included in the contract liability balance at December 31, 2020 24 11 5 6 Contract liabilities as of December 31, 2020 $ 40 $ 23 $ 5 $ 6 Contract liabilities as of December 31, 2019 37 21 5 4 Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 22 9 5 4 Contract liabilities result from recording contractual billings in advance for customer attachments to the Registrants' infrastructure and payments received in excess of revenues earned to date. Advanced billings for customer attachments are recognized as revenue ratably over the billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods.

Preferred Securities

Preferred Securities	12 Months Ended
	Dec. 31, 2022
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2022, 2021 or 2020. RIE has $3 million of outstanding preferred stock. See Note 8 for additional information. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2022, 2021 or 2020. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2022, 2021 or 2020. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2022, 2021 or 2020.
PPL Electric Utilities Corp [Member]
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2022, 2021 or 2020. RIE has $3 million of outstanding preferred stock. See Note 8 for additional information. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2022, 2021 or 2020. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2022, 2021 or 2020. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2022, 2021 or 2020.
Louisville Gas And Electric Co [Member]
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2022, 2021 or 2020. RIE has $3 million of outstanding preferred stock. See Note 8 for additional information. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2022, 2021 or 2020. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2022, 2021 or 2020. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2022, 2021 or 2020.
Kentucky Utilities Co [Member]
Preferred Securities [Line Items]
Preferred Securities	(PPL) PPL is authorized to issue up to 10 million shares of preferred stock. No PPL preferred stock was issued or outstanding in 2022, 2021 or 2020. RIE has $3 million of outstanding preferred stock. See Note 8 for additional information. (PPL Electric) PPL Electric is authorized to issue up to 20,629,936 shares of preferred stock. No PPL Electric preferred stock was issued or outstanding in 2022, 2021 or 2020. (LG&E) LG&E is authorized to issue up to 1,720,000 shares of preferred stock at a $25 par value and 6,750,000 shares of preferred stock without par value. LG&E had no preferred stock issued or outstanding in 2022, 2021 or 2020. (KU) KU is authorized to issue up to 5,300,000 shares of preferred stock and 2,000,000 shares of preference stock without par value. KU had no preferred or preference stock issued or outstanding in 2022, 2021 or 2020.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2022
Earnings Per Share [Abstract]
Earnings Per Share	(PPL) Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by incremental shares that would be outstanding if potentially dilutive non-participating securities were converted to common shares as calculated using the Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below. Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31, used in the EPS calculation are: 2022 2021 2020 Income (Numerator) Income from continuing operations after income taxes $ 714 $ 18 $ 640 Less amounts allocated to participating securities 1 — 1 Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted $ 713 $ 18 $ 639 Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ 42 $ (1,498) $ 829 Net income (loss) attributable to PPL $ 756 $ (1,480) 1,469 Less amounts allocated to participating securities 1 — 1 Net income (loss) available to PPL common shareowners - Basic and Diluted $ 755 $ (1,480) $ 1,468 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 736,027 762,902 768,590 Add: Dilutive share-based payment awards (a) 875 1,917 794 Weighted-average shares - Diluted EPS 736,902 764,819 769,384 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.97 $ 0.03 $ 0.83 Income (loss) from discontinued operations (net of income taxes) 0.06 (1.96) 1.08 Net Income (Loss) available to PPL common shareowners $ 1.03 $ (1.93) $ 1.91 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.96 $ 0.03 $ 0.83 Income (loss) from discontinued operations (net of income taxes) 0.06 (1.96) 1.08 Net Income (Loss) available to PPL common shareowners $ 1.02 $ (1.93) $ 1.91 (a) The Treasury Stock Method was applied to non-participating share-based payment awards. For the years ended December 31, PPL issued common stock related to stock-based compensation plans as follows (in thousands): 2022 2021 Stock-based compensation plans (a) 124 983 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors. For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive: 2022 2021 2020 Stock-based compensation awards 93 1,783 452

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income and Other Taxes	(PPL) "Income (Loss) from Continuing Operations Before Income Taxes" is from domestic operations. Deferred income taxes reflect the net tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes and the tax effects of net operating loss and tax credit carryforwards. The provision for PPL's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles of the applicable jurisdiction. See Notes 1 and 7 for additional information. Net deferred tax assets have been recognized based on management's estimates of future taxable income. Significant components of PPL's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Deferred investment tax credits $ 29 $ 30 Regulatory liabilities 88 94 Income taxes due to customers 448 422 Accrued pension and postretirement costs 86 75 State loss carryforwards 230 483 Federal and state tax credit carryforwards 68 15 Internal Revenue Code Section 197 intangibles (a) 85 — Leases 15 67 Contributions in aid of construction 114 120 Other 72 84 Valuation allowances (213) (462) Total deferred tax assets 1,022 928 Deferred Tax Liabilities Plant - net 3,609 3,812 Regulatory assets 337 180 Prepayments 46 — Other 30 75 Total deferred tax liabilities 4,022 4,067 Net deferred tax liability $ 3,000 $ 3,139 (a) Certain of the RIE assets acquired in 2022 are treated as intangibles for tax purposes that are amortized over a 15 year period. PPL recorded deferred tax assets on these intangibles, which will reverse as tax deductions are taken. State deferred taxes are determined by entity and by jurisdiction. As a result, $6 million and $12 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 2022 and 2021. At December 31, 2022, PPL had the following loss and tax credit carryforwards, related deferred tax assets and valuation allowances recorded against the deferred tax assets: Gross Deferred Tax Asset Valuation Allowance Expiration Loss and other carryforwards State net operating losses $ 5,830 $ 230 $ (213) 2023-2042 Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal investment tax credit 20 — 2042 Federal foreign tax credits 32 — 2027 Federal - other 3 — 2042 State recycling credit 12 — 2028 State - other 1 — Indefinite Valuation allowances have been established for the amount that, more likely than not, will not be realized. The changes in deferred tax valuation allowances were as follows: Additions Balance at Charged Charged to Deductions Balance 2022 $ 462 $ 10 $ — $ 259 (a) $ 213 2021 536 48 (b) — 122 (c) 462 2020 514 26 — 4 536 (a) In 2022, PPL recorded a $36 million decrease in a valuation allowance on a 2002 state net operating loss carryforward that expired in 2022 and a $213 million decrease in the valuation allowance due to the Pennsylvania rate change. See reconciliation of income tax table below. (b) In 2021, PPL recorded a $31 million increase in a valuation allowance on a state net operating loss carryforward in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. (c) In light of the disposition of PPL's U.K. utility business, there was a decrease in the valuation allowance of approximately $113 million. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ (2) $ (1) $ (8) Current - State 24 36 24 Current - Foreign — (1) (2) Total Current Expense (Benefit) 22 34 14 Deferred - Federal 122 28 135 Deferred - State 68 105 94 Deferred - Foreign (a) — 383 101 Total Deferred Expense (Benefit), excluding operating loss carryforwards 190 516 330 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 2 12 6 Deferred - State (10) (56) (33) Total Tax Expense (Benefit) of Operating Loss Carryforwards (8) (44) (27) Total income tax expense (benefit) $ 201 $ 503 $ 314 Total income tax expense (benefit) - Federal $ 119 $ 36 $ 130 Total income tax expense (benefit) - State 82 85 85 Total income tax expense (benefit) - Foreign — 382 99 Total income tax expense (benefit) $ 201 $ 503 $ 314 (a) The U.K. Finance Act 2021, formally enacted on June 10, 2021, increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in 2021. In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction from 19% to 17%. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2022 2021 2020 Discontinued operations $ (42) $ 759 $ 188 Reclassification from AOCI due to sale of UK utility business — 660 — Other comprehensive income 11 150 (19) Total $ (31) $ 1,569 $ 169 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 192 $ 109 $ 200 State income taxes, net of federal income tax benefit 68 23 48 Valuation allowance adjustments (a) 9 48 24 Federal and state income tax return adjustments (1) (3) (9) Impact of the U.K. Finance Acts on deferred tax balances (b) — 383 101 Depreciation and other items not normalized (8) (5) (5) Amortization of excess deferred federal and state income taxes (54) (54) (43) Non-deductible officer's salary 5 6 7 Other (10) (4) (9) Total increase (decrease) 9 394 114 Total income tax expense (benefit) $ 201 $ 503 $ 314 Effective income tax rate 22.0% 96.5% 32.9% (a) In 2021, PPL recorded a $31 million state deferred tax benefit on a net operating loss and an offsetting valuation allowance in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. In 2022, 2021, and 2020, PPL recorded deferred income tax expense of $5 million, $15 million and $24 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction to 17%, thereby maintaining the corporation tax rate at 19% for financial years 2020 and 2021. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. The U.K. Finance Act 2021, formally enacted on June 10, 2021, increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in 2021. 2022 2021 2020 Taxes, other than income State gross receipts (a) $ 175 $ 113 $ 100 Domestic - other (a) 157 94 80 Total $ 332 $ 207 $ 180 (a) Increase primarily due to the acquisition of RIE. (PPL Electric) The provision for PPL Electric's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the PAPUC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of PPL Electric's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Accrued pension and postretirement costs $ 27 $ 14 Contributions in aid of construction 87 95 Regulatory liabilities 36 52 Income taxes due to customers 193 154 Other 18 21 Total deferred tax assets 361 336 Deferred Tax Liabilities Electric utility plant - net 1,745 1,891 Regulatory assets 93 74 Prepayments 35 — Other 2 39 Total deferred tax liabilities 1,875 2,004 Net deferred tax liability $ 1,514 $ 1,668 PPL Electric expects to have adequate levels of taxable income to realize its recorded deferred income tax assets. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ 63 $ 40 $ 61 Current - State 20 35 23 Total Current Expense (Benefit) 83 75 84 Deferred - Federal 60 59 45 Deferred - State 31 20 38 Total Deferred Expense (Benefit), excluding operating loss carryforwards 91 79 83 Total income tax expense (benefit) $ 174 $ 154 $ 167 Total income tax expense (benefit) - Federal $ 123 $ 99 $ 106 Total income tax expense (benefit) - State 51 55 61 Total income tax expense (benefit) $ 174 $ 154 $ 167 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 147 $ 126 $ 139 Increase (decrease) due to: State income taxes, net of federal income tax benefit 54 46 52 Federal and state income tax return adjustments (1) — (4) Depreciation and other items not normalized (7) (5) (5) Amortization of excess deferred federal income taxes (a) (12) (14) (16) State income tax rate change (b) (9) — — Other 2 1 1 Total increase (decrease) 27 28 28 Total income tax expense (benefit) $ 174 $ 154 $ 167 Effective income tax rate 24.9% 25.7% 25.2% (a) In 2022, 2021, and 2020, PPL Electric recorded lower income tax expense for the amortization of excess deferred taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. This amortization represents each year's refund amount, prior to a tax gross-up, to be paid to customers for previously collected deferred taxes at higher income tax rates. (b) On July 8, 2022, the Governor of Pennsylvania signed into law Pennsylvania House Bill 1342 (H.B. 1342). Among other changes to the state tax code, the bill reduces the corporate net income tax rate from 9.99% to 8.99% beginning January 1, 2023, and further reduces the rate annually by half a percentage point until the rate reaches 4.99% in 2031. The income statement impact of the corporate net income tax reduction was a deferred tax benefit of $9 million. 2022 2021 2020 Taxes, other than income State gross receipts $ 142 $ 113 $ 100 Property and other 7 7 7 Total $ 149 $ 120 $ 107 (LG&E) The provision for LG&E's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of LG&E's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Contributions in aid of construction $ 17 $ 15 Regulatory liabilities 18 18 Deferred investment tax credits 8 8 Income taxes due to customers 119 125 State tax credit carryforwards 9 11 Lease liabilities 4 4 Valuation allowances (9) (11) Other 8 11 Total deferred tax assets 174 181 Deferred Tax Liabilities Plant - net 869 854 Regulatory assets 69 65 Lease right-of-use assets 3 4 Other 4 9 Total deferred tax liabilities 945 932 Net deferred tax liability $ 771 $ 751 At December 31, 2022, LG&E had $9 million of state credit carryforwards that expire in 2028 and a $9 million valuation allowance related to state credit carryforwards due to insufficient projected Kentucky taxable income. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ 60 $ 41 $ 53 Current - State 9 5 7 Total Current Expense (Benefit) 69 46 60 Deferred - Federal (10) 1 (4) Deferred - State 5 8 7 Total Deferred Expense (Benefit) (5) 9 3 Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 63 $ 54 $ 62 Total income tax expense (benefit) - Federal $ 49 $ 41 $ 48 Total income tax expense (benefit) - State 14 13 14 Total income tax expense (benefit) $ 63 $ 54 $ 62 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 70 $ 64 $ 64 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 12 12 Amortization of excess deferred federal and state income taxes (18) (20) (11) Other (2) (2) (3) Total increase (decrease) (7) (10) (2) Total income tax expense (benefit) $ 63 $ 54 $ 62 Effective income tax rate 18.8% 17.8% 20.3% 2022 2021 2020 Taxes, other than income Property and other $ 48 $ 46 $ 40 Total $ 48 $ 46 $ 40 (KU) The provision for KU's deferred income taxes for regulated assets and liabilities is based upon the ratemaking principles reflected in rates established by the KPSC, the VSCC and the FERC. The difference in the provision for deferred income taxes for regulated assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included in "Regulatory assets" or "Regulatory liabilities" on the Balance Sheets. Significant components of KU's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Contributions in aid of construction $ 9 $ 9 Regulatory liabilities 23 23 Deferred investment tax credits 21 22 Income taxes due to customers 136 143 State tax credit carryforwards 4 4 Lease liabilities 5 7 Valuation allowances (3) (3) Other 4 4 Total deferred tax assets 199 209 Deferred Tax Liabilities Plant - net 1,028 1,012 Regulatory assets 56 41 Pension and postretirement costs 6 13 Lease right-of-use assets 5 6 Other — 2 Total deferred tax liabilities 1,095 1,074 Net deferred tax liability $ 896 $ 865 At December 31, 2022, KU had $4 million of state credit carryforwards of which $3 million will expire in 2028 and $1 million that has an indefinite carryforward period. At December 31, 2022, KU had a $3 million valuation allowance related to state credit carryforwards due to insufficient projected Kentucky taxable income. Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ 63 $ 58 $ 40 Current - State 11 8 3 Total Current Expense (Benefit) 74 66 43 Deferred - Federal (3) (4) 11 Deferred - State 7 7 11 Total Deferred Expense (Benefit) 4 3 22 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 76 $ 67 $ 63 Total income tax expense (benefit) - Federal $ 58 $ 52 $ 49 Total income tax expense (benefit) - State 18 15 14 Total income tax expense (benefit) $ 76 $ 67 $ 63 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 84 $ 76 $ 72 Increase (decrease) due to: State income taxes, net of federal income tax benefit 16 14 14 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (21) (20) (17) Other (1) (1) (4) Total decrease (8) (9) (9) Total income tax expense (benefit) $ 76 $ 67 $ 63 Effective income tax rate 19.1% 18.4% 18.4% 2022 2021 2020 Taxes, other than income Property and other $ 45 $ 41 $ 37 Total $ 45 $ 41 $ 37 (All Registrants) Unrecognized Tax Benefits PPL or its subsidiaries file tax returns in four major tax jurisdictions. The income tax provisions for PPL Electric, LG&E and KU are calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if each domestic subsidiary filed a separate consolidated return. PPL Electric or its subsidiaries indirectly or directly file tax returns in three major tax jurisdictions, and LG&E and KU indirectly or directly file tax returns in two major tax jurisdictions. With few exceptions, at December 31, 2022, these jurisdictions, as well as the tax years that are no longer subject to examination, were as follows. PPL PPL Electric LG&E KU U.S. (federal) 2018 and prior 2018 and prior 2018 and prior 2018 and prior Pennsylvania (state) 2017 and prior 2017 and prior Kentucky (state) 2017 and prior 2017 and prior 2017 and prior 2017 and prior U.K. (foreign) 2019 and prior Other Narragansett Electric Acquisition (PPL) The acquisition of Narragansett Electric was deemed an asset acquisition for federal and state income tax purposes, as a result of PPL and National Grid making a tax election under Internal Revenue Code (IRC) §338(h)(10). Accordingly, the tax bases of substantially all of the assets acquired were increased to fair market value, which equaled net book value, thereby eliminating the related deferred tax assets and liabilities. This election resulted in tax goodwill that will be amortized for tax purposes over 15 years. Pennsylvania State Tax Reform (PPL and PPL Electric) On July 8, 2022, the Governor of Pennsylvania signed into law Pennsylvania House Bill 1342 (H.B. 1342). Among other changes to the state tax code, the bill reduces the corporate net income tax rate from 9.99% to 8.99% beginning January 1, 2023, and further reduces the rate annually by half a percentage point until the rate reaches 4.99% in 2031. GAAP requires that deferred tax assets and liabilities be measured at the enacted tax rate expected to apply when temporary book-to-tax differences are expected to be realized or settled. In 2022, PPL and PPL Electric recorded an increase in regulatory liabilities of $270 million for the remeasurement of regulated accumulated deferred tax balances and a deferred tax benefit of $5 million and $9 million, respectively, associated with the remeasurement of non-regulated accumulated deferred income tax balances. The amounts recorded are estimates that will be updated quarterly to reflect revised forecast, actual activity, and applicable orders from regulatory authorities. Inflation Reduction Act (All Registrants) On August 16, 2022, the Inflation Reduction Act (IRA) was signed into law. Among other things, the IRA enacted a new 15% corporate "book minimum tax," which is based on adjusted GAAP pre-tax income and is only applicable to corporations whose pre-tax income exceeds a certain threshold. PPL continues to assess the impacts of the IRA on the financial statements of PPL and the other Registrants and will monitor guidance issued by the U.S. Treasury in the future. In addition, the IRA enacted numerous new tax credits, largely associated with renewable energy. PPL continues to assess the applicability of these provisions to PPL and its subsidiaries.

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Financing Activities	Credit Arrangements and Short-term Debt (All Registrants) The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LG&E and KU also apply to PPL. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance Sheets except for borrowings under PPL Electric's term loan agreement due March 2024 and borrowings under LG&E's and KU's term loan agreements due July 2024, which are reflected in "Long-term debt." The following credit facilities were in place at: December 31, 2022 December 31, 2021 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL PPL Capital Funding Syndicated Credit Facility (a) (b) Dec 2026 $ 1,250 $ — $ 561 $ 689 $ — $ — Bilateral Credit Facility (a) (b) Mar 2023 100 — — 100 — — Bilateral Credit Facility (a) (b) Mar 2023 100 — 58 42 — 15 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 619 $ 831 $ — $ 15 PPL Electric Syndicated Credit Facility (a) (b) Dec 2026 650 — 146 504 — 1 Term Loan Credit Facility (a) (b) Mar 2024 250 250 — — — — Total PPL Electric Credit Facilities $ 900 $ 250 $ 146 $ 504 $ — $ 1 December 31, 2022 December 31, 2021 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of LG&E Syndicated Credit Facility (a) (b) Dec 2026 500 — 180 320 — 69 Term Loan Credit Facility (a) (b) Jul 2024 300 300 — — — — Total LG&E Credit Facilities $ 800 $ 300 $ 180 $ 320 $ — $ 69 KU Syndicated Credit Facility (a) (b) Dec 2026 400 — 101 299 — — Term Loan Credit Facility (a) (b) Jul 2024 300 300 — — — — Total KU Credit Facilities $ 700 $ 300 $ 101 $ 299 $ — $ — (a) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates, or applicable secured overnight financing rates, plus an applicable margin. (b) The facilities contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, subject to certain conditions, PPL Capital Funding may request that the capacity of one of its bilateral credit facilities expiring in March 2023 be increased by up to $30 million and PPL Capital Funding, PPL Electric, LG&E and KU may each request up to a $250 million increase in its syndicated credit facility's capacity. Participation in any such increase is at the sole discretion of each lender. (c) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL) In March 2022, PPL Capital Funding amended and restated its two existing $50 million bilateral credit facilities to extend the termination dates from March 9, 2022 to March 6, 2023 and to increase the borrowing capacity under each facility to $100 million. (PPL and LG&E) In July 2022, LG&E entered into a $300 million term loan credit facility expiring in 2024. On July 29, 2022, LG&E borrowed $300 million under this facility at an initial interest rate of 3.23%. The per annum interest rate fluctuates based on the applicable secured overnight financing rate plus a spread. The proceeds were used to repay short-term debt and for general corporate purposes. (PPL and KU) In July 2022, KU entered into a $300 million term loan credit facility expiring in 2024. On July 29, 2022, KU borrowed $300 million under this facility at an initial interest rate of 3.23%. The per annum interest rate fluctuates based on the applicable secured overnight financing rate plus a spread. The proceeds were used to repay short-term debt and for general corporate purposes. (PPL and PPL Electric) In September 2022, PPL Electric entered into a $250 million term loan credit facility expiring in 2024. On September 16, 2022, PPL Electric borrowed $250 million under this facility at an initial interest rate of 3.77%. The per annum interest rate fluctuates based on the applicable secured overnight financing rate plus a spread. The proceeds were used to repay long-term debt. (All Registrants) The Registrants maintain commercial paper programs to provide an additional financing source to fund short-term liquidity needs. Commercial paper issuances, included in "Short-term debt" on the Balance Sheets, are supported by the respective Registrant's credit facilities. The following commercial paper programs were in place at: December 31, 2022 December 31, 2021 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) 4.84% $ 1,350 $ 561 $ 789 $ — PPL Electric 4.74% 650 145 505 — LG&E (b) 4.94% 500 180 320 0.31% 69 KU (c) 4.90% 400 101 299 — Total $ 2,900 $ 987 $ 1,913 $ 69 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) In August 2022, LG&E increased the size of their commercial paper program to $500 million. (c) In August 2022, KU increased the size of their commercial paper program to $400 million. (d) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL Electric, LG&E and KU) See Note 15 for a discussion of intercompany borrowings. Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (d) 2022 2021 PPL Senior Unsecured Notes 3.95 % 2026 - 2047 $ 3,066 $ 1,566 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 4.06 % 2023 - 2050 8,957 9,205 Junior Subordinated Notes 7.39 % 2067 480 480 Term Loan Credit Facility 5.21 % 2024 850 — Total Long-term Debt before adjustments 13,353 11,251 Unamortized premium and (discount), net (32) (34) Unamortized debt issuance costs (78) (77) Total Long-term Debt 13,243 11,140 Less current portion of Long-term Debt 354 474 Total Long-term Debt, noncurrent $ 12,889 $ 10,666 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.26 % 2023 - 2049 $ 4,289 $ 4,539 Term Loan Credit Facility 5.17 % 2024 250 — Total Long-term Debt Before Adjustments 4,539 4,539 Unamortized discount (22) (22) Unamortized debt issuance costs (31) (33) Total Long-term Debt 4,486 4,484 Less current portion of Long-term Debt 340 474 Total Long-term Debt, noncurrent $ 4,146 $ 4,010 December 31, Weighted-Average Maturities (d) 2022 2021 LG&E Senior Secured Notes/First Mortgage Bonds (a) (c) 3.70 % 2025 - 2049 $ 2,024 $ 2,024 Term Loan Credit Facility 5.22 % 2024 300 — Total Long-term Debt Before Adjustments 2,324 2,024 Unamortized discount (4) (4) Unamortized debt issuance costs (13) (14) Total Long-term Debt 2,307 2,006 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 2,307 $ 2,006 KU Senior Secured Notes/First Mortgage Bonds (a) (c) 4.00 % 2023 - 2050 $ 2,642 $ 2,642 Term Loan Credit Facility 5.22 % 2024 300 — Total Long-term Debt Before Adjustments 2,942 2,642 Unamortized premium 5 5 Unamortized discount (9) (9) Unamortized debt issuance costs (18) (20) Total Long-term Debt 2,920 2,618 Less current portion of Long-term Debt 13 — Total Long-term Debt, noncurrent $ 2,907 $ 2,618 (a) Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all of PPL Electric’s tangible distribution properties and certain of its tangible transmission properties located in Pennsylvania, subject to certain exceptions and exclusions. The carrying value of PPL Electric's property, plant and equipment was approximately $11.8 billion and $11.3 billion at December 31, 2022 and 2021. Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $5.8 billion and $5.7 billion at December 31, 2022 and 2021. Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $7.1 billion and $6.9 billion at December 31, 2022 and 2021. (b) Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (a) above. The tax-exempt revenue bonds are subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes. Includes $250 million of notes that may be called at a redemption price equal to 100% of the principal amount, plus accrued and unpaid interest to, but excluding, the redemption date. (c) Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amounts, contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in (a) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate. At December 31, 2022, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $782 million for PPL, comprised of $473 million and $309 million for LG&E and KU. At December 31, 2022, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $66 million and $33 million for LG&E and KU. These variable rate tax-exempt revenue bonds are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events. (d) The table reflects principal maturities only, based on stated maturities, sinking fund requirements, or earlier put dates, and the weighted-average rates as of December 31, 2022. The aggregate maturities of long-term debt, based on sinking fund requirements, stated maturities or earlier put dates, for the periods 2023 through 2027 and thereafter are as follows: PPL PPL LG&E KU 2023 $ 354 $ 340 $ — $ 13 2024 1,501 900 300 300 2025 551 — 300 250 2026 904 — 90 164 2027 303 108 195 — Thereafter 9,740 3,191 1,439 2,215 Total $ 13,353 $ 4,539 $ 2,324 $ 2,942 (PPL and PPL Electric) In August 2022, the Lehigh County Industrial Development Authority remarketed $108 million of Pollution Control Revenue Refunding Bonds (PPL Electric Utilities Corporation Project), 2016 Series B due 2027 previously issued on behalf of PPL Electric. The bonds were remarketed at a long-term rate and will bear interest at 2.63% through their maturity date of February 15, 2027. In September 2022, the Lehigh County Industrial Development Authority remarketed $116 million of Pollution Control Revenue Refunding Bonds (PPL Electric Utilities Corporation Project), 2016 Series A due 2029 previously issued on behalf of PPL Electric. The bonds were remarketed at a long-term rate and will bear interest at 3.00% through their maturity date of September 1, 2029. (PPL Electric, LG&E and KU) See Note 15 for additional information related to intercompany borrowings. Legal Separateness (All Registrants) The subsidiaries of PPL are separate legal entities. PPL's subsidiaries are not liable for the debts of PPL. Accordingly, creditors of PPL may not satisfy their debts from the assets of PPL's subsidiaries absent a specific contractual undertaking by a subsidiary to pay PPL's creditors or as required by applicable law or regulation. Similarly, PPL is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of PPL's subsidiaries may not satisfy their debts from the assets of PPL or its other subsidiaries absent a specific contractual undertaking by PPL or its other subsidiaries to pay the creditors or as required by applicable law or regulation. Similarly, the subsidiaries of PPL Electric are each separate legal entities. These subsidiaries are not liable for the debts of PPL Electric. Accordingly, creditors of PPL Electric may not satisfy its debts from the assets of its subsidiaries absent a specific contractual undertaking by a subsidiary to pay the creditors or as required by applicable law or regulation. Similarly, PPL Electric is not liable for the debts of its subsidiaries, nor are its subsidiaries liable for the debts of one another. Accordingly, creditors of these subsidiaries may not satisfy their debts from the assets of PPL Electric (or its other subsidiaries) absent a specific contractual undertaking by PPL Electric or any such other subsidiary to pay such creditors or as required by applicable law or regulation. (PPL) Equity Securities Share Repurchases In August 2021, PPL's Board of Directors authorized share repurchases of up to $3 billion of PPL common shares. In 2021, PPL repurchased approximately $1 billion of PPL common shares. There were no share repurchases during the year ended December 31, 2022. Any additional amounts to be repurchased pursuant to this authority will depend on various factors, including PPL’s share price and market conditions. PPL may purchase shares on each trading day subject to market conditions and principles of best execution. Distributions and Related Restrictions In November 2022, PPL declared its quarterly common stock dividend, payable January 3, 2023, at 22.50 cents per share (equivalent to 0.90 cents per annum). On February 17, 2023, PPL announced a quarterly common stock dividend of 24.00 cents per share, payable April 3, 2023, to shareowners of record as of March 10, 2023. Future dividends will be declared at the discretion of the Board of Directors and will depend upon future earnings, cash flows, financial and legal requirements and other factors. Neither PPL Capital Funding nor PPL may declare or pay any cash dividend or distribution on its capital stock during any period in which PPL Capital Funding defers interest payments on its 2007 Series A Junior Subordinated Notes due 2067. At December 31, 2022, no interest payments were deferred. RIE has $3 million of certain issues of non-participating cumulative preferred stock outstanding that can be redeemed at the option of RIE. There are no mandatory redemption provisions on the cumulative preferred stock. Dividends on the cumulative preferred stock accrue quarterly and are prior to any dividends on the common stock of RIE. Pursuant to the preferred stock arrangement, as long as any preferred stock is outstanding, certain restrictions on payment of common stock dividends would come into effect if the common stock equity of RIE was, or by reason of payment of such dividends became, less than 25% of total capitalization of RIE. RIE was current on the preferred stock dividends and was in compliance with this covenant and accordingly, was not restricted as to the payment of common stock dividends under the foregoing provisions as of December 31, 2022. (All Registrants) PPL relies on dividends or loans from its subsidiaries to fund PPL's dividends to its common shareholders. The net assets of certain PPL subsidiaries are subject to legal restrictions. LG&E, KU and PPL Electric are subject to Section 305(a) of the Federal Power Act, which makes it unlawful for a public utility to make or pay a dividend from any funds "properly included in capital account." The meaning of this limitation has never been clarified under the Federal Power Act. LG&E, KU and PPL Electric believe, however, that this statutory restriction, as applied to their circumstances, would not be construed or applied by the FERC to prohibit the payment from retained earnings of dividends that are not excessive and are for lawful and legitimate business purposes. In February 2012, LG&E and KU petitioned the FERC requesting authorization to pay dividends in the future based on retained earnings balances calculated without giving effect to the impact of purchase accounting adjustments for PPL's 2010 acquisition of LG&E and KU. In May 2012, the FERC approved the petitions with the further condition that each utility may not pay dividends if such payment would cause its adjusted equity ratio to fall below 30% of total capitalization. Accordingly, at December 31, 2022, net assets of $1.4 billion for LG&E and $1.9 billion for KU were restricted for purposes of paying dividends to LKE, and net assets of $1.8 billion for LG&E and $2.1 billion for KU were available for payment of dividends to LKE. LG&E and KU believe they will not be required to change their current dividend practices as a result of the foregoing requirement. In addition, under Virginia law, KU is prohibited from making loans to affiliates without the prior approval of the VSCC. There are no comparable statutes under Kentucky law applicable to LG&E and KU, or under Pennsylvania law applicable to PPL Electric. However, orders from the KPSC require LG&E and KU to obtain prior consent or approval before lending amounts to PPL.

Acquisitions, Development and D

Acquisitions, Development and Divestitures	12 Months Ended
	Dec. 31, 2022
Contractors [Abstract]
Mergers, Acquisitions and Dispositions Disclosures	(PPL) Acquisitions Acquisition of Narragansett Electric On May 25, 2022, PPL Rhode Island Holdings acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid U.S., a subsidiary of National Grid plc (the Acquisition). Narragansett Electric, whose service area covers substantially all of Rhode Island, is primarily engaged in the transmission and distribution of electricity and distribution of natural gas. The Acquisition expands PPL's portfolio of regulated natural gas and electricity transmission and distribution assets, has improved PPL's credit metrics and is expected to enhance long term earnings growth. Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). The consideration for the Acquisition consisted of approximately $3.8 billion in cash and approximately $1.5 billion of long-term debt assumed through the transaction. The fair value of the consideration paid for Narragansett Electric was as follows (in billions): Aggregate enterprise consideration $ 5.3 Less: fair value of assumed long-term debt outstanding 1.5 Total cash consideration $ 3.8 The $3.8 billion total cash consideration paid was funded with proceeds from PPL's 2021 sale of its U.K. utility business. In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid U.S. and Narragansett Electric have entered into a transition services agreement (TSA), pursuant to which National Grid has agreed to provide certain transition services to Narragansett Electric to facilitate the transition of the operation of Narragansett Electric to PPL following the Acquisition, as agreed upon in the Narragansett SPA. The TSA is for an initial two-year term and is subject to extension as necessary to complete the successful transition. TSA costs of $123 million were incurred for the twelve month period ended December 31, 2022. Acquisition Approval The Acquisition required certain approvals or waivers, including, among others, approval of National Grid USA's shareholders, authorizations or waivers from the Rhode Island Division of Public Utilities and Carriers, the Massachusetts Department of Public Utilities, the Federal Communications Commission (FCC), and the FERC, as well as review under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended. All such approvals were received prior to closing of the Acquisition. Commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island As a condition to the Acquisition, PPL made certain commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island. As a result: • RIE provided a credit to all its electric and natural gas distribution customers in the total amount of $50 million ($40 million net of tax benefit). Based on the relative number of electric distribution customers and natural gas distribution customers as of November 1, 2022, RIE refunded, in the form of a bill credit, $33 million to electric customers and $17 million to natural gas customers of amounts collected from customers since the Acquisition date. Each electric customer received the same credit, and each natural gas customer received the same credit. A reduction of revenue and a regulatory liability of $50 million for the amounts refunded were recorded during the quarter ended September 30, 2022. These credits were issued during the fourth quarter of 2022. The amounts refunded will not impact RIE's earnings sharing regulatory mechanism. • RIE forgave approximately $44 million ($21 million net of allowance for doubtful accounts) in arrearages for low-income and protected residential customers, which represents 100% of the arrearages over 90 days for those customers as of March 31, 2022. PPL deemed these accounts uncollectible and fully reserved for them as of September 30, 2022, resulting in an increase to "Other operations and maintenance expense" on the Statement of Income of $23 million for the year ended December 31, 2022. • RIE will not file a base rate case seeking an increase in base distribution rates for natural gas and/or electric service sooner than three years from the Acquisition date, and RIE will not submit a request for a change in base rates unless and until there is at least twelve months of operating experience under PPL's exclusive leadership and after the TSA with National Grid terminates. • RIE will forgo potential recovery of any and all transition costs which PPL estimates will be approximately $408 million through June 30, 2024, and includes (1) the installation of certain information technology systems; (2) modification and enhancements to physical facilities in Rhode Island; and (3) incurring costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $181 million for the year ended December 31, 2022. • RIE will not seek to recover any transaction costs related to the Acquisition, which were $27 million through December 31, 2022, including $18 million for the year ended December 31, 2022 recorded in "Other operations and maintenance" on the Statement of Income. • RIE will not seek to recover in rates any markup charged by National Grid U.S. and/or its affiliates under the TSA. These amounts were $3 million as of December 31, 2022. • In June 2022, RIE expensed $20 million of regulatory assets as of the Acquisition date for the Gas Business Enablement (GBE) project and for certain Cybersecurity/IT investments related to GBE. The expense was recorded to "Other operations and maintenance" on the Statements of Income for the year ended December 31, 2022. RIE will not seek to recover these regulatory assets from customers in any future proceedings. • RIE will exclude all goodwill from the ratemaking capital structure. • RIE will hold harmless Rhode Island customers from any changes to Accumulated Deferred Income Taxes (ADIT) as a result of the Acquisition. RIE reserves the right to seek rate adjustments based on future changes to ADIT that are not related to the Acquisition. • RIE will not increase its revenue requirement to a level higher than what would exist in the absence of the Acquisition as a result of any restatement of pension and other post-retirement benefits plan assets and liabilities to fair value after the close of the Acquisition. • Rhode Island Holdings contributed $2.5 million to the Rhode Island Commerce Corporation's Renewable Energy Fund and will not use any of the $2.5 million to meet its pre-existing renewable energy credit goals in Rhode Island or any other state. This contribution was made during the year ended December 31, 2022 and was recorded in "Other Income (Expense)" on the Statement of Income. • RIE will make available up to $2.5 million for the Rhode Island Attorney General to utilize as needed in evaluating PPL's report on RIE's specific decarbonization goals to support Rhode Island's 2021 Act on Climate or to assess the future of the gas distribution business in Rhode Island. This amount was accrued during the year ended December 31, 2022 and was recorded in "Other Income (Expense) - net" on the Statement of Income. • Various other operational and reporting commitments have been established. Purchase Price Allocation The operations of Narragansett Electric are subject to the accounting for certain types of regulation as prescribed by GAAP. The carrying value of Narragansett Electric’s assets and liabilities subject to rate-setting and cost recovery provisions provide revenues derived from costs, including a return on investment of net assets and liabilities included in rate base. As such, the fair values of these assets and liabilities equal their carrying values. Accordingly, neither the assets acquired or liabilities assumed, nor the unaudited pro forma financial information presented below, reflect any adjustments related to these amounts. As of December 31, 2022, the excess of the purchase price over the estimated fair values of the assets acquired and liabilities assumed was $1,586 million, which has been recorded as goodwill. PPL has elected to not reflect the effects of purchase accounting in the separate financial statements of RIE or PPL's Rhode Island Regulated segment. Accordingly, the Rhode Island Regulated segment includes $725 million of acquired legacy goodwill. The remaining excess purchase price of $861 million is included in PPL's Corporate and Other category for segment reporting purposes. The goodwill reflects the value paid for the expected continued growth of a rate-regulated business located in a defined service area with a constructive regulatory environment, the ability of PPL to leverage its assembled workforce to take advantage of those growth opportunities and the attractiveness of stable, growing cash flows. The tax goodwill is deductible for income tax purposes over a 15 year period, and as such, deferred taxes will be recorded as the tax deductions are taken. The table below shows the preliminary allocation of the purchase price to the assets acquired and liabilities assumed that were recorded in PPL’s Consolidated Balance Sheet as of the Acquisition date. The allocation is subject to change during the one-year measurement period as additional information is obtained about the facts and circumstances that existed at closing. As a result, the amount of goodwill included below may change by a material amount as PPL finalizes the allocation of the purchase price. Adjustments to certain assets acquired and liabilities assumed resulted in an increase in goodwill of $5 million since the initial purchase price allocation as of the Acquisition date. Purchase Price Allocation as of December 31, 2022 Assets Current Assets Cash and Cash Equivalents $ 154 Accounts Receivable (a) 195 Unbilled Revenues 54 Price Risk Management Assets 99 Regulatory Assets 75 Other Current Assets 65 Total Current Assets 642 Purchase Price Allocation as of December 31, 2022 Noncurrent Assets Property, Plant and Equipment, net 3,988 Regulatory Assets 395 Goodwill 1,586 Other Noncurrent Assets 166 Total Noncurrent Assets 6,135 Total Assets $ 6,777 Liabilities Current Liabilities Long-Term Debt Due Within One Year $ 14 Accounts Payable 180 Taxes Accrued 44 Regulatory Liabilities 239 Other Current Liabilities 198 Total Current Liabilities 675 Noncurrent Liabilities Long-Term Debt 1,496 Regulatory Liabilities 643 Other Deferred Credits and Noncurrent Liabilities 143 Noncurrent Liabilities 2,282 Total Purchase Price (Balance Sheet Net Assets) $ 3,820 (a) Amounts represent fair value as of May 25, 2022. The gross contractual amount is $255 million. Cash flows not expected to be collected as of May 25, 2022 were $60 million. Pro Forma Financial Information The actual RIE Operating Revenues and Net income attributable to PPL included in PPL's Statement of Income for the period ended December 31, 2022, and PPL's unaudited pro forma 2022 and 2021 Operating Revenues and Net Income (Loss) attributable to PPL, including RIE, as if the Acquisition had occurred on January 1, 2021 are as follows. Operating Revenues Net Income (Loss) Actual RIE results included from May 25, 2022 - December 31, 2022 (a) $ 1,038 $ (44) PPL Pro Forma for the year ended 2022 8,667 790 PPL Pro Forma for the year ended 2021 7,478 159 (a) Net Income (Loss) includes expenses of $98 million (pre-tax) related to commitments made as a condition of the Acquisition. The pro forma financial information presented above has been derived from the historical consolidated financial statements of PPL and Narragansett Electric. Non-recurring items included in the 2022 pro forma financial information include: (a) $18 million (pre-tax) of transaction costs related to the Acquisition, primarily for advisory, accounting and legal fees incurred, (b) $223 million (pre-tax) of Acquisition integration costs, (c) a $50 million reduction of revenue (pre-tax), write-offs of $43 million (pre-tax) of certain accounts receivable and regulatory assets of RIE and $5 million (pre-tax) of expenses accrued in support of Rhode Island's decarbonization goals, all of which were conditions of the Acquisition, and (d) the income tax effect of these items, which was tax effected at the statutory federal income tax rate of 21%. Non-recurring items included in the 2021 pro forma financial information include: (a) $38 million (pre-tax) of Acquisition integration costs and (b) the income tax effect of this item, which was tax effected at the statutory federal income tax rate of 21%. Losses from the discontinued operations (net of income taxes) of PPL of $1,498 million in 2021 were excluded from the pro forma amount above. Divestitures Sale of Safari Holdings On September 29, 2022, PPL signed a definitive agreement to sell all of Safari Holdings membership interests to Aspen Power Services, LLC (Aspen Power). On November 1, 2022, PPL completed the sale (the Transaction). A loss on sale of $60 million ($46 million net of tax benefit) was recorded in "Other operation and maintenance" on the Statement of Income for the year ended December 31, 2022. As a result of the Transaction, $53 million of goodwill previously presented in the Corporate and Other category for segment reporting purposes was written-off. The accounting for the closing of the Transaction was substantially completed in the fourth quarter of 2022. Final closing adjustments are expected to be completed in the first quarter of 2023. In connection with the closing of the Transaction, PPL provided certain guarantees and other assurances. See Note 14 to the Financial Statements for additional information. Discontinued Operation s Sale of the U.K. Utility Business On June 14, 2021, PPL WPD Limited completed the sale of PPL's utility business to National Grid Holdings One plc (National Grid U.K.), a subsidiary of National Grid plc. The transaction resulted in cash proceeds of $10.7 billion inclusive of foreign currency hedges executed by PPL. PPL received net proceeds, after taxes and fees, of $10.4 billion. PPL WPD Limited agreed to indemnify National Grid U.K. for certain tax related matters. See Note 14 for additional information. PPL has not had and will not have any significant involvement with the U.K. utility business since completion of the sale. Summarized Results of Discontinued Operations The operations of the U.K. utility business are included in "Income (Loss) from Discontinued Operations (net of income taxes)" on the Statements of Income. Following are the components of discontinued operations in the Statements of Income for the years ended December 31: 2022 2021 2020 Operating Revenues $ — $ 1,344 $ 2,133 Operating Expenses — 467 916 Other Income (Expense) - net — 202 167 Interest Expense (a) — 209 367 Income before income taxes — 870 1,017 Loss on sale — (1,609) — Income tax (benefit) expense (42) 759 188 Income (Loss) from Discontinued Operations (net of income taxes) $ 42 $ (1,498) $ 829 (a) No interest from corporate level debt was allocated to discontinued operations.

Leases

Leases	12 Months Ended
	Dec. 31, 2022
Leases [Line Items]
Lessee, Operating Leases [Text Block]	(All Registrants) LG&E and KU have entered into various operating leases primarily for office space, vehicles and railcars. The leases generally have fixed payments with expiration dates ranging from 2023 to 2040, some of which have options to extend the leases from one year to ten years and some have options to terminate at LG&E's and KU's discretion. PPL has also entered into various operating leases primarily for office and warehouse space. These leases generally have fixed payments with expiration dates ranging from 2024 through 2030. RIE has various operating leases, primarily related to a transmission line, buildings, land, and fleet vehicles used to support the electric and gas operations, with lease terms ranging between 1 and 50 years. In measuring lease liabilities, the Company excludes variable lease payments, other than those that depend on an index or rate, or are in substance fixed payments, and includes lease payments made at or before the commencement date. The variable lease payments were not material for the year ended December 31, 2022. PPL Electric also has operating leases which do not have a significant impact to its operations. (PPL, LG&E and KU) Lessee Transactions The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2022 2021 2020 PPL Lease cost: Operating lease cost $ 20 $ 24 $ 28 Short-term lease cost 6 6 7 Total lease cost $ 26 $ 30 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 6 $ 8 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 7 $ 9 KU Lease cost: Operating lease cost $ 9 $ 10 $ 13 Short-term lease cost 2 1 1 Total lease cost $ 11 $ 11 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2022 2021 2020 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 23 $ 24 Right-of-use asset obtained in exchange for new operating lease liabilities 15 12 17 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 8 $ 6 $ 7 Right-of-use asset obtained in exchange for new operating lease liabilities 4 4 6 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 12 $ 10 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 5 7 9 The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2022. PPL LG&E KU 2023 $ 24 $ 6 $ 9 2024 17 5 7 2025 12 3 4 2026 5 1 1 2027 4 1 — Thereafter 7 — — Total $ 69 $ 16 $ 21 Weighted-average discount rate 3.1% 3.17% 3.4% Weighted-average remaining lease term (in years) 4 3 3 Current lease liabilities (a) $ 22 $ 6 $ 8 Non-current lease liabilities (a) 42 9 12 Right-of-use assets (b) 60 13 19 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in " Other noncurrent assets Lessor Transactions Third parties leased land from LG&E and KU at certain generation plants to produce refined coal used to generate electricity. The leases were operating leases and expired in 2021. Payments were allocated among lease and non-lease components as stated in the agreements. Lease payments were fixed or determined based on the amount of refined coal used in electricity generation at the facility. Payments received were primarily recorded as a regulatory liability and amortized in accordance with regulatory approvals. There are certain leases in which RIE is the lessor. Revenue under such leases was immaterial for the year ended December 31, 2022. The following table shows the lease income recognized for the years ended December 31: 2022 2021 2020 PPL $ 6 11 16 LG&E 2 5 6 KU — 5 9

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
	Dec. 31, 2022
Stock-Based Compensation [Line Items]
Stock-Based Compensation	(PPL and PPL Electric) Under the SIP and the ICPKE (together, the Plans), restricted shares of PPL common stock, restricted stock units, performance units and stock options may be granted to officers and other key employees of PPL, PPL Electric and other affiliated companies. Awards under the Plans are made by the Compensation Committee of the PPL Board of Directors, in the case of the SIP, and by the PPL Corporate Leadership Council (CLC), in the case of the ICPKE. The following table details the award limits under each of the Plans. Total Plan Annual Grant Limit Annual Grant Annual Grant Limit Award PPL Common Stock Limit For awards For awards Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) SIP 15,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2 % 3,000,000 Any portion of these awards that has not been granted may be carried over and used in any subsequent year. If any award lapses, the rights of the participant terminate, or, with respect to certain awards, is forfeited, and the shares of PPL common stock underlying such an award are again available for grant. Shares delivered under the Plans may be in the form of authorized and unissued PPL common stock, common stock held in treasury by PPL or PPL common stock purchased on the open market (including private purchases) in accordance with applicable securities laws. Restricted Stock Units Restricted stock units represent the right to receive shares of PPL common stock in the future, generally three years after the date of grant, in an amount based on the fair value of PPL common stock on the date of grant. Under the SIP, each restricted stock unit entitles the grant recipient to accrue additional restricted stock units equal to the amount of quarterly dividends paid on PPL stock. These additional restricted stock units are deferred and payable in shares of PPL common stock at the end of the restriction period. Dividend equivalents on restricted stock unit awards granted under the ICPKE are currently paid in cash when dividends are declared by PPL. The fair value of restricted stock units granted is recognized on a straight-line basis over the restriction period or through the date at which the employee reaches retirement eligibility. The fair value of restricted stock units granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. Recipients of restricted stock units granted under the ICPKE may also be granted the right to receive dividend equivalents through the end of the restriction period or until the award is forfeited. Restricted stock units are subject to forfeiture or accelerated payout under the plan provisions for termination, retirement, disability and death of employees. Restrictions lapse on restricted stock units fully, in certain situations, as defined by each of the Plans. The weighted-average grant date fair value of restricted stock units granted was: 2022 2021 2020 PPL $ 27.52 $ 28.00 $ 35.30 PPL Electric 26.66 27.96 35.37 Restricted stock unit activity for 2022 was: Restricted Weighted- PPL Nonvested, beginning of period 1,004,583 $ 31.19 Granted 620,708 27.52 Vested (427,095) 31.55 Forfeited (15,779) 29.61 Nonvested, end of period 1,182,417 29.16 PPL Electric Nonvested, beginning of period 131,287 $ 31.50 Transfer between registrants (30,353) 30.03 Granted 51,832 26.66 Vested (41,233) 32.19 Forfeited (1,747) 32.19 Nonvested, end of period 109,786 28.91 Substantially all restricted stock unit awards are expected to vest. The total fair value of restricted stock units vesting for the years ended December 31 was: 2022 2021 2020 PPL $ 12 $ 8 $ 19 PPL Electric 1 1 3 Performance Units - Total Shareowner Return Performance units based on relative Total Shareowner Return (TSR) are intended to encourage and reward future corporate performance. Performance units represent a target number of shares (Target Award) of PPL's common stock that the recipient would receive upon PPL's attainment of the applicable performance goal. Performance is determined based on TSR during a three The fair value of TSR performance units granted to retirement-eligible employees is recognized as compensation expense on a straight-line basis over a one three one The fair value of each performance unit granted was estimated using a Monte Carlo pricing model that considers stock beta, a risk-free interest rate, expected stock volatility and expected life. The stock beta was calculated comparing the risk of the individual securities to the average risk of the companies in the index group. The risk-free interest rate reflects the yield on a U.S. Treasury bond commensurate with the expected life of the performance unit. Volatility over the expected term of the performance unit is calculated using daily stock price observations for PPL and all companies in the index group and is evaluated with consideration given to prior periods that may need to be excluded based on events not likely to recur that had impacted PPL and the companies in the index group. PPL uses a mix of historic and implied volatility to value awards. The weighted-average assumptions used in the model were: 2022 2021 2020 Expected stock volatility 22.79% 27.81% 15.64% Expected life 3 years 3 years 3 years The weighted-average grant date fair value of TSR performance units granted was: 2022 2021 2020 PPL $ 34.27 $ 32.44 $ 37.63 PPL Electric 34.42 32.92 38.64 TSR performance unit activity for 2022 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 633,773 $ 34.68 Granted 298,795 34.27 Forfeited (a) (245,861) 35.48 Nonvested, end of period 686,707 34.21 TSR Performance Units Weighted- PPL Electric Nonvested, beginning of period 15,354 $ 34.36 Granted 14,238 34.42 Forfeited (a) (3,113) 35.58 Nonvested, end of period 26,479 34.25 (a) Primarily related to the forfeiture of 2019 domestic performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. For the year ended December 31, 2021, $2 million of TSR performance units vested. All awards vested were associated with the sale of the U.K. utility business. See Note 9 for additional information on the sale of the U.K. utility business. No TSR performance units vested for the years ended December 31, 2022 and 2020. Amounts for PPL Electric are insignificant. Performance Units - Return on Equity In 2017, PPL changed its executive compensation mix to add performance units based on achievement of a corporate Return on Equity (ROE). ROE performance units were intended to further align compensation with the company’s strategy and reward for future corporate performance. The Compensation Committee, eliminated the use of ROE performance units due to changes in its long-term incentive mix beginning in January 2022 . Payout of these performance units will be based on the calculated average of the annual corporate ROE for each year of the three The fair value of each ROE performance unit is based on the closing price of PPL Common Stock on the date of grant. The fair value of ROE performance units is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value awards granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. As these awards are based on performance conditions, the level of attainment is monitored each reporting period and compensation expense is adjusted based on the expected attainment level. The weighted-average grant date fair value of ROE performance units granted was: 2022 2021 2020 PPL $ 30.81 $ 30.08 $ 34.95 PPL Electric 30.70 29.39 35.59 ROE performance unit activity for 2022 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 722,353 $ 31.28 Granted (a) 257,199 30.81 Vested (470,182) 30.76 Nonvested, end of period 509,370 31.53 PPL Electric Nonvested, beginning of period 15,354 $ 30.27 Granted (a) 3,663 30.70 Vested (6,311) 30.78 Nonvested, end of period 12,706 30.14 (a) Represents attainment updates to the 2019 awards that paid out at 200% of target, as well as dividend equivalents that accumulated on outstanding 2020 and 2021 awards. The total fair value of ROE performance units vesting for the years ended December 31 was: 2022 2021 2020 PPL $ 12 $ 16 $ 8 PPL Electric — — 1 Performance Units - Earnings Growth Beginning in 2022, PPL changed its executive compensation mix to add performance units based on achievement of corporate earnings growth (EG) metrics. EG performance units are intended to further align executive compensation with the company’s future strategy. Payout of these performance units will be based on the earnings growth above the projected midpoint of ongoing earnings for the three The fair value of each EG performance unit is based on the closing price of PPL Common Stock on the date of grant. The fair value of EG performance units is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value awards granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. As these awards are based on performance conditions, the level of attainment is monitored each reporting period and compensation expense is adjusted based on the expected attainment level. The weighted-average grant date fair value of EG performance units granted was: 2022 PPL $ 29.29 PPL Electric 29.35 EG performance unit activity for 2022 was: EG Performance Unit Weighted- PPL Nonvested, beginning of period — $ — Granted 141,880 29.29 Nonvested, end of period 141,880 29.29 PPL Electric Nonvested, beginning of period — $ — Granted 6,888 29.35 Nonvested, end of period 6,888 29.35 Performance Units - Environmental, Social and Governance Beginning in 2022, PPL changed its executive compensation mix to add performance units based on environmental, social and governance (ESG) metrics. ESG performance units are tied to climate-related performance and intended to further align executive compensation with the company’s future strategy. Payout of these performance units will be based on the attainment of reductions in company vehicle emissions and building energy use, as well as the retirement of Mill Creek Unit 1, a coal-fired generating facility in Kentucky. ESG performance units can be paid up to 200% of the Target Award or forfeited with no payout if performance is below a minimum established performance threshold. Dividends payable during the performance cycle accumulate and are converted into additional performance units and are payable in shares of PPL common stock upon completion of the performance period based on the Compensation Committee's determination of achievement of the performance goals. Under the plan provisions, these performance units are subject to forfeiture upon termination of employment other than retirement, disability or death of an employee. The fair value of each ESG performance unit is based on the closing price of PPL Common Stock on the date of grant. The fair value of ESG performance units is recognized on a straight-line basis over the service period or through the date at which the employee reaches retirement eligibility. The fair value awards granted to retirement-eligible employees is recognized as compensation expense immediately upon the date of grant. As these awards are based on performance conditions, the level of attainment is monitored each reporting period and compensation expense is adjusted based on the expected attainment level. The weighted-average grant date fair value of ESG performance units granted was: 2022 PPL $ 29.29 PPL Electric 29.35 ESG performance unit activity for 2022 was: ESG Performance Unit Weighted- PPL Nonvested, beginning of period — $ — Granted 141,880 29.29 Nonvested, end of period 141,880 29.29 PPL Electric Nonvested, beginning of period — $ — Granted 6,888 29.35 Nonvested, end of period 6,888 29.35 Stock Options PPL's Compensation, Governance and Nominating Committee, now known as the Compensation Committee, eliminated the use of stock options due to changes in its long-term incentive mix beginning in January 2014 . Under the Plans, stock options had been granted with an option exercise price per share not less than the fair value of PPL's common stock on the date of grant. Options outstanding at December 31, 2022, are fully vested. All options expire no later than 10 years from the grant date. The options become exercisable immediately in certain situations, as defined by each of the Plans. Stock option activity for 2022 was: Number Weighted Weighted- Aggregate PPL Outstanding at beginning of period 766,002 $ 26.57 Exercised (594,450) 26.44 Outstanding and exercisable at end of period 171,552 27.04 0.1 $ — For 2022, 2021 and 2020, PPL received $18 million, $10 million and $8 million in cash from stock options exercised. The total intrinsic value of stock options exercised was insignificant in each of those years. The related income tax benefits realized were not significant. Compensation Expense Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was: 2022 2021 2020 PPL $ 36 $ 34 $ 28 PPL Electric 2 11 10 The income tax benefit related to above compensation expense was as follows: 2022 2021 2020 PPL $ 10 $ 10 $ 8 PPL Electric 1 3 3 At December 31, 2022, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 23 1.8 PPL Electric 2 1.8

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Retirement and Postemployment Benefits	(All Registrants) Defined Benefits Certain employees of PPL's subsidiaries are eligible for pension benefits under non-contributory defined benefit pension plans with benefits based on length of service and final average pay, as defined by the plans. Effective January 1, 2012, PPL's primary defined benefit pension plan was closed to all newly hired salaried employees. Effective July 1, 2014, PPL's primary defined benefit pension plan was closed to all newly hired bargaining unit employees. Newly hired employees are eligible to participate in the PPL Retirement Savings Plan, a 401(k) savings plan with enhanced employer contributions. The defined benefit pension plans of LKE and its subsidiaries were closed to new salaried and bargaining unit employees hired after December 31, 2005. Employees hired after December 31, 2005 receive additional company contributions above the standard matching contributions to their savings plans. The pension plans sponsored by LKE and LG&E were merged effective January 1, 2020 into the LG&E and KU Pension Plan. The merged plan is sponsored by LKE. LG&E and KU participate in this plan. The Rhode Island defined benefit plans provide most union employees, as well as non-union employees hired before January 1, 2011, with a retirement benefit. Supplemental non-qualified, non-contributory executive retirement programs provide additional defined pension benefits for certain executives. PPL and certain of its subsidiaries also provide supplemental retirement benefits to executives and other key management employees through unfunded nonqualified retirement plans. Certain employees of PPL's subsidiaries are eligible for certain health care and life insurance benefits upon retirement through contributory plans. Effective January 1, 2014, the PPL Postretirement Medical Plan was closed to all newly hired salaried employees. Effective July 1, 2014, the PPL Postretirement Medical Plan was closed to all newly hired bargaining unit employees. Postretirement health benefits may be paid from 401(h) accounts established as part of the PPL Retirement Plan and the LG&E and KU Pension Plan within the PPL Services Corporation Master Trust, funded VEBA trusts and company funds. The Rhode Island postretirement benefit plans provide health care and life insurance coverage to eligible retired employees. Eligibility is based on age and length of service requirements and, in most cases, retirees must contribute to the cost of their coverage. (PPL) The following table provides the components of net periodic defined benefit costs (credits) for PPL's pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 Net periodic defined benefit costs (credits): Service cost $ 51 $ 56 $ 56 $ 7 $ 6 $ 6 Interest cost 144 121 146 20 16 19 Expected return on plan assets (276) (255) (246) (28) (23) (21) Amortization of: Prior service cost (credit) 8 8 9 1 1 1 Actuarial (gain) loss 51 93 89 (5) (1) — Net periodic defined benefit costs (credits) prior to settlements and termination benefits (22) 23 54 (5) (1) 5 Settlements (a) 23 18 23 — — — Net periodic defined benefit costs (credits) $ 1 $ 41 $ 77 $ (5) $ (1) $ 5 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (loss)/gain allocated at acquisition $ 33 $ — $ — $ (49) $ — $ — Settlement (23) (18) (23) — — — Net (gain) loss 242 42 (221) — (53) (6) Prior service cost (credit) — 3 1 — — 5 Amortization of: Prior service (cost) credit (8) (8) (9) (1) (1) (1) Actuarial gain (loss) (51) (93) (89) 5 1 — Total recognized in OCI and regulatory assets/liabilities 193 (74) (341) (45) (53) (2) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 194 $ (33) $ (264) $ (50) $ (54) $ 3 (a) Settlement charges incurred as a result of the amount of lump sum payment distributions, primarily from the LKE qualified pension plan. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized in accordance with existing regulatory practice. The portion of the settlement attributed to LKE's operations outside of the jurisdiction of the KPSC has been charged to expense. For PPL's pension and postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 OCI $ 142 $ (70) $ (428) $ 13 $ (42) $ (12) Regulatory assets/liabilities 51 (4) 87 (58) (11) 10 Total recognized in OCI and $ 193 $ (74) $ (341) $ (45) $ (53) $ (2) (PPL and LG&E) PPL and LG&E use base mortality tables issued by the Society of Actuaries for all defined benefit pension and other postretirement benefit plans. The Pri-2012 base table and the MP-2020 projection scale with varying adjustment factors based on the underlying demographic and geographic differences and experience of the plan participants was used for all periods. The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 PPL Discount rate 5.80 % 3.15 % 5.81 % 3.13 % Rate of compensation increase 3.77 % 3.76 % 3.78 % 3.77 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 PPL Discount rate 3.35 % 2.92 % 3.64 % 3.54 % 2.84 % 3.60 % Rate of compensation increase 3.74 % 3.76 % 3.79 % 2.84 % 3.75 % 3.76 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 6.52 % 6.48 % 6.44 % (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. (PPL) The following table provides the assumed health care cost trend rates for the years ended December 31: 2022 2021 2020 PPL Health care cost trend rate assumed for next year – obligations 6.50 % 6.25 % 6.50 % – cost 6.25 % 6.50 % 6.60 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.00 % 5.00 % 5.00 % – cost 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate – obligations 2029 2027 2027 – cost 2027 2027 2024 The funded status of PPL's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 Change in Benefit Obligation Benefit Obligation, beginning of period $ 3,989 $ 4,251 $ 504 $ 573 Service cost 51 56 7 6 Interest cost 144 121 20 16 Participant contributions — — 9 14 Plan amendments — 2 — — Actuarial (gain) loss (1,026) (88) (114) (50) Acquisition (a) 553 — 163 — Settlements (111) (106) — — Gross benefits paid (267) (247) (55) (55) Benefit Obligation, end of period 3,333 3,989 534 504 Change in Plan Assets Plan assets at fair value, beginning of period 3,887 4,068 367 367 Actual return on plan assets (992) 125 (86) 25 Employer contributions 9 47 19 18 Participant contributions — — 7 11 Acquisition (a) 623 — 160 — Settlements (111) (106) — — Gross benefits paid (267) (247) (50) (54) Plan assets at fair value, end of period 3,149 3,887 417 367 Funded Status, end of period $ (184) $ (102) $ (117) $ (137) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 33 $ 91 $ 9 $ — Current liability (10) (10) (14) (15) Noncurrent liability (207) (183) (112) (122) Net amount recognized, end of period $ (184) $ (102) $ (117) $ (137) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 14 $ 22 $ 11 $ 12 Net actuarial (gain) loss 827 626 (95) (51) Total $ 841 $ 648 $ (84) $ (39) Total accumulated benefit obligation $ 3,197 $ 3,786 (a) Related to the pension and other postretirement plans assumed for the employees of Rhode Island Energy. See Note 9 for additional details on the acquisition of Narragansett Electric. For PPL's pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 AOCI $ 183 $ 239 $ 13 $ (2) Regulatory assets/liabilities 658 409 (97) (37) Total $ 841 $ 648 $ (84) $ (39) The actuarial gain for pension plans in 2022 was primarily related to a change in the discount rate used to measure the benefit obligations of those plans. The actuarial gain for pension plans in 2021 was related to a change in the discount rate used to measure the benefit obligations of those plans. The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2022 2021 Projected benefit obligation $ 2,818 $ 193 Fair value of plan assets 2,601 — ABO in excess of plan assets 2022 2021 Accumulated benefit obligation $ 1,720 $ 177 Fair value of plan assets 1,581 — (PPL Electric) Although PPL Electric does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by PPL Services based on its participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retirees are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to PPL Electric resulted in assets/(liabilities) at December 31 as follows: 2022 2021 Pension $ (34) $ 42 Other postretirement benefits (60) (78) (LG&E) Although LG&E does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE. LG&E is also allocated costs of defined benefits plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to LG&E from LKS. These allocations are based on LG&E's participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of LG&E are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to LG&E resulted in assets/(liabilities) at December 31 as follows: 2022 2021 Pension $ 41 $ 85 Other postretirement benefits (41) (51) (KU) Although KU does not directly sponsor any defined benefit plans, it is allocated a portion of the funded status and costs of plans sponsored by LKE. KU is also allocated costs of defined benefit plans from LKS for defined benefit plans sponsored by LKE. See Note 15 for additional information on costs allocated to KU from LKS. These allocations are based on KU's participation in those plans, which management believes are reasonable. The actuarially determined obligations of current active employees and retired employees of KU are used as a basis to allocate total plan activity, including active and retiree costs and obligations. Allocations to KU resulted in assets/(liabilities) at December 31 as follows. 2022 2021 Pension $ 44 $ 75 Other postretirement benefits (9) (6) Plan Assets - Pension Plans (PPL) PPL's primary legacy pension plan and the pension plan sponsored by LKE are invested in the PPL Services Corporation Master Trust (the Master Trust) that also includes 401(h) accounts that are restricted for certain other postretirement benefit obligations of PPL and LKE. The investment strategy for the Master Trust is to achieve a risk-adjusted return on a mix of assets that, in combination with PPL's funding policy, will ensure that sufficient assets are available to provide long-term growth and liquidity for benefit payments, while also managing the duration of the assets to complement the duration of the liabilities. The Master Trust benefits from a wide diversification of asset types, investment fund strategies and external investment fund managers, and therefore has no significant concentration of risk. The investment policy of the Master Trust outlines investment objectives and defines the responsibilities of the EBPB, external investment managers, investment advisor and trustee and custodian. The investment policy is reviewed annually by PPL's Board of Directors. The EBPB created a risk management framework around the trust assets and pension liabilities. This framework considers the trust assets as being composed of three sub-portfolios: growth, immunizing and liquidity portfolios. The growth portfolio is comprised of investments that generate a return at a reasonable risk, including equity securities, certain debt securities and alternative investments. The immunizing portfolio consists of debt securities, generally with long durations, and derivative positions. The immunizing portfolio is designed to offset a portion of the change in the pension liabilities due to changes in interest rates. The liquidity portfolio consists primarily of cash and cash equivalents. Target allocation ranges have been developed for each portfolio based on input from external consultants with a goal of limiting funded status volatility. The EBPB monitors the investments in each portfolio and seeks to obtain a target portfolio that emphasizes reduction of risk of loss from market volatility. In pursuing that goal, the EBPB establishes revised guidelines from time to time. EBPB investment guidelines as of the end of 2022 are presented below. The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2022 2022 2021 Target Asset Growth Portfolio 55 % 55 % 55 % Equity securities 31 % 32 % Debt securities (a) 13 % 13 % Alternative investments 11 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 33 % 35 % Derivatives (b) 10 % 8 % Liquidity Portfolio 2 % 2 % 2 % Total 100 % 100 % 100 % (a) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes. (b) Includes posted collateral to support derivative instruments subject to counterparty risk. (PPL) The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2022 December 31, 2021 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 306 $ 306 $ — $ — $ 266 $ 266 $ — $ — Equity securities: U.S. Equity 34 34 — — 41 41 — — U.S. Equity fund measured at NAV (a) 574 — — — 754 — — — International equity fund at NAV (a) 403 — — — 511 — — — Commingled debt measured at NAV (a) 526 — — — 677 — — — Debt securities: U.S. Treasury and U.S. government sponsored 153 153 — — 281 280 1 — Corporate 834 — 818 16 1,039 — 1,019 20 Other 14 — 14 — 14 — 14 — Alternative investments: Real estate measured at NAV (a) 60 — — — 69 — — — Private equity measured at NAV (a) 96 — — — 92 — — — Private credit partnerships measured at NAV (a) 6 — — — 2 — — — Hedge funds measured at NAV (a) 194 — — — 236 — — — Derivatives 8 — 8 — 35 — 35 — PPL Services Corporation Master Trust assets, at 3,208 $ 493 $ 840 $ 16 4,017 $ 587 $ 1,069 $ 20 Receivables and payables, net (b) 67 25 401(h) accounts restricted for other (126) (155) Total PPL Services Corporation Master Trust $ 3,149 $ 3,887 (a) In accordance with accounting guidance, certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received. A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2022 is as follows: Corporate Balance at beginning of period $ 20 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 2 Purchases, sales and settlements (4) Balance at end of period $ 16 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2021 is as follows: Corporate Balance at beginning of period $ 15 Purchases, sales and settlements 5 Balance at end of period $ 20 The fair value measurements of cash and cash equivalents are based on the amounts on deposit. The market approach is used to measure fair value of equity securities. The fair value measurements of equity securities (excluding commingled funds), which are generally classified as Level 1, are based on quoted prices in active markets. These securities represent actively and passively managed investments that are managed against various equity indices. Investments in commingled equity and debt funds are categorized as equity securities. Investments in commingled equity funds include funds that invest in U.S. and international equity securities. Investments in commingled debt funds include funds that invest in a diversified portfolio of emerging market debt obligations, as well as funds that invest in investment grade long-duration fixed-income securities. The fair value measurements of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. The fair value of debt securities is generally measured using a market approach, including the use of pricing models, which incorporate observable inputs. Common inputs include benchmark yields, relevant trade data, broker/dealer bid/ask prices, benchmark securities and credit valuation adjustments. When necessary, the fair value of debt securities is measured using the income approach, which incorporates similar observable inputs as well as payment data, future predicted cash flows, collateral performance and new issue data. For the Master Trust, these securities represent investments in securities issued by U.S. Treasury and U.S. government sponsored agencies; investments securitized by residential mortgages, auto loans, credit cards and other pooled loans; investments in investment grade and non-investment grade bonds issued by U.S. companies across several industries; investments in debt securities issued by foreign governments and corporations. Investments in real estate represent an investment in a partnership whose purpose is to manage investments in core U.S. real estate properties diversified geographically and across major property types (e.g., office, industrial, retail, etc.). The strategy is focused on properties with high occupancy rates with quality tenants. This results in a focus on high income and stable cash flows with appreciation being a secondary factor. Core real estate generally has a lower degree of leverage when compared with more speculative real estate investing strategies. The partnership has limitations on the amounts that may be redeemed based on available cash to fund redemptions. Additionally, the general partner may decline to accept redemptions when necessary to avoid adverse consequences for the partnership, including legal and tax implications, among others. The fair value of the investment is based upon a partnership unit value. Investments in private equity represent interests in partnerships in multiple early-stage venture capital funds and private equity fund of funds that use a number of diverse investment strategies. The partnerships have limited lives of at least 10 years, after which liquidating distributions will be received. Prior to the end of each partnership's life, the investment cannot be redeemed with the partnership; however, the interest may be sold to other parties, subject to the general partner's approval. Fair value is based on an ownership interest in partners' capital to which a proportionate share of net assets is attributed. Investments in private credit represent pools of actively managed loans that span capital structure and borrower type. Strategies carry different types and levels of risk. Returns from those strategies will vary in terms of yield, fees generated, loan loss rates and the pace of principal repayment. Investments have limited lives of approximately 2-8 years. The investment cannot be redeemed with the general partner; however, the interest may be sold to other parties, subject to the general partner’s approval. Fair value is based on an ownership interest in partners’ capital to which a proportionate share of net assets is attributed. At December 31, 2022, the Master Trust had unfunded commitments of $116 million that may be required during the lives of the partnerships. Investments in hedge funds represent investments in a fund of hedge funds. Hedge funds seek a return utilizing a number of diverse investment strategies. The strategies, when combined aim to reduce volatility and risk while attempting to deliver positive returns under most market conditions. Major investment strategies for the fund of hedge funds include long/short equity, tactical trading, event driven, and relative value. Shares may be redeemed with 45 days prior written notice. The fund is subject to short term lockups and other restrictions. The fair value for the fund has been estimated using the net asset value per share. The fair value measurements of derivative instruments utilize various inputs that include quoted prices for similar contracts or market-corroborated inputs. In certain instances, these instruments may be valued using models, including standard option valuation models and standard industry models. These securities primarily represent investments in treasury futures, total return swaps, interest rate swaps and swaptions (the option to enter into an interest rate swap), which are valued based on quoted prices, changes in the value of the underlying exposure or on the swap details, such as swap curves, notional amount, index and term of index, reset frequency, volatility and payer/receiver credit ratings. Plan Assets - Other Postretirement Benefit Plans The investment strategy with respect to other postretirement benefit obligations is to fund VEBA trusts and/or 401(h) accounts with voluntary contributions and to invest in a tax efficient manner. Excluding the 401(h) accounts included in the Master Trust, other postretirement benefit plans are invested in a mix of assets for long-term growth with an objective of earning returns that provide liquidity as required for benefit payments. These plans benefit from diversification of asset types, investment fund strategies and investment fund managers and, therefore, have no significant concentration of risk. Equity securities include investments in domestic large-cap commingled funds. Ownership interests in commingled funds that invest entirely in debt securities are classified as equity securities, but treated as debt securities for asset allocation and target allocation purposes. Ownership interests in money market funds are treated as cash and cash equivalents for asset allocation and target allocation purposes. The asset allocation for the PPL VEBA trusts and the target allocation, by asset class, at December 31 are detailed below. Percentage of plan assets Target Asset 2022 2021 2022 Asset Class Equity securities 45 % 45 % 44 % Debt securities (a) 48 % 52 % 50 % Cash and cash equivalents (b) 7 % 3 % 6 % Total 100 % 100 % 100 % (a) Includes commingled debt funds and debt securities. (b) Includes money market funds. The fair value of assets in the other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2022 December 31, 2021 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 19 $ 19 $ — $ — $ 6 $ 6 $ — $ — Equity securities: Large-cap equity fund measure at NAV (a) 71 — — — 96 — — — Commingled debt fund measured at NAV (a) 77 — — — 75 — — — Global equity exchange-traded fund 61 61 — — — — — — Long-term bond exchange-traded fund 65 65 — — — — — — Debt securities: Corporate bonds — — — — 38 — 38 — Total VEBA trust assets, at fair value 293 $ 145 $ — $ — 215 $ 6 $ 38 $ — Receivables and payables, net (b) (2) (3) 401(h) account assets 126 155 Total other postretirement benefit plan assets $ 417 $ 367 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received. Investments in money market funds represent investments in funds that invest primarily in a diversified portfolio of investment grade money market instruments, including, but not limited to, commercial paper, notes, repurchase agreements and other evidences of indebtedness with a maturity not exceeding 13 months from the date of purchase. The primary objective of the fund is a level of current income consistent with stability of principal and liquidity. Redemptions can be made daily on this fund. Investments in large-cap equity securities represent investments in a passively managed equity index fund that invests in securities and a combination of other collective funds. Fair value measurements are not obtained from a quoted price in an active market but are based on firm quotes of net asset values per share as provided by the trustee of the fund. Redemptions can be made daily on this fund. Investments in commingled debt securities represent investments in a fund that invests in a diversified portfolio of investment grade long-duration fixed income securities. Redemptions can be made daily on these funds. Investments in global equity exchange-traded fund represents a passively-managed pooled investment vehicle that invests in developed market equities and is designed to track the performance of the MSCI World Index. Fair value measurements can be obtained from a quoted price on the exchange. Redemptions can be made daily on this fund. Investments in long-term bond exchange-traded fund represents a passively-managed pooled investment vehicle that is designed to track the performance of the Bloomberg U.S. Long Government/Credit Float Adjusted Index, which includes all medium and larger issues of U.S. Government, investment-grade corporate and investment-grade international dollar-denominated bonds that have maturities of greater than 10 years. Fair value measurements can be obtained from a quoted price on the exchange. Redemptions can be made daily on this fund. Investments in corporate bonds represent investment in a diversified portfolio of investment grade long-duration fixed income securities. The fair value of debt securities are generally based on evaluations that reflect observable market information, such as actual trade information for identical securities or for similar securities, adjusted for observable differences. Expected Cash Flows - Defined Benefit Plans (PPL) PPL does not plan to contribute to its pension plans in 2023, as PPL's defined benefit pension plans have the option to utilize available prior year credit balances to meet current and future contribution requirements. PPL sponsors various non-qualified supplemental pension plans for which no assets are segregated from corporate assets. PPL expects to make approximately $10 million of benefit payments under these plans in 2023. PPL is not required to make contributions to its other postretirement benefit plans but has historically funded these plans in amounts equal to the postretirement benefit costs recognized. Continuation of this past practice would cause PPL to contribute $27 million to its other postretirement benefit plans in 2023. The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by PPL. Other Postretirement Pension Benefit Expected 2023 $ 282 $ 51 $ — 2024 281 50 — 2025 283 49 — 2026 280 48 — 2027 275 48 — 2028-2032 1,327 225 1 Savings Plans (All Registrants) Substantially, all employees of PPL's subsidiaries are eligible to participate in deferred savings plans (401(k)s). Employer contributions to the plans were: 2022 2021 2020 PPL $ 36 $ 29 $ 29 PPL Electric 6 5 6 LG&E 7 7 6 KU 5 5 5

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2022
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2022 and 2021, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2022 Trimble County Unit 1 75.00 % $ 455 $ 94 $ 1 Trimble County Unit 2 75.00 % 1,372 276 148 December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 LG&E December 31, 2022 E.W. Brown Units 6-7 38.00 % $ 53 $ 25 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 27 — Trimble County Unit 1 75.00 % 455 94 1 Trimble County Unit 2 14.25 % 384 66 78 Trimble County Units 5-6 29.00 % 36 16 — Trimble County Units 7-10 37.00 % 81 36 — Cane Run Unit 7 22.00 % 126 21 2 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2022 E.W. Brown Units 6-7 62.00 % $ 87 $ 42 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 23 — Trimble County Unit 2 60.75 % 987 210 70 Trimble County Units 5-6 71.00 % 84 38 — Trimble County Units 7-10 63.00 % 133 61 — Cane Run Unit 7 78.00 % 446 77 6 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2022 and 2021, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2022 Trimble County Unit 1 75.00 % $ 455 $ 94 $ 1 Trimble County Unit 2 75.00 % 1,372 276 148 December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 LG&E December 31, 2022 E.W. Brown Units 6-7 38.00 % $ 53 $ 25 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 27 — Trimble County Unit 1 75.00 % 455 94 1 Trimble County Unit 2 14.25 % 384 66 78 Trimble County Units 5-6 29.00 % 36 16 — Trimble County Units 7-10 37.00 % 81 36 — Cane Run Unit 7 22.00 % 126 21 2 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2022 E.W. Brown Units 6-7 62.00 % $ 87 $ 42 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 23 — Trimble County Unit 2 60.75 % 987 210 70 Trimble County Units 5-6 71.00 % 84 38 — Trimble County Units 7-10 63.00 % 133 61 — Cane Run Unit 7 78.00 % 446 77 6 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2022 and 2021, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2022 Trimble County Unit 1 75.00 % $ 455 $ 94 $ 1 Trimble County Unit 2 75.00 % 1,372 276 148 December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 LG&E December 31, 2022 E.W. Brown Units 6-7 38.00 % $ 53 $ 25 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 27 — Trimble County Unit 1 75.00 % 455 94 1 Trimble County Unit 2 14.25 % 384 66 78 Trimble County Units 5-6 29.00 % 36 16 — Trimble County Units 7-10 37.00 % 81 36 — Cane Run Unit 7 22.00 % 126 21 2 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2022 E.W. Brown Units 6-7 62.00 % $ 87 $ 42 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 23 — Trimble County Unit 2 60.75 % 987 210 70 Trimble County Units 5-6 71.00 % 84 38 — Trimble County Units 7-10 63.00 % 133 61 — Cane Run Unit 7 78.00 % 446 77 6 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — — Each subsidiary owning these interests provides its own funding for its share of the facility. Each receives a portion of the total output of the generating plants equal to its percentage ownership. The share of fuel and other operating costs associated with the plants is included in the corresponding operating expenses on the Statements of Income.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2022
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. Support Costs (PPL Electric, LG&E and KU) PPL Services and LKS provide and, prior to its merger into PPL Services on December 31, 2021, PPL EU Services provided the Registrants and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2022 2021 2020 PPL Electric from PPL Services $ 241 $ 54 $ 50 PPL Electric from PPL EU Services — 222 176 LG&E from LKS 153 169 170 LG&E from PPL Services 13 3 2 KU from LKS 171 179 180 KU from PPL Services 14 3 2 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2022, PPL Energy Funding had no borrowings outstanding. At December 31, 2021, $499 million was outstanding. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. CEP Reserves maintains a $500 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2022 and 2021, CEP Reserves had no borrowings outstanding. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. At December 31, 2022, LG&E's money pool unused capacity was $250 million. At December 31, 2022, LG&E had no borrowings outstanding from KU and/or LKE. At December 31, 2021, LG&E had borrowings of $324 million outstanding from LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. At December 31, 2022, KU's money pool unused capacity was $250 million. At December 31, 2022, KU had no borrowings outstanding from LG&E and/or LKE. At December 31, 2021, KU had borrowings of $294 million outstanding from LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. VEBA Funds Receivable (PPL Electric) In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on the Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022. The intercompany receivable balance associated with these funds was $11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and $1 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. Support Costs (PPL Electric, LG&E and KU) PPL Services and LKS provide and, prior to its merger into PPL Services on December 31, 2021, PPL EU Services provided the Registrants and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2022 2021 2020 PPL Electric from PPL Services $ 241 $ 54 $ 50 PPL Electric from PPL EU Services — 222 176 LG&E from LKS 153 169 170 LG&E from PPL Services 13 3 2 KU from LKS 171 179 180 KU from PPL Services 14 3 2 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2022, PPL Energy Funding had no borrowings outstanding. At December 31, 2021, $499 million was outstanding. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. CEP Reserves maintains a $500 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2022 and 2021, CEP Reserves had no borrowings outstanding. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. At December 31, 2022, LG&E's money pool unused capacity was $250 million. At December 31, 2022, LG&E had no borrowings outstanding from KU and/or LKE. At December 31, 2021, LG&E had borrowings of $324 million outstanding from LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. At December 31, 2022, KU's money pool unused capacity was $250 million. At December 31, 2022, KU had no borrowings outstanding from LG&E and/or LKE. At December 31, 2021, KU had borrowings of $294 million outstanding from LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. VEBA Funds Receivable (PPL Electric) In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on the Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022. The intercompany receivable balance associated with these funds was $11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and $1 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	Wholesale Sales and Purchases (LG&E and KU) LG&E and KU jointly dispatch their generation units with the lowest cost generation used to serve their retail customers. When LG&E has excess generation capacity after serving its own retail customers and its generation cost is lower than that of KU, KU purchases electricity from LG&E and vice versa. These transactions are reflected in the Statements of Income as "Electric revenue from affiliate" and "Energy purchases from affiliate" and are recorded at a price equal to the seller's fuel cost plus any split savings. Savings realized from such intercompany transactions are shared equally between both companies. The volume of energy each company has to sell to the other is dependent on its retail customers' needs and its available generation. Support Costs (PPL Electric, LG&E and KU) PPL Services and LKS provide and, prior to its merger into PPL Services on December 31, 2021, PPL EU Services provided the Registrants and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and PPL EU Services use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services may also use a ratio of overall direct and indirect costs or a weighted average cost ratio. LKS bases its indirect allocations on the subsidiaries' number of employees, total assets, revenues, number of customers and/or other statistical information. PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2022 2021 2020 PPL Electric from PPL Services $ 241 $ 54 $ 50 PPL Electric from PPL EU Services — 222 176 LG&E from LKS 153 169 170 LG&E from PPL Services 13 3 2 KU from LKS 171 179 180 KU from PPL Services 14 3 2 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) PPL Energy Funding maintains a $1,200 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2022, PPL Energy Funding had no borrowings outstanding. At December 31, 2021, $499 million was outstanding. This balance is reflected in "Notes receivable from affiliate" on the PPL Electric balance sheet. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. CEP Reserves maintains a $500 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2022 and 2021, CEP Reserves had no borrowings outstanding. The interest rates on borrowings are equal to one-month LIBOR plus a spread. Interest income is reflected in "Interest Income from Affiliate" on the Income Statements. (LG&E) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. At December 31, 2022, LG&E's money pool unused capacity was $250 million. At December 31, 2022, LG&E had no borrowings outstanding from KU and/or LKE. At December 31, 2021, LG&E had borrowings of $324 million outstanding from LKE. These balances are reflected in "Notes payable to affiliates" on the LG&E Balance Sheets. (KU) KU participates in an intercompany money pool agreement whereby LKE and/or LG&E make available to KU funds up to the difference between KU's FERC borrowing limit and KU's commercial paper limit at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on LIBOR. At December 31, 2022, KU's money pool unused capacity was $250 million. At December 31, 2022, KU had no borrowings outstanding from LG&E and/or LKE. At December 31, 2021, KU had borrowings of $294 million outstanding from LKE. These balances are reflected in "Notes payable to affiliates" on the KU Balance Sheets. VEBA Funds Receivable (PPL Electric) In May 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on the Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022. The intercompany receivable balance associated with these funds was $11 million as of December 31, 2021, of which $10 million was reflected in "Accounts receivable from affiliates" and $1 million was reflected in "Other noncurrent assets" on the Balance Sheets. Other (PPL Electric, LG&E and KU) See Note 1 for discussions regarding the intercompany tax sharing agreement (for PPL Electric, LG&E and KU) and intercompany allocations of stock-based compensation expense (for PPL Electric). For PPL Electric, LG&E and KU, see Note 12 for discussions regarding intercompany allocations associated with defined benefits.

Other Income (Expense) - net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2022
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2022 2021 2020 Defined benefit plans - non-service credits (Note 12) $ 47 $ 21 $ (2) Interest income 4 12 9 AFUDC - equity component 22 18 20 Charitable contributions (14) (14) (3) Miscellaneous (5) (22) (22) Other Income (Expense) - net $ 54 $ 15 $ 2 (PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2022 2021 2020 Defined benefit plans - non-service credits (Note 12) $ 15 $ 9 $ 4 Interest income 3 — 2 AFUDC - equity component 16 18 19 Charitable contributions (3) (3) (3) Miscellaneous (1) (3) (4) Other Income (Expense) - net $ 30 $ 21 $ 18

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements and Credit Concentration	(All Registrants) Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models), and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. See Note 1 for information on the levels in the fair value hierarchy. Recurring Fair Value Measurements The assets and liabilities measured at fair value were: December 31, 2022 December 31, 2021 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 356 $ 356 $ — $ — $ 3,571 $ 3,571 $ — $ — Restricted cash and cash equivalents (a) 1 1 — — 1 1 — — Total Cash, Cash Equivalents and Restricted Cash (b) 357 357 — — 3,572 3,572 — — Special use funds (a): Money market fund 1 1 — — 2 2 — — Commingled debt fund measured at NAV (c) 13 — — — 22 — — — Commingled equity fund measured at NAV (c) 11 — — — 21 — — — Total special use funds 25 1 — — 45 2 — — Price risk management assets (d): Gas contracts 25 — 25 — — — — — Total assets $ 407 $ 358 $ 25 $ — $ 3,617 $ 3,574 $ — $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 7 $ — $ 7 $ — $ 18 $ — $ 18 $ — Gas contracts 66 — 10 56 — — — — Total price risk management liabilities $ 73 $ — $ 17 $ 56 $ 18 $ — $ 18 $ — December 31, 2022 December 31, 2021 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Electric Assets Cash and cash equivalents $ 25 $ 25 $ — $ — $ 21 $ 21 $ — $ — Total assets $ 25 $ 25 $ — $ — $ 21 $ 21 $ — $ — LG&E Assets Cash and cash equivalents $ 93 $ 93 $ — $ — $ 9 $ 9 $ — $ — Total assets $ 93 $ 93 $ — $ — $ 9 $ 9 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 7 $ — $ 7 $ — $ 18 $ — $ 18 $ — Total price risk management liabilities $ 7 $ — $ 7 $ — $ 18 $ — $ 18 $ — KU Assets Cash and cash equivalents $ 21 $ 21 $ — $ — $ 13 $ 13 $ — $ — Total assets $ 21 $ 21 $ — $ — $ 13 $ 13 $ — $ — (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows. (c) In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (d) Current portion is included in "Other current liabilities" and noncurrent portion is included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. A reconciliation of net assets and liabilities classified as Level 3 for the year ended December 31 is as follows: Gas Contracts 2022 Balance at beginning of period $ — Total realized/unrealized gains (losses): Included in regulatory assets 56 Balance at end of period $ 56 Special Use Funds (PPL) The special use funds are investments restricted for paying active union employee medical costs. In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. The funds are invested primarily in commingled debt and equity funds measured at NAV and are classified as investments in equity securities. Changes in the fair value of the funds are recorded to the Statements of Income. Price Risk Management Assets/Liabilities Interest Rate Swaps ( PPL, LG&E and KU) To manage interest rate risk, PPL, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., LIBOR, SOFR, and government security rates), as well as inputs that may not be observable, such as credit valuation adjustments. In certain cases, market information cannot practicably be obtained to value credit risk and therefore internal models are relied upon. These models use projected probabilities of default and estimated recovery rates based on historical observances. When the credit valuation adjustment is significant to the overall valuation, the contracts are classified as Level 3. Gas Contracts (PPL) To manage gas commodity price risk associated with natural gas purchases, RIE utilizes over-the-counter (OTC) gas swaps contracts with pricing inputs obtained from the New York Mercantile Exchange (NYMEX) and the Intercontinental Exchange (ICE), except in cases where the ICE publishes seasonal averages or where there were no transactions within the last seven days. RIE may utilize discounting based on quoted interest rate curves, including consideration of non-performance risk, and may include a liquidity reserve calculated based on bid/ask spread. Substantially all of these price curves are observable in the marketplace throughout at least 95% of the remaining contractual quantity, or they could be constructed from market observable curves with correlation coefficients of 95% or higher. These contracts are classified as Level 2. RIE also utilizes gas option and purchase and capacity transactions, which are valued based on internally developed models. Industry-standard valuation techniques, such as the Black-Scholes pricing model, are used for valuing such instruments. For valuations that include both observable and unobservable inputs, if the unobservable input is determined to be significant to the overall inputs, the entire valuation is classified as Level 3. This includes derivative instruments valued using indicative price quotations whose contract tenure extends into unobservable periods. In instances where observable data is unavailable, consideration is given to the assumptions that market participants would use in valuing the asset or liability. This includes assumptions about market risks such as liquidity, volatility, and contract duration. Such instruments are classified as Level 3 as the model inputs generally are not observable. RIE considers non-performance risk and liquidity risk in the valuation of derivative instruments classified as Level 2 and Level 3. The significant unobservable inputs used in the fair value measurement of the gas derivative instruments are implied volatility and gas forward curves. A relative change in commodity price at various locations underlying the open positions can result in significantly different fair value estimates. Financial Instruments Not Recorded at Fair Value (All Registrants) The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement. December 31, 2022 December 31, 2021 Carrying Fair Value Carrying Fair Value PPL $ 13,243 $ 12,239 $ 11,140 $ 12,955 PPL Electric 4,486 4,259 4,484 5,272 LG&E 2,307 2,128 2,006 2,363 KU 2,920 2,616 2,618 3,120 (a) Amounts are net of debt issuance costs. The carrying amounts of other current financial instruments (except for long-term debt due within one year) approximate their fair values because of their short-term nature.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	18. Derivative Instruments and Hedging Activities Risk Management Objectives (All Registrants) PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The Risk Management Committee, comprised of senior management and chaired by the Senior Director-Risk Management, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program. Market Risk Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices and interest rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected. The following summarizes the market risks that affect PPL and its subsidiaries. Interest Rate Risk • PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates, when appropriate, in connection with future debt issuance. • PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated utilities due to the recovery methods in place. Commodity Price Risk PPL is exposed to commodity price risk through its subsidiaries as described below. • PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is mitigated through its PAPUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers. • LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply costs. These mechanisms generally provide for timely recovery of market price fluctuations associated with these costs. • RIE utilizes derivative instruments pursuant to its RIPUC-approved plan to manage commodity price risk associated with its natural gas purchases. RIE's commodity price risk management strategy is to reduce fluctuations in firm gas sales prices to its customers. RIE's costs associated with derivatives instruments are recoverable through its RIPUC- approved cost recovery mechanisms. RIE is required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices. Volumetric Risk Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below: • PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases. • RIE is exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates. Equity Securities Price Risk • PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place. • PPL is exposed to equity securities price risk from future stock sales and/or purchases. Credit Risk Credit risk is the potential loss that may be incurred due to a counterparty's non-performance. PPL is exposed to credit risk from "in-the-money" transactions with counterparties, as well as additional credit risk through certain of its subsidiaries, as discussed below. In the event a supplier of PPL, PPL Electric, LG&E or KU defaults on its contractual obligation, those Registrants would need to seek replacement power or replacement fuel in the market. In general, subject to regulatory review or other processes, appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit. Master Netting Arrangements (PPL, LG&E and KU) Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. PPL had $4 million cash collateral posted under master netting arrangements at December 31, 2022 and no cash collateral posted at December 31, 2021. PPL had no obligation to return cash collateral under master netting arrangements at December 31, 2022 and 2021. LG&E and KU had no cash collateral posted or obligation to return cash collateral under master netting arrangements at December 31, 2022 and 2021. See "Offsetting Derivative Instruments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements. Interest Rate Risk (All Registrants) PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate case. Cash Flow Hedges (PPL) Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL had no such contracts at December 31, 2022. Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring. For 2022, 2021 and 2020, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At December 31, 2022, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded. Economic Activity (PPL and LG&E) LG&E enters into interest rate swap contracts that economically hedge interest payments. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. At December 31, 2022, LG&E held contracts with a notional amount of $64 million that mature in 2033. Commodity Price Risk (PPL) Economic Activity RIE enters into financial and physical derivative contracts that economically hedge natural gas purchases. Realized gains and losses from the derivatives are recoverable through regulated rates, therefore subsequent changes in fair value are included in regulatory assets or liabilities until they are realized as purchased gas. Realized gains and losses are recognized in "Energy Purchases" on the Statements of Income upon settlement of the contracts. At December 31, 2022, RIE held contracts with a notional amount of $15 million that mature in 2024. Accounting and Reporting (All Registrants) All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless the NPNS is elected. NPNS contracts include certain full-requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps that are recognized as regulatory assets or regulatory liabilities. See Note 7 for amounts recorded in regulatory assets and regulatory liabilities at December 31, 2022 and 2021. See Note 1 for additional information on accounting policies related to derivative instruments. (PPL) The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets: December 31, 2022 December 31, 2021 Derivatives designated as Derivatives not designated Derivatives designated as Derivatives not designated Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ — $ — $ — $ 1 $ — $ — $ — $ 1 Gas contracts — — 20 62 — — — — Total current — — 20 63 — — — 1 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 6 — — — 17 Gas contracts — — 5 4 — — — — Total noncurrent — — 5 10 — — — 17 Total derivatives $ — $ — $ 25 $ 73 $ — $ — $ — $ 18 (a) Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (b) Excludes accrued interest, if applicable. The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities: Derivative Derivative Gain Location of Gain (Loss) Gain (Loss) Reclassified 2022 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) 2021 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ 11 Income (Loss) from Discontinued operations (net of taxes) (2) Cross-currency swaps (50) Income (Loss) from Discontinued operations (net of taxes) (39) Total $ (50) $ (30) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 2020 Cash Flow Hedges: Interest rate swaps $ (9) Interest Expense $ (8) Income(Loss) from Discontinued operations(net of taxes) (2) Cross-currency swaps (15) Income (Loss) from Discontinued operations (net of taxes) (22) Total $ (24) $ (32) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 Derivatives Not Designated as Location of Gain (Loss) Recognized in 2022 2021 2020 Foreign currency contracts Income (Loss) from Discontinued Operations (net of taxes) $ — $ (266) $ (98) Interest rate swaps Interest Expense (2) (2) (5) Gas contracts Energy Purchases 41 — — Total $ 39 $ (268) $ (103) Derivatives Not Designated as Location of Gain (Loss) Recognized as 2022 2021 2020 Gas contracts Regulatory assets - current $ 39 $ — $ — Interest rate swaps Regulatory assets - noncurrent 11 5 (2) Total $ 50 $ 5 $ (2) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2022: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 513 $ 54 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (3) — Cross-currency swaps: Hedged items — — Amount of gain (loss) reclassified from AOCI to income — — The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2021: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 918 $ (1,498) The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income 11 (2) Cross-currency swaps: Hedged items — 39 Amount of gain (loss) reclassified from AOCI to income — (39) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2020: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 634 $ 829 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (8) (2) Cross-currency swaps: Hedged items — 22 Amount of gain (loss) reclassified from AOCI to income — (22) (LG&E) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments: December 31, 2022 December 31, 2021 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 1 Total current — 1 — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 6 — 17 Total noncurrent — 6 — 17 Total derivatives $ — $ 7 $ — $ 18 The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets: Derivative Instruments Location of Gain (Loss) 2022 2021 2020 Interest rate swaps Interest Expense $ (2) $ (2) $ (5) Derivative Instruments Location of Gain (Loss) 2022 2021 2020 Interest rate swaps Regulatory assets - noncurrent $ 11 $ 5 $ (2) (PPL, LG&E and KU) Offsetting Derivative Instruments PPL, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation. PPL, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7 December 31, 2021 Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18 Credit Risk-Related Contingent Features Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions. Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts disclosed below represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features. (PPL) At December 31, 2022, there were an insignificant amount of derivative contracts in a net liability position that contain credit risk-related contingent features, collateral posted on those positions and the related effect of a decrease in credit ratings below investment grade.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2022
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets	19. Goodwill and Other Intangible Assets Goodwill (PPL) The changes in the carrying amount of goodwill by segment were: Kentucky Rhode Island Regulated Corporate and Total 2022 2021 2022 2021 2022 2021 2022 2021 Balance at beginning of period (a) $ 662 $ 662 $ — $ — $ 53 $ 53 $ 715 $ 715 Goodwill recognized during the period (b) — — 725 — 861 — 1,586 — Sale of Safari Holdings (c) — — — — (53) — (53) — Total $ 662 $ 662 $ 725 $ — $ 861 $ 53 $ 2,248 $ 715 (a) There were no accumulated impairment losses related to goodwill. (b) Recognized as a result of the acquisition of RIE. See Note 9 for additional information. (c) See Note 9 for additional information. Other Intangible Assets (PPL) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 125 $ 99 $ 125 $ 90 Renewable Energy Credits 14 — — — Land rights and easements 407 138 406 135 Licenses and other 2 1 20 6 Total subject to amortization 548 238 551 231 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Other — — 6 — Total not subject to amortization due to indefinite life 17 — 23 — Total $ 565 $ 238 $ 574 $ 231 (a) Gross carrying amount in 2022 and 2021 includes the fair value at the acquisition date of the OVEC power purchase contract with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL. Current intangible assets are included in "Other current assets" and long-term intangible assets are included in "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2022 2021 2020 Intangible assets with no regulatory offset $ 5 $ 9 $ 7 Intangible assets with regulatory offset 9 8 8 Total $ 14 $ 17 $ 15 Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with no regulatory offset $ 5 $ 5 $ 5 $ 4 $ 4 Intangible assets with regulatory offset 9 8 8 2 — Total $ 14 $ 13 $ 13 $ 6 $ 4 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 385 $ 134 $ 382 $ 130 Licenses and other 2 1 2 1 Total subject to amortization 387 135 384 131 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 404 $ 135 $ 401 $ 131 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was as follows: 2022 2021 2020 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4 (LG&E) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 68 86 62 Total subject to amortization $ 93 $ 69 $ 93 $ 63 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2022 2021 2020 Intangible assets with regulatory offset $ 6 $ 5 $ 6 Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with regulatory offset $ 6 $ 6 $ 6 $ 1 $ — (KU) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 16 $ 3 $ 16 $ 4 OVEC power purchase agreement (a) 39 31 39 28 Total subject to amortization $ 55 $ 34 $ 55 $ 32 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information. Long-term intangible assets are presented as "Other intangibles" on the Balance Sheets. Amortization expense was as follows: 2022 2021 2020 Intangible assets with no regulatory offset $ — $ 1 $ — Intangible assets with regulatory offset 3 3 2 Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with regulatory offset $ 3 $ 2 $ 2 $ 1 $ —

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(PPL and PPL Electric) PPL Electric has identified legal retirement obligations for the retirement of certain transmission assets that could not be reasonably estimated due to indeterminable settlement dates. These assets are located on rights-of-way that allow the grantor to require PPL Electric to relocate or remove the assets. Since this option is at the discretion of the grantor of the right-of-way, PPL Electric is unable to determine when these events may occur. (PPL, LG&E and KU) PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 14 for information on the CCR rule. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2022 2021 2022 2021 2022 2021 ARO at beginning of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115 Acquisition of RIE (a) 10 — — — — — Accretion 6 16 3 5 3 11 Obligations incurred 2 — 2 — — — Changes in estimated timing or cost 15 56 12 40 4 16 Obligations settled (45) (65) (15) (28) (30) (37) ARO at end of period $ 177 $ 189 $ 86 $ 84 $ 82 $ 105

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	(PPL) The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans Foreign Unrealized gains (losses) on Equity Prior Actuarial Total PPL December 31, 2019 $ (1,425) $ (5) $ — $ (18) $ (2,910) $ (4,358) Amounts arising during the year 267 (19) — (1) (341) (94) Reclassifications from AOCI — 24 — 3 205 232 Net OCI during the year 267 5 — 2 (136) 138 December 31, 2020 $ (1,158) $ — $ — $ (16) $ (3,046) $ (4,220) Amounts arising during the year 372 (39) — — (1) 332 Reclassifications from AOCI — 25 — 2 126 153 Reclassifications from AOCI due to the sale of the U.K. utility business (Note 9) 786 15 — 8 2,769 3,578 Net OCI during the year 1,158 1 — 10 2,894 4,063 December 31, 2021 $ — $ 1 $ — $ (6) $ (152) $ (157) Defined benefit plans Foreign Unrealized gains (losses) on Equity Prior Actuarial Total Amounts arising during the year — — 2 (1) 11 12 Reclassifications from AOCI — 2 — 2 17 21 Net OCI during the year — 2 2 1 28 33 December 31, 2022 $ — $ 3 $ 2 $ (5) $ (124) $ (124) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2022, 2021 and 2020. The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 12 for additional information. PPL Details about AOCI 2022 2021 2020 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (3) $ 11 $ (8) Interest Expense — (2) (2) Income (Loss) from Discontinued Operations (net of income taxes) Cross-currency swaps — (39) (22) Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax (3) (30) (32) Income Taxes 1 5 8 Total After-tax (2) (25) (24) Defined benefit plans Prior service costs (3) (3) (4) Net actuarial loss (24) (159) (256) Total Pre-tax (27) (162) (260) Income Taxes 8 34 52 Total After-tax (19) (128) (208) Sale of the U.K. utility business (Note 9) Foreign currency translation adjustments — (646) — Income (Loss) from Discontinued Operations (net of income taxes) Qualifying derivatives — (15) — Income (Loss) from Discontinued Operations (net of income taxes) Defined benefit plans — (3,577) — Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax — (4,238) — Income Taxes — 660 — Total After-tax — (3,578) — Total reclassifications during the year $ (21) $ (3,731) $ (232)

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2022
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	Business and Consolidation (PPL) PPL is a utility holding company that, through its regulated subsidiaries, is primarily engaged in: 1) the generation, transmission, distribution and sale of electricity and the distribution and sale of natural gas, primarily in Kentucky; 2) the transmission, distribution and sale of electricity in Pennsylvania; and 3) the transmission, distribution and sale of electricity and the distribution and sale of natural gas in Rhode Island. Headquartered in Allentown, PA, PPL's principal subsidiaries are LG&E, KU, RIE and PPL Electric. PPL's corporate level financing subsidiary is PPL Capital Funding. On March 17, 2021, PPL WPD Limited entered into a share purchase agreement to sell PPL's U.K. utility business, which prior to its sale substantially represented PPL's U.K. Regulated segment, to a subsidiary of National Grid plc. The sale was completed on June 14, 2021. The results of operations of the U.K. utility business are classified as Discontinued Operations on PPL's Statements of Income for all periods presented. PPL has elected to separately report the cash flows of continuing and discontinued operations on the Statements of Cash Flows for all periods presented. Unless otherwise noted, the notes to these financial statements exclude amounts related to discontinued operations. See Note 9 for additional information. On May 25, 2022, PPL Rhode Island Holdings, a wholly owned subsidiary of PPL, acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid U.S., a subsidiary of National Grid plc. Narragansett Electric, whose service area covers substantially all of Rhode Island, is primarily engaged in the transmission, distribution and sale of electricity and the distribution and sale of natural gas. The results of Narragansett Electric are included in the consolidated results of PPL from the date of the acquisition. Following the closing of the acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). See Note 9 for additional information. (PPL and PPL Electric) PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR. (PPL, LG&E and KU) LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name. (All Registrants) The financial statements of the Registrants include each company's own accounts as well as the accounts of all entities in which the company has a controlling financial interest. Entities for which a controlling financial interest is not demonstrated through voting interests are evaluated based on accounting guidance for Variable Interest Entities (VIEs). The Registrants consolidate a VIE when they are determined to have a controlling interest in the VIE and, as a result, are the primary beneficiary of the entity. Amounts consolidated under the VIE guidance are not material to the Registrants. All significant intercompany transactions have been eliminated. The financial statements of PPL, LG&E and KU include their share of any undivided interests in jointly owned facilities, as well as their share of the related operating costs of those facilities. See Note 13 for additional information.
Regulation	Regulation (All Registrants) PPL Electric, RIE, LG&E and KU are cost-based rate-regulated utilities for which rates are set by regulators to enable PPL Electric, RIE, LG&E and KU to recover the costs of providing electric or gas service, as applicable, and to provide a reasonable return to shareholders. Base rates are generally established based on a future test period. As a result, the financial statements are subject to the accounting for certain types of regulation as prescribed by GAAP and reflect the effects of regulatory actions. Regulatory assets are recognized for the effect of transactions or events where future recovery of underlying costs is probable in regulated customer rates. The effect of such accounting is to defer certain or qualifying costs that would otherwise currently be charged to expense. Regulatory liabilities are recognized for amounts expected to be returned through future regulated customer rates. In certain cases, regulatory liabilities are recorded based on an understanding or agreement with the regulator that rates have been set to recover expected future costs, and the regulated entity is accountable for any amounts charged pursuant to such rates and not yet expended for the intended purpose. The accounting for regulatory assets and regulatory liabilities is based on specific ratemaking decisions or precedent for each transaction or event as prescribed by the FERC or the applicable state regulatory commissions. See Note 7 for additional details regarding regulatory matters.
Accounting Records	Accounting Records The system of accounts for regulated entities is maintained in accordance with the Uniform System of Accounts prescribed by the FERC and adopted by the applicable state regulatory commissions.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities, the disclosure of contingent liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Loss Accruals	Loss Accruals Potential losses are accrued when (1) information is available that indicates it is "probable" that a loss has been incurred, given the likelihood of uncertain future events and (2) the amount of loss can be reasonably estimated. Accounting guidance defines "probable" as cases in which "the future event or events are likely to occur." The Registrants continuously assess potential loss contingencies for environmental remediation, litigation claims, regulatory penalties and other events. Loss accruals for environmental remediation are discounted when appropriate. The accrual of contingencies that might result in gains is not recorded, unless realization is assured.
Earnings Per Share	Earnings Per Share (PPL) EPS is computed using the two-class method, which is an earnings allocation method for computing EPS that treats a participating security as having rights to earnings that would otherwise have been available to common shareowners. Share-based payment awards that provide recipients a non-forfeitable right to dividends or dividend equivalents are considered participating securities.
Price Risk Management	Price Risk Management (All Registrants) Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Derivative instruments pursuant to regulator approved plans to manage commodity price risk associated with natural gas purchases to reduce fluctuations in natural gas prices and costs associated with these derivatives instruments are generally recoverable through approved cost recovery mechanism. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved to facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. (PPL) Processes exist that allow for subsequent review and validation of contract information as it relates to interest rate derivatives and commodity gas contracts. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to: • Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring. • Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges. • Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. (All Registrants) Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, RIE, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps or commodity gas contracts that are included in customer rates. (PPL and PPL Electric) To meet their obligations as last resort providers to their customers, PPL Electric and RIE have entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. (All Registrants) See Notes 17 and 18 for additional information on derivatives.
Revenue Recognition	Revenue (All Registrants) Operating revenues are primarily recorded based on energy deliveries through the end of each calendar month. Unbilled retail revenues result because customers' bills are rendered throughout the month, rather than at the end of the month. For RIE, LG&E and KU, unbilled revenues for a month are calculated by multiplying an estimate of unbilled kWh or Mcf by the estimated average cents per kWh or Mcf. Any difference between estimated and actual revenues is adjusted the following month when the previous unbilled estimate is reversed and actual billings occur. For PPL Electric, unbilled revenues for a month are calculated by multiplying the actual unbilled volumes by the price per tariff. In the fourth quarter of 2022, PPL Electric estimated deliveries to customers due to a temporary technical system issue. The issue has been resolved and unbilled revenues are expected to resume being calculated by multiplying the actual unbilled volumes by the price per tariff in the first quarter of 2023. PPL Electric's, RIE's, LG&E's and KU's base rates are determined based on cost of service. Some regulators have also authorized the use of additional alternative revenue programs, which enable PPL Electric, RIE, LG&E and KU to adjust future rates based on past activities or completed events. Revenues from alternative revenue programs are recognized when the specific events permitting future billings have occurred. Revenues from alternative revenue programs are required to be presented separately from revenues from contracts with customers. These amounts are, however, presented as revenues from contracts with customers, with an offsetting adjustment to alternative revenue program revenue, when they are billed to customers in future periods. See Note 3 for additional information.
Cash	Cash (All Registrants) Cash Equivalents All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. (PPL) Restricted Cash and Cash Equivalents Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash and cash equivalents. On the Balance Sheets, the current portion of restricted cash and cash equivalents is included in "Other current assets," while the noncurrent portion is included in "Other noncurrent assets." See Note 17 for a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets to the amounts shown on the Statements of Cash Flows.
Fair Value Measurements	(All Registrants) Fair Value Measurements The Registrants value certain financial and nonfinancial assets and liabilities at fair value. Generally, the most significant fair value measurements relate to price risk management assets and liabilities, investments in securities in defined benefit plans, and cash and cash equivalents. PPL and its subsidiaries use, as appropriate, a market approach (generally, data from market transactions), an income approach (generally, present value techniques and option-pricing models) and/or a cost approach (generally, replacement cost) to measure the fair value of an asset or liability. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The Registrants classify fair value measurements within one of three levels in the fair value hierarchy. The level assigned to a fair value measurement is based on the lowest level input that is significant to the fair value measurement in its entirety. The three levels of the fair value hierarchy are as follows: • Level 1 - quoted prices (unadjusted) in active markets for identical assets or liabilities that are accessible at the measurement date. Active markets are those in which transactions for the asset or liability occur with sufficient frequency and volume to provide pricing information on an ongoing basis. • Level 2 - inputs other than quoted prices included within Level 1 that are either directly or indirectly observable for substantially the full term of the asset or liability. • Level 3 - unobservable inputs that management believes are predicated on the assumptions market participants would use to measure the asset or liability at fair value. Assessing the significance of a particular input requires judgment that considers factors specific to the asset or liability. As such, the Registrants' assessment of the significance of a particular input may affect how the assets and liabilities are classified within the fair value hierarchy.
Investments	Investments Generally, the original maturity date of an investment and management's intent and ability to sell an investment prior to its original maturity determine the classification of investments as either short-term or long-term. Investments that would otherwise be classified as short-term, but are restricted as to withdrawal or use for other than current operations or are clearly designated for expenditure in the acquisition or construction of noncurrent assets or for the liquidation of long-term debts, are classified as long-term. Investments in entities in which a company has the ability to exercise significant influence but does not have a controlling financial interest are accounted for under the equity method. All other investments are carried at cost or fair value. These investments are included in "Other noncurrent assets" on the Balance Sheets. Earnings from these investments are recorded in "Other Income (Expense) - net" on the Statements of Income. Short-term investments generally include certain deposits as well as securities that are considered highly liquid or provide for periodic reset of interest rates. Investments with original maturities greater than three months and less than a year, as well as investments with original maturities of greater than a year that management has the ability and intent to sell within a year, are included in "Other current assets" on the Balance Sheets.
Property, Plant and Equipment	Property, Plant and Equipment (All Registrants) PP&E is recorded at original cost, unless impaired. If impaired, the asset is written down to fair value at that time, which becomes the new cost basis of the asset. PP&E acquired in business combinations is recorded at fair value at the time of acquisition. Original cost for constructed assets includes material, labor, contractor costs, certain overheads and financing costs, where applicable. Included in PP&E are capitalized costs of software projects that were developed or obtained for internal use. The cost of repairs and minor replacements are charged to expense as incurred. The Registrants record costs associated with planned major maintenance projects in the period in which work is performed and costs are incurred. AFUDC is capitalized at PPL Electric and RIE as part of the construction costs for cost-based rate-regulated projects for which a return on such costs is recovered after the project is placed in service. The debt component of AFUDC is credited to "Interest Expense" and the equity component is credited to "Other Income (Expense) - net" on the Statements of Income. AFUDC capitalized at LG&E and KU is generally not significant because a return is provided on construction work in progress. (PPL and PPL Electric) Depreciation (All Registrants) Depreciation is recorded over the estimated useful lives of property using various methods including the straight-line, composite and group methods. When a component of PP&E that was depreciated under the composite or group method is retired, the original cost is charged to accumulated depreciation. When all or a significant portion of an operating unit that was depreciated under the composite or group method is retired or sold, the property and the related accumulated depreciation account is reduced and any gain or loss is included in income, unless otherwise required by regulators. RIE, LG&E and KU accrue costs of removal net of estimated salvage value through depreciation, which is included in the calculation of customer rates over the assets' depreciable lives in accordance with regulatory practices. Cost of removal amounts accrued through depreciation rates are accumulated as a regulatory liability until the removal costs are incurred. For LG&E and KU, all ARO depreciation expenses are reclassified to a regulatory asset or regulatory liability. See "Asset Retirement Obligations" below and Note 7 for additional information. PPL Electric records net costs of removal when incurred as a regulatory asset. The regulatory asset is subsequently amortized through depreciation over a five-year period, which is recoverable in customer rates in accordance with regulatory practices.
Goodwill and Other Intangible Assets	Goodwill and Other Intangible Assets ( All Registrants) Goodwill represents the excess of the purchase price paid over the fair value of the identifiable net assets acquired in a business combination. Other acquired intangible assets are initially measured based on their fair value. Intangibles that have finite useful lives are amortized over their useful lives based upon the pattern in which the economic benefits of the intangible assets are consumed or otherwise used. Costs incurred to obtain an initial license and renew or extend terms of licenses are capitalized as intangible assets. When determining the useful life of an intangible asset, including intangible assets that are renewed or extended, PPL and its subsidiaries consider: • the expected use of the asset; • the expected useful life of other assets to which the useful life of the intangible asset may relate; • legal, regulatory, or contractual provisions that may limit the useful life; • the company's historical experience as evidence of its ability to support renewal or extension; • the effects of obsolescence, demand, competition, and other economic factors; and, • the level of maintenance expenditures required to obtain the expected future cash flows from the asset.
Asset Impairment (Excluding Investments)	Asset Impairment (Excluding Investments) (All Registrants) The Registrants review long-lived assets that are subject to depreciation or amortization, including finite-lived intangibles, for impairment when events or circumstances indicate carrying amounts may not be recoverable. A long-lived asset classified as held and used is impaired when the carrying amount of the asset exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If impaired, the asset's carrying value is written down to its fair value. A long-lived asset classified as held for sale is impaired when the carrying amount of the asset (disposal group) exceeds its fair value less cost to sell. If impaired, the asset's (disposal group's) carrying value is written down to its fair value less cost to sell. PPL, LG&E and KU review goodwill for impairment at the reporting unit level annually or more frequently when events or circumstances indicate that the carrying amount of a reporting unit may be greater than the unit's fair value. Additionally, goodwill must be tested for impairment in circumstances when a portion of goodwill has been allocated to a business to be disposed. PPL's, LG&E's and KU's reporting units are primarily at the operating segment level. Goodwill recognized upon the acquisition of Narragansett Electric was assigned for impairment testing by PPL to its reporting units expected to benefit from the acquisition, which were the Rhode Island Regulated reporting unit, the Pennsylvania Regulated reporting unit and the Kentucky Regulated reporting unit. See Note 9 for additional information regarding the acquisition. PPL, for its reporting units, and individually LG&E and KU may elect either to initially make a qualitative evaluation about the likelihood of an impairment of goodwill or to bypass the qualitative evaluation and test goodwill for impairment using a quantitative test. If the qualitative evaluation (referred to as step zero) is elected and the assessment results in a determination that it is not more likely than not that the fair value of a reporting unit is less than the carrying amount, the quantitative impairment test is not necessary. However, the quantitative impairment test is required if management concludes it is more likely than not that the fair value of a reporting unit is less than the carrying amount based on the step zero assessment. If the carrying amount of the reporting unit, including goodwill, exceeds its fair value, an impairment loss is recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit.
Asset Retirement Obligations	( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs.
Compensation and Benefits	Compensation and Benefits Defined Benefits (All Registrants) Certain PPL subsidiaries sponsor various defined benefit pension and other postretirement plans. An asset or liability is recorded to recognize the funded status of all defined benefit plans with an offsetting entry to AOCI or, for LG&E, KU, RIE and PPL Electric, to regulatory assets or liabilities. Consequently, the funded status of all defined benefit plans is fully recognized on the Balance Sheets. The expected return on plan assets is determined based on a market-related value of plan assets, which is calculated by rolling forward the prior year market-related value with contributions, disbursements and long-term expected return on investments. One-fifth of the difference between the actual value and the expected value is added (or subtracted if negative) to the expected value to determine the new market-related value. PPL uses an accelerated amortization method for the recognition of gains and losses for its defined benefit pension plans. Under the accelerated method, actuarial gains and losses in excess of 30% of the plan's projected benefit obligation are amortized on a straight-line basis over one-half of the required amortization period. Actuarial gains and losses in excess of 10% of the greater of the plan's projected benefit obligation or the market-related value of plan assets and less than 30% of the plan's projected benefit obligation are amortized on a straight-line basis over the full required amortization period. See Note 7 for a discussion of the regulatory treatment of defined benefit costs and Note 12 for a discussion of defined benefits. Stock-Based Compensation (PPL and PPL Electric)
Income Taxes	Taxes Income Taxes (All Registrants) PPL and its domestic subsidiaries file a consolidated U.S. federal income tax return. Significant management judgment is required in developing the Registrants' provision for income taxes, primarily due to the uncertainty related to tax positions taken or expected to be taken on tax returns and valuation allowances on deferred tax assets. The Registrants use a two-step process to evaluate tax positions. The first step requires an entity to determine whether, based on the technical merits supporting a particular tax position, it is more likely than not (greater than a 50% chance) that the tax position will be sustained. This determination assumes that the relevant taxing authority will examine the tax position and is aware of all the relevant facts surrounding the tax position. The second step requires an entity to recognize in its financial statements the benefit of a tax position that meets the more-likely-than-not recognition criterion. The benefit recognized is measured at the largest amount of benefit that has a likelihood of realization upon settlement that exceeds 50%. Unrecognized tax benefits are classified as current to the extent management expects to settle the uncertain tax position by payment or receipt of cash within one year of the reporting date. The amounts ultimately paid upon resolution of issues raised by taxing authorities may differ materially from the amounts accrued and may materially impact the financial statements of the Registrants in future periods. At December 31, 2022, no significant changes in unrecognized tax benefits were projected over the next 12 months. Deferred income taxes reflect the net future tax effects of temporary differences between the carrying amounts of assets and liabilities for accounting purposes and their basis for income tax purposes, as well as the tax effects of net operating losses and tax credit carryforwards. The Registrants record valuation allowances to reduce deferred income tax assets to the amounts that are more-likely-than-not to be realized. The need for valuation allowances requires significant management judgment. If the Registrants determine that they are able to realize deferred tax assets in the future in excess of recorded net deferred tax assets, adjustments to the valuation allowances increase income by reducing tax expense in the period that such determination is made. Likewise, if the Registrants determine that they are not able to realize all or part of net deferred tax assets in the future, adjustments to the valuation allowances would decrease income by increasing tax expense in the period that such determination is made. The amount of deferred tax assets ultimately realized may differ materially from the estimates utilized in the computation of valuation allowances and may materially impact the financial statements in the future . The Registrants defer investment tax credits when the credits are generated and amortize the deferred amounts over the average lives of the related assets. The Registrants recognize tax-related interest and penalties in "Income Taxes" on their Statements of Income. The Registrants use the portfolio approach method of accounting for deferred taxes related to pre-tax OCI transactions. The portfolio approach involves a strict period-by-period cumulative incremental allocation of income taxes to the change in income and losses reflected in OCI. Under this approach, the net cumulative tax effect is ignored. The net change in unrealized gains and losses recorded in AOCI under this approach would be eliminated only on the date the investment portfolio is classified as held for sale or is liquidated. See Note 6 to the Financial Statements for income tax disclosures. The provision for the Registrants' deferred income taxes related to regulatory assets and liabilities is based upon the ratemaking principles reflected in rates established by relevant regulators. The difference in the provision for deferred income taxes for regulatory assets and liabilities and the amount that otherwise would be recorded under GAAP is deferred and included on the Balance Sheets in noncurrent "Regulatory assets" or "Regulatory liabilities."
Taxes, Other Than Income	Taxes, Other Than Income (All Registrants) The Registrants present sales taxes in "Other current liabilities" on the Balance Sheets. These taxes are not reflected on the Statements of Income. See Note 6 for details of taxes included in "Taxes, other than income" on the Statements of Income.
Leases	(All Registrants) Leases The Registrants determine whether contractual arrangements contain a lease by evaluating whether those arrangements either implicitly or explicitly identify an asset, whether the Registrants have the right to obtain substantially all of the economic benefits from use of the asset throughout the term of the arrangement, and whether the Registrants have the right to direct the use of the asset. Renewal options are included in the lease term if it is reasonably certain the Registrants will exercise those options. Periods for which the Registrants are reasonably certain not to exercise termination options are also included in the lease term. The Registrants have certain agreements with lease and non-lease components, such as office space leases, which are generally accounted for separately. Short-term leases are leases with a term that is 12 months or less and do not include a purchase option or option to extend the initial term of the lease to greater than 12 months that the Registrants are reasonably certain to exercise. The Registrants have made an accounting policy election to not recognize the right-of-use asset and the lease liability arising from leases classified as short-term. The discount rate for a lease is the rate implicit in the lease unless that rate cannot be readily determined. In that case, the Registrants are required to use their incremental borrowing rate, which is the rate the Registrants would have to pay to borrow, on a collateralized basis over a similar term, an amount equal to the lease payments in a similar economic environment. The Registrants receive secured borrowing rates from financial institutions based on their applicable credit profiles. The Registrants use the secured rate which corresponds with the term of the applicable lease. See Note 10 for additional information.
Fuel, Materials and Supplies	Fuel, Materials and Supplies Fuel, natural gas stored underground and materials and supplies are valued using the average cost method. Fuel costs for electricity generation are charged to expense as used. For RIE, natural gas supply costs are charged to expense when delivered to customers. For LG&E, natural gas supply costs are charged to expense as delivered to the distribution system. See Note 7 for further discussion of the fuel adjustment clauses and gas supply clause. "Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: 2022 PPL PPL Electric LG&E KU Fuel $ 125 $ — $ 44 $ 81 Natural gas stored underground 91 — 68 — Materials and supplies 227 69 54 86 Total $ 443 $ 69 $ 166 $ 167 2021 PPL PPL Electric LG&E KU Fuel $ 90 $ — $ 32 $ 58 Natural gas stored underground 54 — 54 — Materials and supplies 178 61 51 66 Total $ 322 $ 61 $ 137 $ 124
Guarantees	Guarantees Generally, the initial measurement of a guarantee liability is the fair value of the guarantee at its inception. However, there are certain guarantees excluded from the scope of accounting guidance and other guarantees that are not subject to the initial recognition and measurement provisions of accounting guidance that only require disclosure. See Note 14 for further discussion of recorded and unrecorded guarantees.
Treasury Stock	Treasury Stock
Financing Receivable, Allowance for Credit Losses, Policy for Uncollectible Amounts	Financing and Other Receivables (All Registrants) Accounts receivable are reported on the Balance Sheets at the gross outstanding amount adjusted for an allowance for doubtful accounts. Financing receivables include accounts receivable, with the exception of those items within accounts receivable that are not subject to the current expected credit loss model. Financing receivable collectability is evaluated using a current expected credit loss model, consisting of a combination of factors, including past due status based on contractual terms, trends in write-offs and the age of the receivable. Specific events, such as bankruptcies, are also considered when applicable. The Registrants also evaluate the impact of observable external factors on the collectability of the financing receivables to determine if adjustments to the allowance for doubtful accounts should be made based on current conditions or reasonable and supportable forecasts. Adjustments to the allowance for doubtful accounts are made based on the results of these analyses. Accounts receivable are written off in the period in which the receivable is deemed uncollectible. PPL Electric, RIE, LG&E and KU have identified one class of financing receivables, “accounts receivable - customer”, which includes financing receivables for all billed and unbilled sales with customers. All other financing receivables are classified as other. (PPL and PPL Electric) Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation.
PPL Electric Utilities Corp [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	PPL Electric's principal business is the transmission and distribution of electricity to serve retail customers in its franchised territory in eastern and central Pennsylvania and the regulated supply of electricity to retail customers in that territory as a PLR.
Price Risk Management	(PPL and PPL Electric) To meet their obligations as last resort providers to their customers, PPL Electric and RIE have entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. (All Registrants) See Notes 17 and 18 for additional information on derivatives.
Accounts Receivable	(PPL and PPL Electric) Within the credit loss model for the residential customer accounts receivables, customers are disaggregated based on their projected propensity to pay, which is derived from historical trends and the current activity of the individual customer accounts. Conversely, the non-residential customer accounts receivables are not further segmented due to the varying nature of the individual customers, which lack readily identifiable risk characteristics for disaggregation.
Compensation and Benefits	Stock-Based Compensation (PPL and PPL Electric)
Income Taxes	(PPL Electric, LG&E and KU) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.
Louisville Gas And Electric Co [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name.
Asset Retirement Obligations	( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs.
Income Taxes	(PPL Electric, LG&E and KU) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.
Kentucky Utilities Co [Member]
Summary of Significant Accounting Policies [Line Items]
Business and Consolidation	LG&E and KU are engaged in the generation, transmission, distribution and sale of electricity. LG&E also engages in the distribution and sale of natural gas. LG&E and KU maintain their separate identities and serve customers in Kentucky under their respective names. KU also serves customers in Virginia under the Old Dominion Power name.
Asset Retirement Obligations	( PPL, LG&E and KU ) Asset Retirement Obligations PPL and its subsidiaries record liabilities to reflect various legal obligations associated with the retirement of long-lived assets. Initially, this obligation is measured at fair value and offset with an increase in the value of the capitalized asset, which is depreciated over the asset's useful life. Until the obligation is settled, the liability is increased through the recognition of accretion expense classified within "Other operation and maintenance" on the Statements of Income to reflect changes in the obligation due to the passage of time. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. Estimated ARO costs and settlement dates, which affect the carrying value of the ARO and the related capitalized asset, are reviewed periodically to ensure that any material changes are incorporated into the latest estimate of the ARO. Any change to the capitalized asset, positive or negative, is generally amortized over the remaining life of the associated long-lived asset. See Note 7 and Note 20 for additional information on AROs.
Income Taxes	(PPL Electric, LG&E and KU) The income tax provision for PPL Electric, LG&E and KU is calculated in accordance with an intercompany tax sharing agreement, which provides that taxable income be calculated as if PPL Electric, LG&E, KU and any domestic subsidiaries each filed a separate return. Tax benefits are not shared between companies. The entity that generates a tax benefit is the entity that is entitled to the tax benefit. The effect of PPL filing a consolidated tax return is taken into account in the settlement of current taxes and the recognition of deferred taxes.

Fair Value Measurements (Polici

Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurements	The fair value of a group of financial assets and liabilities is measured on a net basis.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Policies)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments And Hedging Activities [Line Items]
Fair Value of Derivatives	Price Risk Management (All Registrants) Interest rate contracts are used to hedge exposure to changes in the fair value of debt instruments and to hedge exposure to variability in expected cash flows associated with existing floating-rate debt instruments or forecasted fixed-rate issuances of debt. Derivative instruments pursuant to regulator approved plans to manage commodity price risk associated with natural gas purchases to reduce fluctuations in natural gas prices and costs associated with these derivatives instruments are generally recoverable through approved cost recovery mechanism. Similar derivatives may receive different accounting treatment, depending on management's intended use and documentation. Certain contracts may not meet the definition of a derivative because they lack a notional amount or a net settlement provision. In cases where there is no net settlement provision, markets are periodically assessed to determine whether market mechanisms have evolved to facilitate net settlement. Certain derivative contracts may be excluded from the requirements of derivative accounting treatment because NPNS has been elected. These contracts are accounted for using accrual accounting. Contracts that have been classified as derivative contracts are reflected on the balance sheets at fair value. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing activities on the Statements of Cash Flows, depending on the classification of the hedged items. PPL and its subsidiaries have elected not to offset net derivative positions against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. (PPL) Processes exist that allow for subsequent review and validation of contract information as it relates to interest rate derivatives and commodity gas contracts. The accounting department provides the treasury department with guidelines on appropriate accounting classifications for various contract types and strategies. Examples of accounting guidelines provided to the treasury department staff include, but are not limited to: • Transactions to lock in an interest rate prior to a debt issuance can be designated as cash flow hedges, to the extent the forecasted debt issuances remain probable of occurring. • Transactions to hedge fluctuations in the fair value of existing debt can be designated as fair value hedges. • Derivative transactions that do not qualify for cash flow or net investment hedge treatment are marked to fair value through earnings. (All Registrants) Derivative transactions may be marked to fair value through regulatory assets/liabilities at PPL Electric, RIE, LG&E and KU, if approved by the appropriate regulatory body. These transactions generally include the effect of interest rate swaps or commodity gas contracts that are included in customer rates. (PPL and PPL Electric) To meet their obligations as last resort providers to their customers, PPL Electric and RIE have entered into certain contracts that meet the definition of a derivative. However, NPNS has been elected for these contracts. (All Registrants) See Notes 17 and 18 for additional information on derivatives.
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
Louisville Gas And Electric Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.
Kentucky Utilities Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Price Risk Management	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2022
Summary of Significant Accounting Policies [Line Items]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow
Capitalized Interest Table Text Block	Capitalized interest, including the debt component of AFUDC, for the years ended December 31 is as follows: 2022 2021 2020 PPL $ 7 $ 6 $ 7 PPL Electric 5 6 7
Weighted-average Rates of Depreciation	Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2022 2021 2020 PPL 3.21 % 3.61 % 3.53 % PPL Electric 2.75 % 3.05 % 2.99 % LG&E 4.16 % 3.99 % 4.00 % KU 4.01 % 4.17 % 4.00 %
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: 2022 PPL PPL Electric LG&E KU Fuel $ 125 $ — $ 44 $ 81 Natural gas stored underground 91 — 68 — Materials and supplies 227 69 54 86 Total $ 443 $ 69 $ 166 $ 167 2021 PPL PPL Electric LG&E KU Fuel $ 90 $ — $ 32 $ 58 Natural gas stored underground 54 — 54 — Materials and supplies 178 61 51 66 Total $ 322 $ 61 $ 137 $ 124
Schedule of Valuation and Qualifying Accounts Disclosure	The changes in the allowance for doubtful accounts are included in the following table. Amounts relate to financing receivables, except as noted. Additions Balance at Charged to Income Deductions (b) Balance at PPL 2022 $ 69 $ 78 $ 52 $ 95 (d) 2021 73 26 30 69 (d) 2020 (a) 58 (a) 28 13 73 (d) PPL Electric 2022 $ 35 $ 27 $ 29 $ 33 (c) 2021 41 13 19 35 (c) 2020 30 (a) 19 8 41 (c) LG&E 2022 $ 3 $ 6 $ 5 $ 4 2021 3 4 4 3 2020 1 4 2 3 KU 2022 $ 3 $ 6 $ 6 $ 3 2021 2 8 7 3 2020 1 4 3 2 (a) Adjusted for $2 million cumulative-effect adjustment upon adoption of current expected credit loss guidance. (b) Primarily related to uncollectible accounts written off. (c) Includes $3 million related to other accounts receivables at December 31, 2022, 2021 and 2020.
PPL Electric Utilities Corp [Member]
Summary of Significant Accounting Policies [Line Items]
Capitalized Interest Table Text Block	Capitalized interest, including the debt component of AFUDC, for the years ended December 31 is as follows: 2022 2021 2020 PPL $ 7 $ 6 $ 7 PPL Electric 5 6 7
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2022 2021 PPL Electric $ 2 $ (4) LG&E (6) 4 KU 4 1
Louisville Gas And Electric Co [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2022 2021 PPL Electric $ 2 $ (4) LG&E (6) 4 KU 4 1
Kentucky Utilities Co [Member]
Summary of Significant Accounting Policies [Line Items]
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2022 2021 PPL Electric $ 2 $ (4) LG&E (6) 4 KU 4 1

Segment and Related Informati_2

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Segment and Related Information	Income Statement data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2022 2021 2020 Operating Revenues from external customers (a) Kentucky Regulated $ 3,811 $ 3,348 $ 3,106 Pennsylvania Regulated 3,030 2,402 2,330 Rhode Island Regulated 1,038 — — Corporate and Other 23 33 38 Total $ 7,902 $ 5,783 $ 5,474 Depreciation Kentucky Regulated $ 685 $ 647 $ 606 Pennsylvania Regulated 393 424 403 Rhode Island Regulated 92 — — Corporate and Other 11 11 13 Total $ 1,181 $ 1,082 $ 1,022 Amortization (b) Kentucky Regulated $ 23 $ 15 $ 19 Pennsylvania Regulated 22 19 26 Rhode Island Regulated 2 — — Corporate and Other 5 5 13 Total $ 52 $ 39 $ 58 2022 2021 2020 Interest Expense (c) Kentucky Regulated $ 262 $ 249 $ 300 Pennsylvania Regulated 171 162 172 Rhode Island Regulated 39 — — Corporate and Other (d) 41 507 162 Total $ 513 $ 918 $ 634 Income Before Income Taxes Kentucky Regulated $ 621 $ 562 $ 516 Pennsylvania Regulated 699 599 664 Rhode Island Regulated (58) — — Corporate and Other (347) (640) (226) Total $ 915 $ 521 $ 954 Income Taxes (e) Kentucky Regulated $ 114 $ 94 $ 98 Pennsylvania Regulated 174 154 167 Rhode Island Regulated (14) — — Corporate and Other (73) 255 49 Total $ 201 $ 503 $ 314 Deferred income taxes and investment tax credits (f) Kentucky Regulated $ 6 $ 272 $ 64 Pennsylvania Regulated 91 79 82 Rhode Island Regulated 39 — — Corporate and Other 43 (264) 23 Total $ 179 $ 87 $ 169 Net Income Kentucky Regulated $ 507 $ 468 $ 418 Pennsylvania Regulated 525 445 497 Rhode Island Regulated (44) — — Corporate and Other (d) (274) (895) (275) Discontinued Operations 42 (1,498) 829 Total $ 756 $ (1,480) $ 1,469 (a) See Note 1 and Note 3 for additional information on Operating Revenues. (b) Represents non-cash expense items that include amortization of operating lease right-of-use assets, regulatory assets and liabilities, debt discounts and premiums and debt issuance costs. (c) Beginning in 2021, corporate level financing costs are no longer allocated to the reportable segments and are being reported in Corporate and Other. For the year ended December 31, 2020, corporate level financing costs of $32 million, net of $8 million of income taxes, were allocated to the Kentucky Regulated segment. For the year ended December 31, 2020, an immaterial amount of financing costs was allocated to the Pennsylvania Regulated segment. (d) 2021 includes losses from the extinguishment of PPL Capital Funding debt. See Note 8 for additional information. (e) Represents both current and deferred income taxes, including investment tax credits. (f) Represents a non-cash expense item that is also included in "Income Taxes." Cash Flow data for the segments and reconciliation to PPL's consolidated results for the years ended December 31 are as follows: 2022 2021 2020 Expenditures for long-lived assets Kentucky Regulated $ 917 $ 1,026 $ 966 Pennsylvania Regulated 889 904 1,154 Rhode Island Regulated 268 — — Corporate and Other 84 49 158 Total $ 2,158 $ 1,979 $ 2,278 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2022 2021 Total Assets Kentucky Regulated $ 16,904 $ 16,360 Pennsylvania Regulated 13,565 13,336 Rhode Island Regulated 6,081 — Corporate and Other (a) 1,287 3,527 Total $ 37,837 $ 33,223 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill, and the elimination of inter-segment transactions.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	12 Months Ended
	Dec. 31, 2022
Revenue from contracts with customers [Line Items]
Reconciliation of revenue from contracts with customers [Table Text Block]	The following table reconciles "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the years ended December 31: 2022 PPL PPL Electric LG&E KU Operating Revenues (a) $ 7,902 $ 3,030 $ 1,798 $ 2,074 Revenues derived from: Alternative revenue programs (b) (92) (56) 9 5 Other (c) (24) (14) (6) (4) Revenues from Contracts with Customers $ 7,786 $ 2,960 $ 1,801 $ 2,075 2021 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,783 $ 2,402 $ 1,569 $ 1,826 Revenues derived from: Alternative revenue programs (b) 77 83 (3) (3) Other (c) (22) (3) (8) (9) Revenues from Contracts with Customers $ 5,838 $ 2,482 $ 1,558 $ 1,814 2020 PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,474 $ 2,331 $ 1,456 $ 1,690 Revenues derived from: Alternative revenue programs (b) (24) (12) (8) (4) Other (c) (21) (3) (7) (10) Revenues from Contracts with Customers $ 5,429 $ 2,316 $ 1,441 $ 1,676 (a) PPL includes $1,038 million for the twelve months ended December 31, 2022 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information. (b) This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under collections as negative amounts. For PPL Electric, revenue in 2022 includes $74 million related to the amortization of the regulatory liability primarily recorded in 2021 for a reduction in the transmission formula rate return on equity that is reflected in rates in 2022. Revenue in 2021 was reduced by $78 million for a reduction in the transmission formula rate return on equity. See Note 7 for additional information. (c) Represents additional revenues outside the scope of revenues from contracts with customers such as leases and other miscellaneous revenues.
Disaggregation of Revenue [Table Text Block]	The following table shows revenues from contracts with customers disaggregated by customer class for the years ended December 31: Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 2022 PA Regulated $ 1,647 $ 491 $ 85 $ 54 $ — $ — $ 683 $ 2,960 RI Regulated 299 101 9 478 — — 101 988 KY Regulated 1,637 1,068 662 323 28 97 — 3,815 Corp and Other — — — 23 — — — 23 Total PPL $ 3,583 $ 1,660 $ 756 $ 878 $ 28 $ 97 $ 784 $ 7,786 2021 PA Regulated $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 RI Regulated — — — — — — — — KY Regulated 1,416 928 586 305 24 66 — 3,325 Corp and Other — — — 31 — — — 31 Total PPL $ 2,715 $ 1,278 $ 639 $ 386 $ 24 $ 66 $ 730 $ 5,838 2020 PA Regulated $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 RI Regulated — — — — — — — — KY Regulated 1,347 871 538 261 20 40 — 3,077 Corp and Other — — — 36 — — — 36 Total PPL $ 2,585 $ 1,185 $ 582 $ 347 $ 20 $ 40 $ 670 $ 5,429 PPL Electric 2022 $ 1,647 $ 491 $ 85 $ 54 $ — $ — $ 683 $ 2,960 2021 $ 1,299 $ 350 $ 53 $ 50 $ — $ — $ 730 $ 2,482 2020 $ 1,238 $ 314 $ 44 $ 50 $ — $ — $ 670 $ 2,316 LG&E 2022 $ 835 $ 551 $ 199 $ 141 $ — $ 75 $ — $ 1,801 2021 $ 711 $ 473 $ 180 $ 145 $ — $ 49 $ — $ 1,558 2020 $ 676 $ 444 $ 173 $ 114 $ — $ 34 $ — $ 1,441 KU 2022 $ 802 $ 517 $ 463 $ 182 $ 28 $ 83 $ — $ 2,075 2021 $ 705 $ 455 $ 406 $ 160 $ 24 $ 64 $ — $ 1,814 2020 $ 671 $ 427 $ 365 $ 147 $ 20 $ 46 $ — $ 1,676 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. (b) Includes wholesale power and transmission revenues. LG&E and KU amounts include intercompany power sales and transmission revenues, which are eliminated upon consolidation at PPL.
Credit loss recognized from contract with customer [Table Text Block]	The following table shows the accounts receivable and unbilled revenues balances that were impaired for the year ended December 31: 2022 2021 2020 PPL(a) $ 70 $ 22 $ 25 PPL Electric 21 10 17 LG&E 6 4 4 KU 6 8 4
Contract with Customer, Asset and Liability [Table Text Block]	The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers: PPL PPL Electric LG&E KU Contract liabilities as of December 31, 2022 $ 34 $ 23 $ 5 $ 6 Contract liabilities as of December 31, 2021 42 25 6 6 Revenue recognized during the year ended December 31, 2022 that was included in the contract liability balance at December 31, 2021 25 12 6 6 Contract liabilities as of December 31, 2021 $ 42 $ 25 $ 6 $ 6 Contract liabilities as of December 31, 2020 40 23 5 6 Revenue recognized during the year ended December 31, 2021 that was included in the contract liability balance at December 31, 2020 24 11 5 6 Contract liabilities as of December 31, 2020 $ 40 $ 23 $ 5 $ 6 Contract liabilities as of December 31, 2019 37 21 5 4 Revenue recognized during the year ended December 31, 2020 that was included in the contract liability balance at December 31, 2019 22 9 5 4

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2022
Earnings Per Share [Abstract]
Basic and Diluted EPS Computations	Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended December 31, used in the EPS calculation are: 2022 2021 2020 Income (Numerator) Income from continuing operations after income taxes $ 714 $ 18 $ 640 Less amounts allocated to participating securities 1 — 1 Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted $ 713 $ 18 $ 639 Income (loss) from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ 42 $ (1,498) $ 829 Net income (loss) attributable to PPL $ 756 $ (1,480) 1,469 Less amounts allocated to participating securities 1 — 1 Net income (loss) available to PPL common shareowners - Basic and Diluted $ 755 $ (1,480) $ 1,468 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 736,027 762,902 768,590 Add: Dilutive share-based payment awards (a) 875 1,917 794 Weighted-average shares - Diluted EPS 736,902 764,819 769,384 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.97 $ 0.03 $ 0.83 Income (loss) from discontinued operations (net of income taxes) 0.06 (1.96) 1.08 Net Income (Loss) available to PPL common shareowners $ 1.03 $ (1.93) $ 1.91 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 0.96 $ 0.03 $ 0.83 Income (loss) from discontinued operations (net of income taxes) 0.06 (1.96) 1.08 Net Income (Loss) available to PPL common shareowners $ 1.02 $ (1.93) $ 1.91 (a) The Treasury Stock Method was applied to non-participating share-based payment awards.
Common Stock Issuances	For the years ended December 31, PPL issued common stock related to stock-based compensation plans as follows (in thousands): 2022 2021 Stock-based compensation plans (a) 124 983 (a) Includes stock options exercised, vesting of performance units, vesting of restricted stock and restricted stock units and conversion of stock units granted to directors.
Antidilutive Securities Excluded From Diluted EPS	For the years ended December 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive: 2022 2021 2020 Stock-based compensation awards 93 1,783 452

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2022
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of PPL's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Deferred investment tax credits $ 29 $ 30 Regulatory liabilities 88 94 Income taxes due to customers 448 422 Accrued pension and postretirement costs 86 75 State loss carryforwards 230 483 Federal and state tax credit carryforwards 68 15 Internal Revenue Code Section 197 intangibles (a) 85 — Leases 15 67 Contributions in aid of construction 114 120 Other 72 84 Valuation allowances (213) (462) Total deferred tax assets 1,022 928 Deferred Tax Liabilities Plant - net 3,609 3,812 Regulatory assets 337 180 Prepayments 46 — Other 30 75 Total deferred tax liabilities 4,022 4,067 Net deferred tax liability $ 3,000 $ 3,139 (a) Certain of the RIE assets acquired in 2022 are treated as intangibles for tax purposes that are amortized over a 15 year period. PPL recorded deferred tax assets on these intangibles, which will reverse as tax deductions are taken.
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2022, PPL had the following loss and tax credit carryforwards, related deferred tax assets and valuation allowances recorded against the deferred tax assets: Gross Deferred Tax Asset Valuation Allowance Expiration Loss and other carryforwards State net operating losses $ 5,830 $ 230 $ (213) 2023-2042 Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal investment tax credit 20 — 2042 Federal foreign tax credits 32 — 2027 Federal - other 3 — 2042 State recycling credit 12 — 2028 State - other 1 — Indefinite
Schedule of Valuation and Qualifying Accounts of Deferred Tax Assets	The changes in deferred tax valuation allowances were as follows: Additions Balance at Charged Charged to Deductions Balance 2022 $ 462 $ 10 $ — $ 259 (a) $ 213 2021 536 48 (b) — 122 (c) 462 2020 514 26 — 4 536 (a) In 2022, PPL recorded a $36 million decrease in a valuation allowance on a 2002 state net operating loss carryforward that expired in 2022 and a $213 million decrease in the valuation allowance due to the Pennsylvania rate change. See reconciliation of income tax table below. (b) In 2021, PPL recorded a $31 million increase in a valuation allowance on a state net operating loss carryforward in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. (c) In light of the disposition of PPL's U.K. utility business, there was a decrease in the valuation allowance of approximately $113 million.
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ (2) $ (1) $ (8) Current - State 24 36 24 Current - Foreign — (1) (2) Total Current Expense (Benefit) 22 34 14 Deferred - Federal 122 28 135 Deferred - State 68 105 94 Deferred - Foreign (a) — 383 101 Total Deferred Expense (Benefit), excluding operating loss carryforwards 190 516 330 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 2 12 6 Deferred - State (10) (56) (33) Total Tax Expense (Benefit) of Operating Loss Carryforwards (8) (44) (27) Total income tax expense (benefit) $ 201 $ 503 $ 314 Total income tax expense (benefit) - Federal $ 119 $ 36 $ 130 Total income tax expense (benefit) - State 82 85 85 Total income tax expense (benefit) - Foreign — 382 99 Total income tax expense (benefit) $ 201 $ 503 $ 314 (a) The U.K. Finance Act 2021, formally enacted on June 10, 2021, increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in 2021. In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction from 19% to 17%. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2022 2021 2020 Discontinued operations $ (42) $ 759 $ 188 Reclassification from AOCI due to sale of UK utility business — 660 — Other comprehensive income 11 150 (19) Total $ (31) $ 1,569 $ 169
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 192 $ 109 $ 200 State income taxes, net of federal income tax benefit 68 23 48 Valuation allowance adjustments (a) 9 48 24 Federal and state income tax return adjustments (1) (3) (9) Impact of the U.K. Finance Acts on deferred tax balances (b) — 383 101 Depreciation and other items not normalized (8) (5) (5) Amortization of excess deferred federal and state income taxes (54) (54) (43) Non-deductible officer's salary 5 6 7 Other (10) (4) (9) Total increase (decrease) 9 394 114 Total income tax expense (benefit) $ 201 $ 503 $ 314 Effective income tax rate 22.0% 96.5% 32.9% (a) In 2021, PPL recorded a $31 million state deferred tax benefit on a net operating loss and an offsetting valuation allowance in connection with the loss on extinguishment associated with a tender offer to purchase and retire PPL Capital Funding's outstanding Senior Notes. In 2022, 2021, and 2020, PPL recorded deferred income tax expense of $5 million, $15 million and $24 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2020, the U.K. Finance Act 2020 cancelled the tax rate reduction to 17%, thereby maintaining the corporation tax rate at 19% for financial years 2020 and 2021. The primary impact of the cancellation of the corporation tax rate reduction was an increase in deferred tax liabilities and a corresponding deferred tax expense of $106 million. The U.K. Finance Act 2021, formally enacted on June 10, 2021, increased the U.K. corporation tax rate from 19% to 25%, effective April 1, 2023. The primary impact of the corporation tax rate increase was an increase in deferred tax liabilities of the U.K. utility business, which was sold on June 14, 2021, and a corresponding deferred tax expense of $383 million, which was recognized in continuing operations in 2021.
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Taxes, other than income State gross receipts (a) $ 175 $ 113 $ 100 Domestic - other (a) 157 94 80 Total $ 332 $ 207 $ 180 (a) Increase primarily due to the acquisition of RIE.
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of PPL Electric's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Accrued pension and postretirement costs $ 27 $ 14 Contributions in aid of construction 87 95 Regulatory liabilities 36 52 Income taxes due to customers 193 154 Other 18 21 Total deferred tax assets 361 336 Deferred Tax Liabilities Electric utility plant - net 1,745 1,891 Regulatory assets 93 74 Prepayments 35 — Other 2 39 Total deferred tax liabilities 1,875 2,004 Net deferred tax liability $ 1,514 $ 1,668
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ 63 $ 40 $ 61 Current - State 20 35 23 Total Current Expense (Benefit) 83 75 84 Deferred - Federal 60 59 45 Deferred - State 31 20 38 Total Deferred Expense (Benefit), excluding operating loss carryforwards 91 79 83 Total income tax expense (benefit) $ 174 $ 154 $ 167 Total income tax expense (benefit) - Federal $ 123 $ 99 $ 106 Total income tax expense (benefit) - State 51 55 61 Total income tax expense (benefit) $ 174 $ 154 $ 167
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 147 $ 126 $ 139 Increase (decrease) due to: State income taxes, net of federal income tax benefit 54 46 52 Federal and state income tax return adjustments (1) — (4) Depreciation and other items not normalized (7) (5) (5) Amortization of excess deferred federal income taxes (a) (12) (14) (16) State income tax rate change (b) (9) — — Other 2 1 1 Total increase (decrease) 27 28 28 Total income tax expense (benefit) $ 174 $ 154 $ 167 Effective income tax rate 24.9% 25.7% 25.2% (a) In 2022, 2021, and 2020, PPL Electric recorded lower income tax expense for the amortization of excess deferred taxes that primarily resulted from the U.S. federal corporate income tax rate reduction from 35% to 21% enacted by the TCJA. This amortization represents each year's refund amount, prior to a tax gross-up, to be paid to customers for previously collected deferred taxes at higher income tax rates.
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were as follows: 2022 2021 2020 Taxes, other than income State gross receipts $ 142 $ 113 $ 100 Property and other 7 7 7 Total $ 149 $ 120 $ 107
Louisville Gas And Electric Co [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of LG&E's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Contributions in aid of construction $ 17 $ 15 Regulatory liabilities 18 18 Deferred investment tax credits 8 8 Income taxes due to customers 119 125 State tax credit carryforwards 9 11 Lease liabilities 4 4 Valuation allowances (9) (11) Other 8 11 Total deferred tax assets 174 181 Deferred Tax Liabilities Plant - net 869 854 Regulatory assets 69 65 Lease right-of-use assets 3 4 Other 4 9 Total deferred tax liabilities 945 932 Net deferred tax liability $ 771 $ 751
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ 60 $ 41 $ 53 Current - State 9 5 7 Total Current Expense (Benefit) 69 46 60 Deferred - Federal (10) 1 (4) Deferred - State 5 8 7 Total Deferred Expense (Benefit) (5) 9 3 Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 63 $ 54 $ 62 Total income tax expense (benefit) - Federal $ 49 $ 41 $ 48 Total income tax expense (benefit) - State 14 13 14 Total income tax expense (benefit) $ 63 $ 54 $ 62
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 70 $ 64 $ 64 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 12 12 Amortization of excess deferred federal and state income taxes (18) (20) (11) Other (2) (2) (3) Total increase (decrease) (7) (10) (2) Total income tax expense (benefit) $ 63 $ 54 $ 62 Effective income tax rate 18.8% 17.8% 20.3%
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Taxes, other than income Property and other $ 48 $ 46 $ 40 Total $ 48 $ 46 $ 40
Kentucky Utilities Co [Member]
Income Taxes [Line Items]
Components of Deferred Tax Assets and Liabilities	Significant components of KU's deferred income tax assets and liabilities were as follows: 2022 2021 Deferred Tax Assets Contributions in aid of construction $ 9 $ 9 Regulatory liabilities 23 23 Deferred investment tax credits 21 22 Income taxes due to customers 136 143 State tax credit carryforwards 4 4 Lease liabilities 5 7 Valuation allowances (3) (3) Other 4 4 Total deferred tax assets 199 209 Deferred Tax Liabilities Plant - net 1,028 1,012 Regulatory assets 56 41 Pension and postretirement costs 6 13 Lease right-of-use assets 5 6 Other — 2 Total deferred tax liabilities 1,095 1,074 Net deferred tax liability $ 896 $ 865
Components of Income Tax Expense (Benefit)	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Income Tax Expense (Benefit) Current - Federal $ 63 $ 58 $ 40 Current - State 11 8 3 Total Current Expense (Benefit) 74 66 43 Deferred - Federal (3) (4) 11 Deferred - State 7 7 11 Total Deferred Expense (Benefit) 4 3 22 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 76 $ 67 $ 63 Total income tax expense (benefit) - Federal $ 58 $ 52 $ 49 Total income tax expense (benefit) - State 18 15 14 Total income tax expense (benefit) $ 76 $ 67 $ 63
Reconciliation of Income Tax Expense Derived From Statutory Tax Rate	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 84 $ 76 $ 72 Increase (decrease) due to: State income taxes, net of federal income tax benefit 16 14 14 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (21) (20) (17) Other (1) (1) (4) Total decrease (8) (9) (9) Total income tax expense (benefit) $ 76 $ 67 $ 63 Effective income tax rate 19.1% 18.4% 18.4%
Details of Taxes Other Than Income	Details of the components of income tax expense, a reconciliation of federal income taxes derived from statutory tax rates applied to "Income Before Income Taxes" to income taxes for reporting purposes, and details of "Taxes, other than income" were: 2022 2021 2020 Taxes, other than income Property and other $ 45 $ 41 $ 37 Total $ 45 $ 41 $ 37

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2022
Regulated Operations [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31: PPL PPL Electric 2022 2021 2022 2021 Current Regulatory Assets: Gas supply clause $ 41 $ 21 $ — $ — Rate adjustment mechanism 96 — — — Derivative Instruments 41 — — — Smart meter rider 5 11 5 11 Universal service rider 3 — 3 — Fuel adjustment clause 38 11 — — Other 34 21 5 11 Total current regulatory assets $ 258 $ 64 $ 13 $ 22 Noncurrent Regulatory Assets: Defined benefit plans $ 778 $ 523 $ 353 $ 256 Plant outage cost 46 54 — — Net Metering 61 — — — Environmental Cost recovery 102 — — — Taxes recoverable through future rates 47 — — — Storm costs 118 11 — — Unamortized loss on debt 21 24 3 4 Interest rate swaps 7 18 — — Terminated interest rate swaps 63 70 — — Accumulated cost of removal of utility plant 212 228 212 228 AROs 295 302 — — Other 69 6 — — Total noncurrent regulatory assets $ 1,819 $ 1,236 $ 568 $ 488 PPL PPL Electric 2022 2021 2022 2021 Current Regulatory Liabilities: Generation supply charge $ 37 $ 10 $ 37 $ 10 Transmission service charge 14 21 7 21 Universal service rider — 17 — 17 TCJA customer refund 15 22 15 22 Act 129 compliance rider 14 10 14 10 Transmission formula rate return on equity (b) — 73 — 73 Economic relief billing rate — 27 — — Transmission formula rate 12 — 12 — Rate adjustment mechanism 96 — — — Energy efficiency 23 — — — Other 27 2 — — Total current regulatory liabilities $ 238 $ 182 $ 85 $ 153 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 950 $ 639 $ — $ — Power purchase agreement - OVEC 26 35 — — Net deferred taxes 2,094 1,591 775 531 Defined benefit plans 187 95 45 28 Terminated interest rate swaps 60 62 — — Energy efficiency 32 — — — Other 63 — — — Total noncurrent regulatory liabilities $ 3,412 $ 2,422 $ 820 $ 559 LG&E KU 2022 2021 2022 2021 Current Regulatory Assets: Gas supply clause $ 13 $ 21 $ — $ — Gas line tracker — 3 — — Generation formula rate — — — 2 Fuel adjustment clause 9 4 29 7 Other 1 5 3 — Total current regulatory assets $ 23 $ 33 $ 32 $ 9 Noncurrent Regulatory Assets: Defined benefit plans $ 209 $ 164 $ 140 $ 103 Storm costs 7 8 3 3 Unamortized loss on debt 11 12 7 8 Interest rate swaps 7 18 — — Terminated interest rate swaps 37 41 26 29 AROs 76 75 219 227 Plant outage costs 12 15 34 39 Other 14 4 13 2 Total noncurrent regulatory assets $ 373 $ 337 $ 442 $ 411 LG&E KU 2022 2021 2022 2021 Current Regulatory Liabilities: Economic relief billing credit $ — $ 21 $ — $ 6 Other 7 — 6 2 Total current regulatory liabilities $ 7 $ 21 $ 6 $ 8 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 287 $ 262 $ 389 $ 377 Power purchase agreement - OVEC 18 24 8 11 Net deferred taxes 477 491 546 569 Defined benefit plans 21 10 56 57 Terminated interest rate swaps 30 31 30 31 Total noncurrent regulatory liabilities $ 833 $ 818 $ 1,029 $ 1,045 (a) See “Regulatory Matters - Federal Matters - PPL Electric Transmission Formula Rate Return on Equity” below for additional information.

Financing Activities (Tables)

Financing Activities (Tables)	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Line Items]
Credit Facilities in Place at Period End	The following credit facilities were in place at: December 31, 2022 December 31, 2021 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL PPL Capital Funding Syndicated Credit Facility (a) (b) Dec 2026 $ 1,250 $ — $ 561 $ 689 $ — $ — Bilateral Credit Facility (a) (b) Mar 2023 100 — — 100 — — Bilateral Credit Facility (a) (b) Mar 2023 100 — 58 42 — 15 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 619 $ 831 $ — $ 15 PPL Electric Syndicated Credit Facility (a) (b) Dec 2026 650 — 146 504 — 1 Term Loan Credit Facility (a) (b) Mar 2024 250 250 — — — — Total PPL Electric Credit Facilities $ 900 $ 250 $ 146 $ 504 $ — $ 1 December 31, 2022 December 31, 2021 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of LG&E Syndicated Credit Facility (a) (b) Dec 2026 500 — 180 320 — 69 Term Loan Credit Facility (a) (b) Jul 2024 300 300 — — — — Total LG&E Credit Facilities $ 800 $ 300 $ 180 $ 320 $ — $ 69 KU Syndicated Credit Facility (a) (b) Dec 2026 400 — 101 299 — — Term Loan Credit Facility (a) (b) Jul 2024 300 300 — — — — Total KU Credit Facilities $ 700 $ 300 $ 101 $ 299 $ — $ — (a) Each company pays customary fees under its respective facility and borrowings generally bear interest at LIBOR-based rates, or applicable secured overnight financing rates, plus an applicable margin. (b) The facilities contain a financial covenant requiring debt to total capitalization not to exceed 70% for PPL Capital Funding, PPL Electric, LG&E and KU, as calculated in accordance with the facilities and other customary covenants. Additionally, subject to certain conditions, PPL Capital Funding may request that the capacity of one of its bilateral credit facilities expiring in March 2023 be increased by up to $30 million and PPL Capital Funding, PPL Electric, LG&E and KU may each request up to a $250 million increase in its syndicated credit facility's capacity. Participation in any such increase is at the sole discretion of each lender.
Commercial paper	The following commercial paper programs were in place at: December 31, 2022 December 31, 2021 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) 4.84% $ 1,350 $ 561 $ 789 $ — PPL Electric 4.74% 650 145 505 — LG&E (b) 4.94% 500 180 320 0.31% 69 KU (c) 4.90% 400 101 299 — Total $ 2,900 $ 987 $ 1,913 $ 69 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) In August 2022, LG&E increased the size of their commercial paper program to $500 million. (c) In August 2022, KU increased the size of their commercial paper program to $400 million. (d) Commercial paper issued reflects the undiscounted face value of the issuance.
Long-term Debt	Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (d) 2022 2021 PPL Senior Unsecured Notes 3.95 % 2026 - 2047 $ 3,066 $ 1,566 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 4.06 % 2023 - 2050 8,957 9,205 Junior Subordinated Notes 7.39 % 2067 480 480 Term Loan Credit Facility 5.21 % 2024 850 — Total Long-term Debt before adjustments 13,353 11,251 Unamortized premium and (discount), net (32) (34) Unamortized debt issuance costs (78) (77) Total Long-term Debt 13,243 11,140 Less current portion of Long-term Debt 354 474 Total Long-term Debt, noncurrent $ 12,889 $ 10,666 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.26 % 2023 - 2049 $ 4,289 $ 4,539 Term Loan Credit Facility 5.17 % 2024 250 — Total Long-term Debt Before Adjustments 4,539 4,539 Unamortized discount (22) (22) Unamortized debt issuance costs (31) (33) Total Long-term Debt 4,486 4,484 Less current portion of Long-term Debt 340 474 Total Long-term Debt, noncurrent $ 4,146 $ 4,010 December 31, Weighted-Average Maturities (d) 2022 2021 LG&E Senior Secured Notes/First Mortgage Bonds (a) (c) 3.70 % 2025 - 2049 $ 2,024 $ 2,024 Term Loan Credit Facility 5.22 % 2024 300 — Total Long-term Debt Before Adjustments 2,324 2,024 Unamortized discount (4) (4) Unamortized debt issuance costs (13) (14) Total Long-term Debt 2,307 2,006 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 2,307 $ 2,006 KU Senior Secured Notes/First Mortgage Bonds (a) (c) 4.00 % 2023 - 2050 $ 2,642 $ 2,642 Term Loan Credit Facility 5.22 % 2024 300 — Total Long-term Debt Before Adjustments 2,942 2,642 Unamortized premium 5 5 Unamortized discount (9) (9) Unamortized debt issuance costs (18) (20) Total Long-term Debt 2,920 2,618 Less current portion of Long-term Debt 13 — Total Long-term Debt, noncurrent $ 2,907 $ 2,618 (a) Includes PPL Electric's senior secured and first mortgage bonds that are secured by the lien of PPL Electric's 2001 Mortgage Indenture, which covers substantially all of PPL Electric’s tangible distribution properties and certain of its tangible transmission properties located in Pennsylvania, subject to certain exceptions and exclusions. The carrying value of PPL Electric's property, plant and equipment was approximately $11.8 billion and $11.3 billion at December 31, 2022 and 2021. Includes LG&E's first mortgage bonds that are secured by the lien of the LG&E 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of LG&E's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity and the storage and distribution of natural gas. The aggregate carrying value of the property subject to the lien was $5.8 billion and $5.7 billion at December 31, 2022 and 2021. Includes KU's first mortgage bonds that are secured by the lien of the KU 2010 Mortgage Indenture which creates a lien, subject to certain exceptions and exclusions, on substantially all of KU's real and tangible personal property located in Kentucky and used or to be used in connection with the generation, transmission and distribution of electricity. The aggregate carrying value of the property subject to the lien was $7.1 billion and $6.9 billion at December 31, 2022 and 2021. (b) Includes PPL Electric's series of senior secured bonds that secure its obligations to make payments with respect to each series of Pollution Control Bonds that were issued by the LCIDA and the PEDFA on behalf of PPL Electric. These senior secured bonds were issued in the same principal amount, contain payment and redemption provisions that correspond to and bear the same interest rate as such Pollution Control Bonds. These senior secured bonds were issued under PPL Electric's 2001 Mortgage Indenture and are secured as noted in (a) above. The tax-exempt revenue bonds are subject to mandatory redemption upon determination that the interest rate on the bonds would be included in the holders' gross income for federal tax purposes. Includes $250 million of notes that may be called at a redemption price equal to 100% of the principal amount, plus accrued and unpaid interest to, but excluding, the redemption date. (c) Includes LG&E's and KU's series of first mortgage bonds that were issued to the respective trustees of tax-exempt revenue bonds to secure its respective obligations to make payments with respect to each series of bonds. The first mortgage bonds were issued in the same principal amounts, contain payment and redemption provisions that correspond to and bear the same interest rate as such tax-exempt revenue bonds. These first mortgage bonds were issued under the LG&E 2010 Mortgage Indenture and the KU 2010 Mortgage Indenture and are secured as noted in (a) above. The related tax-exempt revenue bonds were issued by various governmental entities, principally counties in Kentucky, on behalf of LG&E and KU. The related revenue bond documents allow LG&E and KU to convert the interest rate mode on the bonds from time to time to a commercial paper rate, daily rate, weekly rate, term rate of at least one year or, in some cases, an auction rate or a LIBOR index rate. At December 31, 2022, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $782 million for PPL, comprised of $473 million and $309 million for LG&E and KU. At December 31, 2022, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a variable rate mode totaled $66 million and $33 million for LG&E and KU. These variable rate tax-exempt revenue bonds are subject to tender for purchase by LG&E and KU at the option of the holder and to mandatory tender for purchase by LG&E and KU upon the occurrence of certain events. (d) The table reflects principal maturities only, based on stated maturities, sinking fund requirements, or earlier put dates, and the weighted-average rates as of December 31, 2022.
Long-term Debt Maturities	The aggregate maturities of long-term debt, based on sinking fund requirements, stated maturities or earlier put dates, for the periods 2023 through 2027 and thereafter are as follows: PPL PPL LG&E KU 2023 $ 354 $ 340 $ — $ 13 2024 1,501 900 300 300 2025 551 — 300 250 2026 904 — 90 164 2027 303 108 195 — Thereafter 9,740 3,191 1,439 2,215 Total $ 13,353 $ 4,539 $ 2,324 $ 2,942

Acquisitions, Development and_2

Acquisitions, Development and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2022
Acquisitions, Development and Divestitures [Line Items]
Disposal Group, Including Discontinued Operation, Income Statement Line Items	Following are the components of discontinued operations in the Statements of Income for the years ended December 31: 2022 2021 2020 Operating Revenues $ — $ 1,344 $ 2,133 Operating Expenses — 467 916 Other Income (Expense) - net — 202 167 Interest Expense (a) — 209 367 Income before income taxes — 870 1,017 Loss on sale — (1,609) — Income tax (benefit) expense (42) 759 188 Income (Loss) from Discontinued Operations (net of income taxes) $ 42 $ (1,498) $ 829 (a) No interest from corporate level debt was allocated to discontinued operations.
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The table below shows the preliminary allocation of the purchase price to the assets acquired and liabilities assumed that were recorded in PPL’s Consolidated Balance Sheet as of the Acquisition date. Purchase Price Allocation as of December 31, 2022 Assets Current Assets Cash and Cash Equivalents $ 154 Accounts Receivable (a) 195 Unbilled Revenues 54 Price Risk Management Assets 99 Regulatory Assets 75 Other Current Assets 65 Total Current Assets 642 Purchase Price Allocation as of December 31, 2022 Noncurrent Assets Property, Plant and Equipment, net 3,988 Regulatory Assets 395 Goodwill 1,586 Other Noncurrent Assets 166 Total Noncurrent Assets 6,135 Total Assets $ 6,777 Liabilities Current Liabilities Long-Term Debt Due Within One Year $ 14 Accounts Payable 180 Taxes Accrued 44 Regulatory Liabilities 239 Other Current Liabilities 198 Total Current Liabilities 675 Noncurrent Liabilities Long-Term Debt 1,496 Regulatory Liabilities 643 Other Deferred Credits and Noncurrent Liabilities 143 Noncurrent Liabilities 2,282 Total Purchase Price (Balance Sheet Net Assets) $ 3,820 (a) Amounts represent fair value as of May 25, 2022. The gross contractual amount is $255 million. Cash flows not expected to be collected as of May 25, 2022 were $60 million.
Business Acquisition, Pro Forma Information	The actual RIE Operating Revenues and Net income attributable to PPL included in PPL's Statement of Income for the period ended December 31, 2022, and PPL's unaudited pro forma 2022 and 2021 Operating Revenues and Net Income (Loss) attributable to PPL, including RIE, as if the Acquisition had occurred on January 1, 2021 are as follows. Operating Revenues Net Income (Loss) Actual RIE results included from May 25, 2022 - December 31, 2022 (a) $ 1,038 $ (44) PPL Pro Forma for the year ended 2022 8,667 790 PPL Pro Forma for the year ended 2021 7,478 159 (a) Net Income (Loss) includes expenses of $98 million (pre-tax) related to commitments made as a condition of the Acquisition.

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2022
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2022 2021 2020 PPL Lease cost: Operating lease cost $ 20 $ 24 $ 28 Short-term lease cost 6 6 7 Total lease cost $ 26 $ 30 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 6 $ 8 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 7 $ 9 KU Lease cost: Operating lease cost $ 9 $ 10 $ 13 Short-term lease cost 2 1 1 Total lease cost $ 11 $ 11 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2022 2021 2020 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 23 $ 24 Right-of-use asset obtained in exchange for new operating lease liabilities 15 12 17 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 8 $ 6 $ 7 Right-of-use asset obtained in exchange for new operating lease liabilities 4 4 6 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 12 $ 10 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 5 7 9
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2022. PPL LG&E KU 2023 $ 24 $ 6 $ 9 2024 17 5 7 2025 12 3 4 2026 5 1 1 2027 4 1 — Thereafter 7 — — Total $ 69 $ 16 $ 21 Weighted-average discount rate 3.1% 3.17% 3.4% Weighted-average remaining lease term (in years) 4 3 3 Current lease liabilities (a) $ 22 $ 6 $ 8 Non-current lease liabilities (a) 42 9 12 Right-of-use assets (b) 60 13 19 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in " Other noncurrent assets
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: 2022 2021 2020 PPL $ 6 11 16 LG&E 2 5 6 KU — 5 9
Louisville Gas And Electric Co [Member]
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2022 2021 2020 PPL Lease cost: Operating lease cost $ 20 $ 24 $ 28 Short-term lease cost 6 6 7 Total lease cost $ 26 $ 30 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 6 $ 8 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 7 $ 9 KU Lease cost: Operating lease cost $ 9 $ 10 $ 13 Short-term lease cost 2 1 1 Total lease cost $ 11 $ 11 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2022 2021 2020 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 23 $ 24 Right-of-use asset obtained in exchange for new operating lease liabilities 15 12 17 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 8 $ 6 $ 7 Right-of-use asset obtained in exchange for new operating lease liabilities 4 4 6 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 12 $ 10 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 5 7 9
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2022. PPL LG&E KU 2023 $ 24 $ 6 $ 9 2024 17 5 7 2025 12 3 4 2026 5 1 1 2027 4 1 — Thereafter 7 — — Total $ 69 $ 16 $ 21 Weighted-average discount rate 3.1% 3.17% 3.4% Weighted-average remaining lease term (in years) 4 3 3 Current lease liabilities (a) $ 22 $ 6 $ 8 Non-current lease liabilities (a) 42 9 12 Right-of-use assets (b) 60 13 19 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in " Other noncurrent assets
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: 2022 2021 2020 PPL $ 6 11 16 LG&E 2 5 6 KU — 5 9
Kentucky Utilities Co [Member]
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' operating leases for the years ended December 31: 2022 2021 2020 PPL Lease cost: Operating lease cost $ 20 $ 24 $ 28 Short-term lease cost 6 6 7 Total lease cost $ 26 $ 30 $ 35 LG&E Lease cost: Operating lease cost $ 6 $ 6 $ 8 Short-term lease cost 1 1 1 Total lease cost $ 7 $ 7 $ 9 KU Lease cost: Operating lease cost $ 9 $ 10 $ 13 Short-term lease cost 2 1 1 Total lease cost $ 11 $ 11 $ 14 The following table provides other key information related to the Registrants' operating leases at December 31: 2022 2021 2020 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 26 $ 23 $ 24 Right-of-use asset obtained in exchange for new operating lease liabilities 15 12 17 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 8 $ 6 $ 7 Right-of-use asset obtained in exchange for new operating lease liabilities 4 4 6 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 12 $ 10 $ 11 Right-of-use asset obtained in exchange for new operating lease liabilities 5 7 9
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for operating leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2022. PPL LG&E KU 2023 $ 24 $ 6 $ 9 2024 17 5 7 2025 12 3 4 2026 5 1 1 2027 4 1 — Thereafter 7 — — Total $ 69 $ 16 $ 21 Weighted-average discount rate 3.1% 3.17% 3.4% Weighted-average remaining lease term (in years) 4 3 3 Current lease liabilities (a) $ 22 $ 6 $ 8 Non-current lease liabilities (a) 42 9 12 Right-of-use assets (b) 60 13 19 (a) Current lease liabilities are included in " Other Current Liabilities Other deferred credits and noncurrent liabilities (b) Right-of-use assets are included in " Other noncurrent assets
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: 2022 2021 2020 PPL $ 6 11 16 LG&E 2 5 6 KU — 5 9

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2022
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Total Plan Annual Grant Limit Annual Grant Annual Grant Limit Award PPL Common Stock Limit For awards For awards Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) SIP 15,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2 % 3,000,000
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock units granted was: 2022 2021 2020 PPL $ 27.52 $ 28.00 $ 35.30 PPL Electric 26.66 27.96 35.37
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2022 was: Restricted Weighted- PPL Nonvested, beginning of period 1,004,583 $ 31.19 Granted 620,708 27.52 Vested (427,095) 31.55 Forfeited (15,779) 29.61 Nonvested, end of period 1,182,417 29.16 PPL Electric Nonvested, beginning of period 131,287 $ 31.50 Transfer between registrants (30,353) 30.03 Granted 51,832 26.66 Vested (41,233) 32.19 Forfeited (1,747) 32.19 Nonvested, end of period 109,786 28.91
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock units vesting for the years ended December 31 was: 2022 2021 2020 PPL $ 12 $ 8 $ 19 PPL Electric 1 1 3
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2022 2021 2020 Expected stock volatility 22.79% 27.81% 15.64% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2022 2021 2020 PPL $ 34.27 $ 32.44 $ 37.63 PPL Electric 34.42 32.92 38.64 The weighted-average grant date fair value of ROE performance units granted was: 2022 2021 2020 PPL $ 30.81 $ 30.08 $ 34.95 PPL Electric 30.70 29.39 35.59
Performance Units, Activity Rollforward	TSR performance unit activity for 2022 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 633,773 $ 34.68 Granted 298,795 34.27 Forfeited (a) (245,861) 35.48 Nonvested, end of period 686,707 34.21 TSR Performance Units Weighted- PPL Electric Nonvested, beginning of period 15,354 $ 34.36 Granted 14,238 34.42 Forfeited (a) (3,113) 35.58 Nonvested, end of period 26,479 34.25 (a) Primarily related to the forfeiture of 2019 domestic performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2022 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 722,353 $ 31.28 Granted (a) 257,199 30.81 Vested (470,182) 30.76 Nonvested, end of period 509,370 31.53 PPL Electric Nonvested, beginning of period 15,354 $ 30.27 Granted (a) 3,663 30.70 Vested (6,311) 30.78 Nonvested, end of period 12,706 30.14 (a) Represents attainment updates to the 2019 awards that paid out at 200% of target, as well as dividend equivalents that accumulated on outstanding 2020 and 2021 awards.
Share-based Compensation Arrangements by Share-based Payment Award, Performance-Based Units, Vested and Expected to Vest	The total fair value of ROE performance units vesting for the years ended December 31 was: 2022 2021 2020 PPL $ 12 $ 16 $ 8 PPL Electric — — 1
Stock Options, Activity Rollforward	Stock option activity for 2022 was: Number Weighted Weighted- Aggregate PPL Outstanding at beginning of period 766,002 $ 26.57 Exercised (594,450) 26.44 Outstanding and exercisable at end of period 171,552 27.04 0.1 $ —
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was: 2022 2021 2020 PPL $ 36 $ 34 $ 28 PPL Electric 2 11 10 The income tax benefit related to above compensation expense was as follows: 2022 2021 2020 PPL $ 10 $ 10 $ 8 PPL Electric 1 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2022, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 23 1.8 PPL Electric 2 1.8
PPL Electric Utilities Corp [Member]
Disclosure Of Compensation Related Costs Sharebased Payments [Line Items]
Stock-Based Compensation, Plan Award Limits	The following table details the award limits under each of the Plans. Total Plan Annual Grant Limit Annual Grant Annual Grant Limit Award PPL Common Stock Limit For awards For awards Plan (Shares) Each Calendar Year (Shares) shares (Shares) cash (in dollars) SIP 15,000,000 2,000,000 750,000 $ 15,000,000 ICPKE 14,199,796 2 % 3,000,000
Restricted Stock and Restricted Stock Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of restricted stock units granted was: 2022 2021 2020 PPL $ 27.52 $ 28.00 $ 35.30 PPL Electric 26.66 27.96 35.37
Restricted Stock and Restricted Stock Units, Activity Rollforward	Restricted stock unit activity for 2022 was: Restricted Weighted- PPL Nonvested, beginning of period 1,004,583 $ 31.19 Granted 620,708 27.52 Vested (427,095) 31.55 Forfeited (15,779) 29.61 Nonvested, end of period 1,182,417 29.16 PPL Electric Nonvested, beginning of period 131,287 $ 31.50 Transfer between registrants (30,353) 30.03 Granted 51,832 26.66 Vested (41,233) 32.19 Forfeited (1,747) 32.19 Nonvested, end of period 109,786 28.91
Restricted Stock and Restricted Stock Units, Total Fair Value Vested at Year End	The total fair value of restricted stock units vesting for the years ended December 31 was: 2022 2021 2020 PPL $ 12 $ 8 $ 19 PPL Electric 1 1 3
Performance Units, Valuation Assumptions	The weighted-average assumptions used in the model were: 2022 2021 2020 Expected stock volatility 22.79% 27.81% 15.64% Expected life 3 years 3 years 3 years
Performance Units, Weighted Average Grant Date Fair Value	The weighted-average grant date fair value of TSR performance units granted was: 2022 2021 2020 PPL $ 34.27 $ 32.44 $ 37.63 PPL Electric 34.42 32.92 38.64 The weighted-average grant date fair value of ROE performance units granted was: 2022 2021 2020 PPL $ 30.81 $ 30.08 $ 34.95 PPL Electric 30.70 29.39 35.59
Performance Units, Activity Rollforward	TSR performance unit activity for 2022 was: TSR Performance Units Weighted- PPL Nonvested, beginning of period 633,773 $ 34.68 Granted 298,795 34.27 Forfeited (a) (245,861) 35.48 Nonvested, end of period 686,707 34.21 TSR Performance Units Weighted- PPL Electric Nonvested, beginning of period 15,354 $ 34.36 Granted 14,238 34.42 Forfeited (a) (3,113) 35.58 Nonvested, end of period 26,479 34.25 (a) Primarily related to the forfeiture of 2019 domestic performance units as performance during the period was below the minimum established performance threshold, which resulted in no payout. ROE performance unit activity for 2022 was: ROE Performance Unit Weighted- PPL Nonvested, beginning of period 722,353 $ 31.28 Granted (a) 257,199 30.81 Vested (470,182) 30.76 Nonvested, end of period 509,370 31.53 PPL Electric Nonvested, beginning of period 15,354 $ 30.27 Granted (a) 3,663 30.70 Vested (6,311) 30.78 Nonvested, end of period 12,706 30.14 (a) Represents attainment updates to the 2019 awards that paid out at 200% of target, as well as dividend equivalents that accumulated on outstanding 2020 and 2021 awards.
Share-based Compensation Arrangements by Share-based Payment Award, Performance-Based Units, Vested and Expected to Vest	The total fair value of ROE performance units vesting for the years ended December 31 was: 2022 2021 2020 PPL $ 12 $ 16 $ 8 PPL Electric — — 1
Compensation Costs for Restricted Stock, Restricted Stock Units, Performance Units and Stock Options	Compensation expense for restricted stock, restricted stock units, performance units and stock options accounted for as equity awards was: 2022 2021 2020 PPL $ 36 $ 34 $ 28 PPL Electric 2 11 10 The income tax benefit related to above compensation expense was as follows: 2022 2021 2020 PPL $ 10 $ 10 $ 8 PPL Electric 1 3 3
Unrecognized Compensation Cost, Nonvested Restricted Stock, Restricted Stock Units, Performance Units and Stock Option Awards	At December 31, 2022, unrecognized compensation expense related to nonvested stock awards was: Unrecognized Weighted- PPL $ 23 1.8 PPL Electric 2 1.8

Retirement and Postemployment_2

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2022
Defined Benefit Plan Disclosure [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	The following table provides the components of net periodic defined benefit costs (credits) for PPL's pension and other postretirement benefit plans for the years ended December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 Net periodic defined benefit costs (credits): Service cost $ 51 $ 56 $ 56 $ 7 $ 6 $ 6 Interest cost 144 121 146 20 16 19 Expected return on plan assets (276) (255) (246) (28) (23) (21) Amortization of: Prior service cost (credit) 8 8 9 1 1 1 Actuarial (gain) loss 51 93 89 (5) (1) — Net periodic defined benefit costs (credits) prior to settlements and termination benefits (22) 23 54 (5) (1) 5 Settlements (a) 23 18 23 — — — Net periodic defined benefit costs (credits) $ 1 $ 41 $ 77 $ (5) $ (1) $ 5 Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: Net (loss)/gain allocated at acquisition $ 33 $ — $ — $ (49) $ — $ — Settlement (23) (18) (23) — — — Net (gain) loss 242 42 (221) — (53) (6) Prior service cost (credit) — 3 1 — — 5 Amortization of: Prior service (cost) credit (8) (8) (9) (1) (1) (1) Actuarial gain (loss) (51) (93) (89) 5 1 — Total recognized in OCI and regulatory assets/liabilities 193 (74) (341) (45) (53) (2) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 194 $ (33) $ (264) $ (50) $ (54) $ 3 (a) Settlement charges incurred as a result of the amount of lump sum payment distributions, primarily from the LKE qualified pension plan. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized in accordance with existing regulatory practice. The portion of the settlement attributed to LKE's operations outside of the jurisdiction of the KPSC has been charged to expense.
Schedule of Amounts Recognized in Other Comprehensive Income and Regulatory Assets and Liabilities	For PPL's pension and postretirement benefits, the amounts recognized in OCI and regulatory assets/liabilities for the years ended December 31 were as follows: Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 OCI $ 142 $ (70) $ (428) $ 13 $ (42) $ (12) Regulatory assets/liabilities 51 (4) 87 (58) (11) 10 Total recognized in OCI and $ 193 $ (74) $ (341) $ (45) $ (53) $ (2)
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 PPL Discount rate 5.80 % 3.15 % 5.81 % 3.13 % Rate of compensation increase 3.77 % 3.76 % 3.78 % 3.77 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 PPL Discount rate 3.35 % 2.92 % 3.64 % 3.54 % 2.84 % 3.60 % Rate of compensation increase 3.74 % 3.76 % 3.79 % 2.84 % 3.75 % 3.76 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 6.52 % 6.48 % 6.44 % (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption. The following table provides the assumed health care cost trend rates for the years ended December 31: 2022 2021 2020 PPL Health care cost trend rate assumed for next year – obligations 6.50 % 6.25 % 6.50 % – cost 6.25 % 6.50 % 6.60 % Rate to which the cost trend rate is assumed to decline (the ultimate trend rate) – obligations 5.00 % 5.00 % 5.00 % – cost 5.00 % 5.00 % 5.00 % Year that the rate reaches the ultimate trend rate – obligations 2029 2027 2027 – cost 2027 2027 2024
Schedule of Funded Status of Defined Benefit Plans	The funded status of PPL's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 Change in Benefit Obligation Benefit Obligation, beginning of period $ 3,989 $ 4,251 $ 504 $ 573 Service cost 51 56 7 6 Interest cost 144 121 20 16 Participant contributions — — 9 14 Plan amendments — 2 — — Actuarial (gain) loss (1,026) (88) (114) (50) Acquisition (a) 553 — 163 — Settlements (111) (106) — — Gross benefits paid (267) (247) (55) (55) Benefit Obligation, end of period 3,333 3,989 534 504 Change in Plan Assets Plan assets at fair value, beginning of period 3,887 4,068 367 367 Actual return on plan assets (992) 125 (86) 25 Employer contributions 9 47 19 18 Participant contributions — — 7 11 Acquisition (a) 623 — 160 — Settlements (111) (106) — — Gross benefits paid (267) (247) (50) (54) Plan assets at fair value, end of period 3,149 3,887 417 367 Funded Status, end of period $ (184) $ (102) $ (117) $ (137) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 33 $ 91 $ 9 $ — Current liability (10) (10) (14) (15) Noncurrent liability (207) (183) (112) (122) Net amount recognized, end of period $ (184) $ (102) $ (117) $ (137) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ 14 $ 22 $ 11 $ 12 Net actuarial (gain) loss 827 626 (95) (51) Total $ 841 $ 648 $ (84) $ (39) Total accumulated benefit obligation $ 3,197 $ 3,786 (a) Related to the pension and other postretirement plans assumed for the employees of Rhode Island Energy. See Note 9 for additional details on the acquisition of Narragansett Electric. For PPL's pension and other postretirement benefit plans, the amounts recognized in AOCI and regulatory assets/liabilities at December 31 were as follows: Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 AOCI $ 183 $ 239 $ 13 $ (2) Regulatory assets/liabilities 658 409 (97) (37) Total $ 841 $ 648 $ (84) $ (39)
Schedule of Projected or Accumulated Benefit Obligations In Excess of Plan Assets	The following tables provide information on pension plans where the projected benefit obligation (PBO) or accumulated benefit obligation (ABO) exceed the fair value of plan assets: PBO in excess of plan assets 2022 2021 Projected benefit obligation $ 2,818 $ 193 Fair value of plan assets 2,601 — ABO in excess of plan assets 2022 2021 Accumulated benefit obligation $ 1,720 $ 177 Fair value of plan assets 1,581 —
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2022 2022 2021 Target Asset Growth Portfolio 55 % 55 % 55 % Equity securities 31 % 32 % Debt securities (a) 13 % 13 % Alternative investments 11 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 33 % 35 % Derivatives (b) 10 % 8 % Liquidity Portfolio 2 % 2 % 2 % Total 100 % 100 % 100 % (a) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2022 December 31, 2021 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 306 $ 306 $ — $ — $ 266 $ 266 $ — $ — Equity securities: U.S. Equity 34 34 — — 41 41 — — U.S. Equity fund measured at NAV (a) 574 — — — 754 — — — International equity fund at NAV (a) 403 — — — 511 — — — Commingled debt measured at NAV (a) 526 — — — 677 — — — Debt securities: U.S. Treasury and U.S. government sponsored 153 153 — — 281 280 1 — Corporate 834 — 818 16 1,039 — 1,019 20 Other 14 — 14 — 14 — 14 — Alternative investments: Real estate measured at NAV (a) 60 — — — 69 — — — Private equity measured at NAV (a) 96 — — — 92 — — — Private credit partnerships measured at NAV (a) 6 — — — 2 — — — Hedge funds measured at NAV (a) 194 — — — 236 — — — Derivatives 8 — 8 — 35 — 35 — PPL Services Corporation Master Trust assets, at 3,208 $ 493 $ 840 $ 16 4,017 $ 587 $ 1,069 $ 20 Receivables and payables, net (b) 67 25 401(h) accounts restricted for other (126) (155) Total PPL Services Corporation Master Trust $ 3,149 $ 3,887 (a) In accordance with accounting guidance, certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2022 is as follows: Corporate Balance at beginning of period $ 20 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 2 Purchases, sales and settlements (4) Balance at end of period $ 16 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2021 is as follows: Corporate Balance at beginning of period $ 15 Purchases, sales and settlements 5 Balance at end of period $ 20
Schedules of Target Allocation of U.S. Other Postretirement Benefit Plans VEBA Trust	The asset allocation for the PPL VEBA trusts and the target allocation, by asset class, at December 31 are detailed below. Percentage of plan assets Target Asset 2022 2021 2022 Asset Class Equity securities 45 % 45 % 44 % Debt securities (a) 48 % 52 % 50 % Cash and cash equivalents (b) 7 % 3 % 6 % Total 100 % 100 % 100 % (a) Includes commingled debt funds and debt securities. (b) Includes money market funds.
Schedule of Fair Value of Financial Assets for U.S. Postretirement Benefits	The fair value of assets in the other postretirement benefit plans by asset class and level within the fair value hierarchy was: December 31, 2022 December 31, 2021 Fair Value Measurement Using Fair Value Measurement Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Money market funds $ 19 $ 19 $ — $ — $ 6 $ 6 $ — $ — Equity securities: Large-cap equity fund measure at NAV (a) 71 — — — 96 — — — Commingled debt fund measured at NAV (a) 77 — — — 75 — — — Global equity exchange-traded fund 61 61 — — — — — — Long-term bond exchange-traded fund 65 65 — — — — — — Debt securities: Corporate bonds — — — — 38 — 38 — Total VEBA trust assets, at fair value 293 $ 145 $ — $ — 215 $ 6 $ 38 $ — Receivables and payables, net (b) (2) (3) 401(h) account assets 126 155 Total other postretirement benefit plan assets $ 417 $ 367 (a) In accordance with accounting guidance certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables represent amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Schedule of Expected Cash Flows - U.S. Defined Benefit Plans - Expected Payments and Related Federal Subsidy	The following benefit payments, which reflect expected future service, as appropriate, are expected to be paid by the plans and the following federal subsidy payments are expected to be received by PPL. Other Postretirement Pension Benefit Expected 2023 $ 282 $ 51 $ — 2024 281 50 — 2025 283 49 — 2026 280 48 — 2027 275 48 — 2028-2032 1,327 225 1
Expected Employer Contributions to U.S. Savings Plans	Substantially, all employees of PPL's subsidiaries are eligible to participate in deferred savings plans (401(k)s). Employer contributions to the plans were: 2022 2021 2020 PPL $ 36 $ 29 $ 29 PPL Electric 6 5 6 LG&E 7 7 6 KU 5 5 5
LKE [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedules of Asset Allocation of U.S. Pension Trusts Assets	The asset allocation for the trust and the target allocation by portfolio at December 31 are as follows: Percentage of trust assets 2022 2022 2021 Target Asset Growth Portfolio 55 % 55 % 55 % Equity securities 31 % 32 % Debt securities (a) 13 % 13 % Alternative investments 11 % 10 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 33 % 35 % Derivatives (b) 10 % 8 % Liquidity Portfolio 2 % 2 % 2 % Total 100 % 100 % 100 % (a) Includes commingled debt funds, which PPL treats as debt securities for asset allocation purposes.
Schedule of Fair Value of Financial Assets for U.S. Pension Plan Assets	The fair value of net assets in the Master Trust by asset class and level within the fair value hierarchy was: December 31, 2022 December 31, 2021 Fair Value Measurements Using Fair Value Measurements Using Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Services Corporation Master Trust Cash and cash equivalents $ 306 $ 306 $ — $ — $ 266 $ 266 $ — $ — Equity securities: U.S. Equity 34 34 — — 41 41 — — U.S. Equity fund measured at NAV (a) 574 — — — 754 — — — International equity fund at NAV (a) 403 — — — 511 — — — Commingled debt measured at NAV (a) 526 — — — 677 — — — Debt securities: U.S. Treasury and U.S. government sponsored 153 153 — — 281 280 1 — Corporate 834 — 818 16 1,039 — 1,019 20 Other 14 — 14 — 14 — 14 — Alternative investments: Real estate measured at NAV (a) 60 — — — 69 — — — Private equity measured at NAV (a) 96 — — — 92 — — — Private credit partnerships measured at NAV (a) 6 — — — 2 — — — Hedge funds measured at NAV (a) 194 — — — 236 — — — Derivatives 8 — 8 — 35 — 35 — PPL Services Corporation Master Trust assets, at 3,208 $ 493 $ 840 $ 16 4,017 $ 587 $ 1,069 $ 20 Receivables and payables, net (b) 67 25 401(h) accounts restricted for other (126) (155) Total PPL Services Corporation Master Trust $ 3,149 $ 3,887 (a) In accordance with accounting guidance, certain investments that are measured at fair value using the net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (b) Receivables and payables, net represents amounts for investments sold/purchased but not yet settled along with interest and dividends earned but not yet received.
Reconciliation of U.S. Pension Trust Assets Classified as Level 3 Included in Earnings	A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2022 is as follows: Corporate Balance at beginning of period $ 20 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 2 Purchases, sales and settlements (4) Balance at end of period $ 16 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2021 is as follows: Corporate Balance at beginning of period $ 15 Purchases, sales and settlements 5 Balance at end of period $ 20
PPL Electric Utilities Corp [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to PPL Electric resulted in assets/(liabilities) at December 31 as follows: 2022 2021 Pension $ (34) $ 42 Other postretirement benefits (60) (78)
Louisville Gas And Electric Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Assumptions and Impact of One Point Change on Postretirement Plans	The following weighted-average assumptions were used in the valuation of the benefit obligations at December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2022 2021 PPL Discount rate 5.80 % 3.15 % 5.81 % 3.13 % Rate of compensation increase 3.77 % 3.76 % 3.78 % 3.77 % The following weighted-average assumptions were used to determine the net periodic defined benefit costs for the years ended December 31. Pension Benefits Other Postretirement Benefits 2022 2021 2020 2022 2021 2020 PPL Discount rate 3.35 % 2.92 % 3.64 % 3.54 % 2.84 % 3.60 % Rate of compensation increase 3.74 % 3.76 % 3.79 % 2.84 % 3.75 % 3.76 % Expected return on plan assets 7.25 % 7.25 % 7.25 % 6.52 % 6.48 % 6.44 % (a) The expected long-term rates of return for pension and other postretirement benefits are based on management's projections using a best-estimate of expected returns, volatilities and correlations for each asset class. Each plan's specific current and expected asset allocations are also considered in developing a reasonable return assumption.
Schedule of Funded Status of Defined Benefit Plans	Allocations to LG&E resulted in assets/(liabilities) at December 31 as follows: 2022 2021 Pension $ 41 $ 85 Other postretirement benefits (41) (51)
Kentucky Utilities Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to KU resulted in assets/(liabilities) at December 31 as follows. 2022 2021 Pension $ 44 $ 75 Other postretirement benefits (9) (6)

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2022
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2022 and 2021, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2022 Trimble County Unit 1 75.00 % $ 455 $ 94 $ 1 Trimble County Unit 2 75.00 % 1,372 276 148 December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 LG&E December 31, 2022 E.W. Brown Units 6-7 38.00 % $ 53 $ 25 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 27 — Trimble County Unit 1 75.00 % 455 94 1 Trimble County Unit 2 14.25 % 384 66 78 Trimble County Units 5-6 29.00 % 36 16 — Trimble County Units 7-10 37.00 % 81 36 — Cane Run Unit 7 22.00 % 126 21 2 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2022 E.W. Brown Units 6-7 62.00 % $ 87 $ 42 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 23 — Trimble County Unit 2 60.75 % 987 210 70 Trimble County Units 5-6 71.00 % 84 38 — Trimble County Units 7-10 63.00 % 133 61 — Cane Run Unit 7 78.00 % 446 77 6 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — —
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2022 and 2021, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2022 Trimble County Unit 1 75.00 % $ 455 $ 94 $ 1 Trimble County Unit 2 75.00 % 1,372 276 148 December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 LG&E December 31, 2022 E.W. Brown Units 6-7 38.00 % $ 53 $ 25 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 27 — Trimble County Unit 1 75.00 % 455 94 1 Trimble County Unit 2 14.25 % 384 66 78 Trimble County Units 5-6 29.00 % 36 16 — Trimble County Units 7-10 37.00 % 81 36 — Cane Run Unit 7 22.00 % 126 21 2 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2022 E.W. Brown Units 6-7 62.00 % $ 87 $ 42 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 23 — Trimble County Unit 2 60.75 % 987 210 70 Trimble County Units 5-6 71.00 % 84 38 — Trimble County Units 7-10 63.00 % 133 61 — Cane Run Unit 7 78.00 % 446 77 6 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — —
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2022 and 2021, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2022 Trimble County Unit 1 75.00 % $ 455 $ 94 $ 1 Trimble County Unit 2 75.00 % 1,372 276 148 December 31, 2021 Trimble County Unit 1 75.00 % $ 457 $ 79 $ — Trimble County Unit 2 75.00 % 1,360 247 121 LG&E December 31, 2022 E.W. Brown Units 6-7 38.00 % $ 53 $ 25 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 27 — Trimble County Unit 1 75.00 % 455 94 1 Trimble County Unit 2 14.25 % 384 66 78 Trimble County Units 5-6 29.00 % 36 16 — Trimble County Units 7-10 37.00 % 81 36 — Cane Run Unit 7 22.00 % 126 21 2 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — December 31, 2021 E.W. Brown Units 6-7 38.00 % $ 53 $ 24 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 51 25 — Trimble County Unit 1 75.00 % 457 79 — Trimble County Unit 2 14.25 % 379 57 64 Trimble County Units 5-6 29.00 % 36 15 — Trimble County Units 7-10 37.00 % 81 34 — Cane Run Unit 7 22.00 % 125 19 — E.W. Brown Solar Unit 39.00 % 10 2 — Solar Share 44.00 % 2 — — KU December 31, 2022 E.W. Brown Units 6-7 62.00 % $ 87 $ 42 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 23 — Trimble County Unit 2 60.75 % 987 210 70 Trimble County Units 5-6 71.00 % 84 38 — Trimble County Units 7-10 63.00 % 133 61 — Cane Run Unit 7 78.00 % 446 77 6 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — December 31, 2021 E.W. Brown Units 6-7 62.00 % $ 88 $ 40 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 45 22 — Trimble County Unit 2 60.75 % 981 190 57 Trimble County Units 5-6 71.00 % 84 36 — Trimble County Units 7-10 63.00 % 133 57 — Cane Run Unit 7 78.00 % 444 70 — E.W. Brown Solar Unit 61.00 % 16 4 — Solar Share 56.00 % 3 — —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2022
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2027 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2030 LG&E KU Total 2023 $ 24 $ 10 $ 34 2024 22 10 32 2025 22 10 32 2026 22 10 32 2027 22 10 32 Thereafter 184 81 265 Total $ 296 $ 131 $ 427 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2022 2021 2020 LG&E $ 21 $ 13 $ 12 KU 9 6 6 Total $ 30 $ 19 $ 18
Guarantees	The table below details guarantees provided as of December 31, 2022. Exposure at December 31, 2022 Expiration PPL Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business £ 50 (a) 2028 PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings $ 148 (b) 2028 PPL guarantee of Safari payment obligations under certain PPAs related to the sale of Safari Holdings 55 (c) Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings 140 (d) Various LG&E and KU LG&E and KU obligation of shortfall related to OVEC (e) (a) PPL WPD Limited entered into a Tax Deed dated June 9, 2021 in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million. (b) PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million. The estimated maximum exposure of this guarantee is $148 million. (c) PPL guaranteed the payment obligations of Safari under certain PPAs executed by Safari. Aspen Power is expected to replace these guarantees and retain liability for any payments made by PPL or claims against PPL under any guarantee that is not replaced. The estimated maximum exposure of this guarantee is $55 million. (d) Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. Expiration of these indemnifications range from 18 months to 6 years from the date of the closing of the transaction, and PPL’s aggregate liability for these claims will not exceed $140 million subject to certain adjustments plus the support obligations provided by PPL under sale-leaseback financings and PPAs that will be replaced by Aspen Power. (e) Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $89 million at December 31, 2022, consisting of LG&E's share of $62 million and KU's share of $27 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" above for additional information on the OVEC power purchase contract.
Louisville Gas And Electric Co [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2027 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2030 LG&E KU Total 2023 $ 24 $ 10 $ 34 2024 22 10 32 2025 22 10 32 2026 22 10 32 2027 22 10 32 Thereafter 184 81 265 Total $ 296 $ 131 $ 427 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2022 2021 2020 LG&E $ 21 $ 13 $ 12 KU 9 6 6 Total $ 30 $ 19 $ 18
Kentucky Utilities Co [Member]
Commitments And Contingencies [Line Items]
Unrecorded Unconditional Purchase Obligations	LG&E and KU enter into purchase contracts to supply the coal and natural gas requirements for generation facilities and LG&E's retail natural gas supply operations. These contracts include the following commitments: Contract Type Maximum Maturity Natural Gas Fuel 2024 Natural Gas Retail Supply 2023 Coal 2027 Coal Transportation and Fleeting Services 2027 Natural Gas Transportation 2030 LG&E KU Total 2023 $ 24 $ 10 $ 34 2024 22 10 32 2025 22 10 32 2026 22 10 32 2027 22 10 32 Thereafter 184 81 265 Total $ 296 $ 131 $ 427 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2022 2021 2020 LG&E $ 21 $ 13 $ 12 KU 9 6 6 Total $ 30 $ 19 $ 18

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2022
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2022 2021 2020 PPL Electric from PPL Services $ 241 $ 54 $ 50 PPL Electric from PPL EU Services — 222 176 LG&E from LKS 153 169 170 LG&E from PPL Services 13 3 2 KU from LKS 171 179 180 KU from PPL Services 14 3 2
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2022 2021 2020 PPL Electric from PPL Services $ 241 $ 54 $ 50 PPL Electric from PPL EU Services — 222 176 LG&E from LKS 153 169 170 LG&E from PPL Services 13 3 2 KU from LKS 171 179 180 KU from PPL Services 14 3 2
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services, PPL EU Services and LKS charged the following amounts for the years ended December 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. 2022 2021 2020 PPL Electric from PPL Services $ 241 $ 54 $ 50 PPL Electric from PPL EU Services — 222 176 LG&E from LKS 153 169 170 LG&E from PPL Services 13 3 2 KU from LKS 171 179 180 KU from PPL Services 14 3 2

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2022
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2022 2021 2020 Defined benefit plans - non-service credits (Note 12) $ 47 $ 21 $ (2) Interest income 4 12 9 AFUDC - equity component 22 18 20 Charitable contributions (14) (14) (3) Miscellaneous (5) (22) (22) Other Income (Expense) - net $ 54 $ 15 $ 2
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	(PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2022 2021 2020 Defined benefit plans - non-service credits (Note 12) $ 15 $ 9 $ 4 Interest income 3 — 2 AFUDC - equity component 16 18 19 Charitable contributions (3) (3) (3) Miscellaneous (1) (3) (4) Other Income (Expense) - net $ 30 $ 21 $ 18

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2022
Fair Value [Line Items]
Fair Value of Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were: December 31, 2022 December 31, 2021 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 356 $ 356 $ — $ — $ 3,571 $ 3,571 $ — $ — Restricted cash and cash equivalents (a) 1 1 — — 1 1 — — Total Cash, Cash Equivalents and Restricted Cash (b) 357 357 — — 3,572 3,572 — — Special use funds (a): Money market fund 1 1 — — 2 2 — — Commingled debt fund measured at NAV (c) 13 — — — 22 — — — Commingled equity fund measured at NAV (c) 11 — — — 21 — — — Total special use funds 25 1 — — 45 2 — — Price risk management assets (d): Gas contracts 25 — 25 — — — — — Total assets $ 407 $ 358 $ 25 $ — $ 3,617 $ 3,574 $ — $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 7 $ — $ 7 $ — $ 18 $ — $ 18 $ — Gas contracts 66 — 10 56 — — — — Total price risk management liabilities $ 73 $ — $ 17 $ 56 $ 18 $ — $ 18 $ — December 31, 2022 December 31, 2021 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Electric Assets Cash and cash equivalents $ 25 $ 25 $ — $ — $ 21 $ 21 $ — $ — Total assets $ 25 $ 25 $ — $ — $ 21 $ 21 $ — $ — LG&E Assets Cash and cash equivalents $ 93 $ 93 $ — $ — $ 9 $ 9 $ — $ — Total assets $ 93 $ 93 $ — $ — $ 9 $ 9 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 7 $ — $ 7 $ — $ 18 $ — $ 18 $ — Total price risk management liabilities $ 7 $ — $ 7 $ — $ 18 $ — $ 18 $ — KU Assets Cash and cash equivalents $ 21 $ 21 $ — $ — $ 13 $ 13 $ — $ — Total assets $ 21 $ 21 $ — $ — $ 13 $ 13 $ — $ — (a) Current portion is included in "Other current assets" and long-term portion is included in "Other noncurrent assets" on the Balance Sheets. (b) Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows. (c) In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the statement of financial position. (d) Current portion is included in "Other current liabilities" and noncurrent portion is included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets.
Fair Value of Financial Instruments Not Recorded at Fair Value - Other	The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. December 31, 2022 December 31, 2021 Carrying Fair Value Carrying Fair Value PPL $ 13,243 $ 12,239 $ 11,140 $ 12,955 PPL Electric 4,486 4,259 4,484 5,272 LG&E 2,307 2,128 2,006 2,363 KU 2,920 2,616 2,618 3,120 (a) Amounts are net of debt issuance costs.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	A reconciliation of net assets and liabilities classified as Level 3 for the year ended December 31 is as follows: Gas Contracts 2022 Balance at beginning of period $ — Total realized/unrealized gains (losses): Included in regulatory assets 56 Balance at end of period $ 56

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and location of derivative instruments recorded on the Balance Sheets: December 31, 2022 December 31, 2021 Derivatives designated as Derivatives not designated Derivatives designated as Derivatives not designated Assets Liabilities Assets Liabilities Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) $ — $ — $ — $ 1 $ — $ — $ — $ 1 Gas contracts — — 20 62 — — — — Total current — — 20 63 — — — 1 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 6 — — — 17 Gas contracts — — 5 4 — — — — Total noncurrent — — 5 10 — — — 17 Total derivatives $ — $ — $ 25 $ 73 $ — $ — $ — $ 18 (a) Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. (b) Excludes accrued interest, if applicable.
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities: Derivative Derivative Gain Location of Gain (Loss) Gain (Loss) Reclassified 2022 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) 2021 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ 11 Income (Loss) from Discontinued operations (net of taxes) (2) Cross-currency swaps (50) Income (Loss) from Discontinued operations (net of taxes) (39) Total $ (50) $ (30) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 2020 Cash Flow Hedges: Interest rate swaps $ (9) Interest Expense $ (8) Income(Loss) from Discontinued operations(net of taxes) (2) Cross-currency swaps (15) Income (Loss) from Discontinued operations (net of taxes) (22) Total $ (24) $ (32) Net Investment Hedges: Foreign currency contracts in Discontinued operations $ 1 Derivatives Not Designated as Location of Gain (Loss) Recognized in 2022 2021 2020 Foreign currency contracts Income (Loss) from Discontinued Operations (net of taxes) $ — $ (266) $ (98) Interest rate swaps Interest Expense (2) (2) (5) Gas contracts Energy Purchases 41 — — Total $ 39 $ (268) $ (103) Derivatives Not Designated as Location of Gain (Loss) Recognized as 2022 2021 2020 Gas contracts Regulatory assets - current $ 39 $ — $ — Interest rate swaps Regulatory assets - noncurrent 11 5 (2) Total $ 50 $ 5 $ (2) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2022: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 513 $ 54 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (3) — Cross-currency swaps: Hedged items — — Amount of gain (loss) reclassified from AOCI to income — — The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2021: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 918 $ (1,498) The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income 11 (2) Cross-currency swaps: Hedged items — 39 Amount of gain (loss) reclassified from AOCI to income — (39) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2020: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Income (Loss) from Discontinued Operations (net of income taxes) Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 634 $ 829 The effects of cash flow hedges: Gain (Loss) on cash flow hedging relationships: Interest rate swaps: Amount of gain (loss) reclassified from AOCI to income (8) (2) Cross-currency swaps: Hedged items — 22 Amount of gain (loss) reclassified from AOCI to income — (22)
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7 December 31, 2021 Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18
Louisville Gas And Electric Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Fair Value and Balance Sheet Location of Derivative Instruments	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments: December 31, 2022 December 31, 2021 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 1 Total current — 1 — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 6 — 17 Total noncurrent — 6 — 17 Total derivatives $ — $ 7 $ — $ 18
Pre-tax Gain (Loss) on Derivative Instruments Recognized in Income or on the Balance Sheet	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets: Derivative Instruments Location of Gain (Loss) 2022 2021 2020 Interest rate swaps Interest Expense $ (2) $ (2) $ (5) Derivative Instruments Location of Gain (Loss) 2022 2021 2020 Interest rate swaps Regulatory assets - noncurrent $ 11 $ 5 $ (2)
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7 December 31, 2021 Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18
Kentucky Utilities Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7 December 31, 2021 Derivatives PPL $ — $ — $ — $ — $ 18 $ — $ — $ 18 LG&E — — — — 18 — — 18

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2022
Goodwill and Other Intangible Assets [Line Items]
Goodwill Rollforward	The changes in the carrying amount of goodwill by segment were: Kentucky Rhode Island Regulated Corporate and Total 2022 2021 2022 2021 2022 2021 2022 2021 Balance at beginning of period (a) $ 662 $ 662 $ — $ — $ 53 $ 53 $ 715 $ 715 Goodwill recognized during the period (b) — — 725 — 861 — 1,586 — Sale of Safari Holdings (c) — — — — (53) — (53) — Total $ 662 $ 662 $ 725 $ — $ 861 $ 53 $ 2,248 $ 715 (a) There were no accumulated impairment losses related to goodwill. (b) Recognized as a result of the acquisition of RIE. See Note 9 for additional information. (c) See Note 9 for additional information.
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 125 $ 99 $ 125 $ 90 Renewable Energy Credits 14 — — — Land rights and easements 407 138 406 135 Licenses and other 2 1 20 6 Total subject to amortization 548 238 551 231 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Other — — 6 — Total not subject to amortization due to indefinite life 17 — 23 — Total $ 565 $ 238 $ 574 $ 231 (a) Gross carrying amount in 2022 and 2021 includes the fair value at the acquisition date of the OVEC power purchase contract with terms favorable to market recognized as a result of the 2010 acquisition of LKE by PPL.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2022 2021 2020 Intangible assets with no regulatory offset $ 5 $ 9 $ 7 Intangible assets with regulatory offset 9 8 8 Total $ 14 $ 17 $ 15
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with no regulatory offset $ 5 $ 5 $ 5 $ 4 $ 4 Intangible assets with regulatory offset 9 8 8 2 — Total $ 14 $ 13 $ 13 $ 6 $ 4
PPL Electric Utilities Corp [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 385 $ 134 $ 382 $ 130 Licenses and other 2 1 2 1 Total subject to amortization 387 135 384 131 Not subject to amortization due to indefinite life: Land rights and easements 17 — 17 — Total $ 404 $ 135 $ 401 $ 131
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2022 2021 2020 Intangible assets with no regulatory offset $ 4 $ 4 $ 4
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4
Louisville Gas And Electric Co [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 1 $ 7 $ 1 OVEC power purchase agreement (a) 86 68 86 62 Total subject to amortization $ 93 $ 69 $ 93 $ 63 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2022 2021 2020 Intangible assets with regulatory offset $ 6 $ 5 $ 6
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with regulatory offset $ 6 $ 6 $ 6 $ 1 $ —
Kentucky Utilities Co [Member]
Goodwill and Other Intangible Assets [Line Items]
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2022 December 31, 2021 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 16 $ 3 $ 16 $ 4 OVEC power purchase agreement (a) 39 31 39 28 Total subject to amortization $ 55 $ 34 $ 55 $ 32 (a) Gross carrying amount represents the fair value at the acquisition date of the OVEC power purchase contract recognized as a result of the 2010 acquisition by PPL. An offsetting regulatory liability was recorded related to this contract, which is being amortized over the same period as the intangible asset, eliminating any income statement impact. See Note 7 for additional information.
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2022 2021 2020 Intangible assets with no regulatory offset $ — $ 1 $ — Intangible assets with regulatory offset 3 3 2
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2023 2024 2025 2026 2027 Intangible assets with regulatory offset $ 3 $ 2 $ 2 $ 1 $ —

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2022 2021 2022 2021 2022 2021 ARO at beginning of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115 Acquisition of RIE (a) 10 — — — — — Accretion 6 16 3 5 3 11 Obligations incurred 2 — 2 — — — Changes in estimated timing or cost 15 56 12 40 4 16 Obligations settled (45) (65) (15) (28) (30) (37) ARO at end of period $ 177 $ 189 $ 86 $ 84 $ 82 $ 105
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2022 2021 2022 2021 2022 2021 ARO at beginning of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115 Acquisition of RIE (a) 10 — — — — — Accretion 6 16 3 5 3 11 Obligations incurred 2 — 2 — — — Changes in estimated timing or cost 15 56 12 40 4 16 Obligations settled (45) (65) (15) (28) (30) (37) ARO at end of period $ 177 $ 189 $ 86 $ 84 $ 82 $ 105
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows: PPL LG&E KU 2022 2021 2022 2021 2022 2021 ARO at beginning of period $ 189 $ 182 $ 84 $ 67 $ 105 $ 115 Acquisition of RIE (a) 10 — — — — — Accretion 6 16 3 5 3 11 Obligations incurred 2 — 2 — — — Changes in estimated timing or cost 15 56 12 40 4 16 Obligations settled (45) (65) (15) (28) (30) (37) ARO at end of period $ 177 $ 189 $ 86 $ 84 $ 82 $ 105

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the years ended December 31 were as follows: Defined benefit plans Foreign Unrealized gains (losses) on Equity Prior Actuarial Total PPL December 31, 2019 $ (1,425) $ (5) $ — $ (18) $ (2,910) $ (4,358) Amounts arising during the year 267 (19) — (1) (341) (94) Reclassifications from AOCI — 24 — 3 205 232 Net OCI during the year 267 5 — 2 (136) 138 December 31, 2020 $ (1,158) $ — $ — $ (16) $ (3,046) $ (4,220) Amounts arising during the year 372 (39) — — (1) 332 Reclassifications from AOCI — 25 — 2 126 153 Reclassifications from AOCI due to the sale of the U.K. utility business (Note 9) 786 15 — 8 2,769 3,578 Net OCI during the year 1,158 1 — 10 2,894 4,063 December 31, 2021 $ — $ 1 $ — $ (6) $ (152) $ (157) Defined benefit plans Foreign Unrealized gains (losses) on Equity Prior Actuarial Total Amounts arising during the year — — 2 (1) 11 12 Reclassifications from AOCI — 2 — 2 17 21 Net OCI during the year — 2 2 1 28 33 December 31, 2022 $ — $ 3 $ 2 $ (5) $ (124) $ (124)
Reclassification out of Other Comprehensive Income (Loss)	The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2022, 2021 and 2020. The defined benefit plan components of AOCI are not reflected in their entirety in the statement of income; rather, they are included in the computation of net periodic defined benefit costs (credits) and subject to capitalization. See Note 12 for additional information. PPL Details about AOCI 2022 2021 2020 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (3) $ 11 $ (8) Interest Expense — (2) (2) Income (Loss) from Discontinued Operations (net of income taxes) Cross-currency swaps — (39) (22) Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax (3) (30) (32) Income Taxes 1 5 8 Total After-tax (2) (25) (24) Defined benefit plans Prior service costs (3) (3) (4) Net actuarial loss (24) (159) (256) Total Pre-tax (27) (162) (260) Income Taxes 8 34 52 Total After-tax (19) (128) (208) Sale of the U.K. utility business (Note 9) Foreign currency translation adjustments — (646) — Income (Loss) from Discontinued Operations (net of income taxes) Qualifying derivatives — (15) — Income (Loss) from Discontinued Operations (net of income taxes) Defined benefit plans — (3,577) — Income (Loss) from Discontinued Operations (net of income taxes) Total Pre-tax — (4,238) — Income Taxes — 660 — Total After-tax — (3,578) — Total reclassifications during the year $ (21) $ (3,731) $ (232)

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Other	$ 150	$ 58
Cumulative Effect, Period of Adoption, Adjustment
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount		2
Allowance For Doubtful Accounts [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	95	69	$ 73	$ 58
Additions charged to income	78	26	28
Deductions	52	30	13
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount			73
Other	36	32	30
PPL Electric Utilities Corp [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Other	12	22
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
SEC Schedule, 12-09, Valuation Allowances and Reserves, Amount	33	35	41	$ 30
Additions charged to income	27	13	19
Deductions	29	19	8
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount			$ 41
Other	$ 3	$ 3

Accounting Policies (Details)

Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Utility Revenue (Details) [Abstract]
Operating Revenues	$ 7,902	$ 5,783	$ 5,474
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	356	3,571
Total Cash, Cash Equivalents and Restricted Cash	357	3,572	443	$ 660
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 7	6	$ 7
Discount Rate Change For United Kingdom Pension Plans Numeric [Abstract]
Percentage in excess of gains and losses equal to the plan's projected benefit obligation to use accelerated amortization	30%
Minimum percentage of gains and losses under the accelerated method that are amortized on a straight line basis	10%
Maximum percentage of gains and losses under the accelerated that are amortized on a straight line basis	30%
Income Taxes [Abstract]
Minimum percentage to be attained of likelihood of uncertain tax position being realized	50%
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 443	322
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	2,248	716
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	125	90
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	91	54
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 227	$ 178
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	3.21%	3.61%	3.53%
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 69	$ 73	$ 58
Additions charged to income	78	26	28
Deductions	52	30	13
Balance at end of period	95	69	73
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	3,030	2,402	2,331
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	25	21
Total Cash, Cash Equivalents and Restricted Cash	25	21	40	264
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	5	6	$ 7
Income Taxes [Abstract]
Intercompany tax receivables (payables)	2	(4)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	69	61
PPL Electric Utilities Corp [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	0	0
PPL Electric Utilities Corp [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	0	0
PPL Electric Utilities Corp [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 69	$ 61
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	2.75%	3.05%	2.99%
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 35	$ 41	$ 30
Additions charged to income	27	13	19
Deductions	29	19	8
Balance at end of period	33	35	41
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,798	1,569	1,456
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	93	9	$ 7	15
Income Taxes [Abstract]
Intercompany tax receivables (payables)	(6)	4
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	166	137
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	389	389
Louisville Gas And Electric Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	44	32
Louisville Gas And Electric Co [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	68	54
Louisville Gas And Electric Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 54	$ 51
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.16%	3.99%	4%
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 3	$ 3	$ 1
Additions charged to income	6	4	4
Deductions	5	4	2
Balance at end of period	4	3	3
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	2,074	1,826	1,690
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	21	13	$ 22	$ 12
Income Taxes [Abstract]
Intercompany tax receivables (payables)	4	1
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	167	124
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	607	607
Kentucky Utilities Co [Member] | Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	81	58
Kentucky Utilities Co [Member] | Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	0	0
Kentucky Utilities Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 86	$ 66
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.01%	4.17%	4%
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 3	$ 2	$ 1
Additions charged to income	6	8	4
Deductions	6	7	3
Balance at end of period	$ 3	$ 3	$ 2

New Accounting Guidance Adopted

New Accounting Guidance Adopted (Details) $ in Millions	Dec. 31, 2022 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 60
Lease Liability - Current	22
Lease Liability - Noncurrent	42
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	13
Lease Liability - Current	6
Lease Liability - Noncurrent	9
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	19
Lease Liability - Current	8
Lease Liability - Noncurrent	$ 12

Segment and Related Informati_3

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Statement Data
Operating Revenues from external customers	$ 7,902	$ 5,783	$ 5,474
Depreciation	1,181	1,082	1,022
Amortization	52	39	58
Interest Expense	513	918	634
Income Before Income Taxes	915	521	954
Income Taxes	201	503	314
Deferred income taxes and investment tax credits	179	87	169
Net income (loss)	756	(1,480)	1,469
Cash Flow Data
Expenditures for long-lived assets	2,158	1,979	2,278
Balance Sheet Data
Total Assets	37,837	33,223
Kentucky Regulated [Member]
Income Statement Data
Operating Revenues from external customers	3,811	3,348	3,106
Depreciation	685	647	606
Amortization	23	15	19
Interest Expense	262	249	300
Income Before Income Taxes	621	562	516
Income Taxes	114	94	98
Deferred income taxes and investment tax credits	6	272	64
Net income (loss)	507	468	418
Cash Flow Data
Expenditures for long-lived assets	917	1,026	966
Balance Sheet Data
Total Assets	16,904	16,360
Segment Information (Numeric) [Abstract]
Financing Costs Allocated to Segment, Net of Tax			32
Income Taxes Allocated to Segment			8
Pennsylvania Regulated [Member]
Income Statement Data
Operating Revenues from external customers	3,030	2,402	2,330
Depreciation	393	424	403
Amortization	22	19	26
Interest Expense	171	162	172
Income Before Income Taxes	699	599	664
Income Taxes	174	154	167
Deferred income taxes and investment tax credits	91	79	82
Net income (loss)	525	445	497
Cash Flow Data
Expenditures for long-lived assets	889	904	1,154
Balance Sheet Data
Total Assets	13,565	13,336
Corporate And Other [Member]
Income Statement Data
Operating Revenues from external customers	23	33	38
Depreciation	11	11	13
Amortization	5	5	13
Interest Expense	41	507	162
Income Before Income Taxes	(347)	(640)	(226)
Income Taxes	(73)	255	49
Deferred income taxes and investment tax credits	43	(264)	23
Net income (loss)	(274)	(895)	(275)
Cash Flow Data
Expenditures for long-lived assets	84	49	158
Balance Sheet Data
Total Assets	1,287	3,527
Discontinued Operations Segment
Income Statement Data
Net income (loss)	42	(1,498)	829
Rhode Island Regulated
Income Statement Data
Operating Revenues from external customers	1,038	0	0
Depreciation	92	0	0
Amortization	2	0	0
Interest Expense	39	0	0
Income Before Income Taxes	(58)	0	0
Income Taxes	(14)	0	0
Deferred income taxes and investment tax credits	39	0	0
Net income (loss)	(44)	0	0
Cash Flow Data
Expenditures for long-lived assets	268	0	$ 0
Balance Sheet Data
Total Assets	$ 6,081	$ 0

Segment and Related Informati_4

Segment and Related Information (Geographic Data) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) Integer	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 7,902	$ 5,783	$ 5,474
Number of reportable segments	3
PPL Electric Utilities Corp [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 3,030	2,402	2,331
Number of reportable segments	1
Number of operating segments	2
LOUISVILLE GAS And ELECTRIC CO [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 1,798	1,569	1,456
Number of reportable segments	1
Number of operating segments	1
Kentucky Utilities Co [Member]
Revenues from External Customers and Long-Lived Assets [Line Items]
Revenues from external customers | $	$ 2,074	$ 1,826	$ 1,690
Number of reportable segments	1
Number of operating segments	1

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	7 Months Ended	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2022 USD ($) Days	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 7,902	$ 5,783	$ 5,474
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		(92)	77	(24)
Other Revenue		(24)	(22)	(21)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		7,786	5,838	5,429
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		70	22	25
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	$ 34	34	42	40	$ 37
Contract with Customer, Liability, Revenue Recognized		$ 25	24	22
PPL Electric [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days		21
Contract with Customer, Asset and Liability [Abstract]
Amortization of Revenue Reserve for ROE Challenge		$ 74
KU [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days		22
LGE [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days		22
Rhode Island Energy
Revenue from contracts with customers [Line Items]
Operating Revenues	1,038
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable Forgiven, AR Reserve		$ 23
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		3,583	2,715	2,585
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,660	1,278	1,185
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		756	639	582
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		878	386	347
Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		28	24	20
Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		97	66	40
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		784	730	670
Pennsylvania Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		3,030	2,402	2,330
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,960	2,482	2,316
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,647	1,299	1,238
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		491	350	314
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		85	53	44
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		54	50	50
Pennsylvania Regulated [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Pennsylvania Regulated [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Pennsylvania Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		683	730	670
Kentucky Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		3,811	3,348	3,106
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		3,815	3,325	3,077
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,637	1,416	1,347
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,068	928	871
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		662	586	538
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		323	305	261
Kentucky Regulated [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		28	24	20
Kentucky Regulated [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		97	66	40
Kentucky Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Corporate And Other [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		23	33	38
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		23	31	36
Corporate And Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Corporate And Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Corporate And Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Corporate And Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		23	31	36
Corporate And Other [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Corporate And Other [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Corporate And Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Rhode Island Regulated
Revenue from contracts with customers [Line Items]
Operating Revenues		1,038	0	0
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		988	0	0
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		299	0	0
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		101	0	0
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		9	0	0
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		478	0	0
Rhode Island Regulated | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Rhode Island Regulated | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Rhode Island Regulated | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		101	0	0
PPL Electric Utilities Corp [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 3,030	2,402	2,331
Number Of Days Due From Invoice Date | Days		21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		$ (56)	83	(12)
Other Revenue		(14)	(3)	(3)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,960	2,482	2,316
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		21	10	17
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	23	23	25	23	21
Contract with Customer, Liability, Revenue Recognized		12	11	9
Revenue Reserve for ROE Challenge			78
Amortization of Revenue Reserve for ROE Challenge		74
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,647	1,299	1,238
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		491	350	314
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		85	53	44
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		54	50	50
PPL Electric Utilities Corp [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
PPL Electric Utilities Corp [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		683	730	670
Louisville Gas And Electric Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 1,798	1,569	1,456
Number Of Days Due From Invoice Date | Days		22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		$ 9	(3)	(8)
Other Revenue		(6)	(8)	(7)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,801	1,558	1,441
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		6	4	4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	5	5	6	5	5
Contract with Customer, Liability, Revenue Recognized		6	5	5
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		835	711	676
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		551	473	444
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		199	180	173
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		141	145	114
Louisville Gas And Electric Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Louisville Gas And Electric Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		75	49	34
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		0	0	0
Kentucky Utilities Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 2,074	1,826	1,690
Number Of Days Due From Invoice Date | Days		22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		$ 5	(3)	(4)
Other Revenue		(4)	(9)	(10)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,075	1,814	1,676
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		6	8	4
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	$ 6	6	6	6	$ 4
Contract with Customer, Liability, Revenue Recognized		6	6	4
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		802	705	671
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		517	455	427
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		463	406	365
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		182	160	147
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		28	24	20
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		83	64	46
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		$ 0	$ 0	$ 0

Disaggregation of Revenue (Deta

Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 7,786	$ 5,838	$ 5,429
Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,960	2,482	2,316
Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	3,815	3,325	3,077
Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	23	31	36
Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	988	0	0
Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	3,583	2,715	2,585
Residential [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,647	1,299	1,238
Residential [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,637	1,416	1,347
Residential [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Residential [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	299	0	0
Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,660	1,278	1,185
Commercial [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	491	350	314
Commercial [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,068	928	871
Commercial [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Commercial [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	101	0	0
Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	756	639	582
Industrial [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	85	53	44
Industrial [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	662	586	538
Industrial [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Industrial [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	9	0	0
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	878	386	347
Other [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	54	50	50
Other [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	323	305	261
Other [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	23	31	36
Other [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	478	0	0
Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	28	24	20
Wholesale Municipal [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Municipal [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	28	24	20
Wholesale Municipal [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Municipal [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	97	66	40
Wholesale Other [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Other [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	97	66	40
Wholesale Other [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Wholesale Other [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	784	730	670
Transmission [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	683	730	670
Transmission [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Transmission [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
Transmission [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	101	0	0
PPL Electric Utilities Corp [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,960	2,482	2,316
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,647	1,299	1,238
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	491	350	314
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	85	53	44
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	54	50	50
PPL Electric Utilities Corp [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	683	730	670
Kentucky Utilities Co [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,075	1,814	1,676
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	802	705	671
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	517	455	427
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	463	406	365
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	182	160	147
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	28	24	20
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	83	64	46
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
LOUISVILLE GAS And ELECTRIC CO [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,801	1,558	1,441
LOUISVILLE GAS And ELECTRIC CO [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	835	711	676
LOUISVILLE GAS And ELECTRIC CO [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	551	473	444
LOUISVILLE GAS And ELECTRIC CO [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	199	180	173
LOUISVILLE GAS And ELECTRIC CO [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	141	145	114
LOUISVILLE GAS And ELECTRIC CO [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	0	0	0
LOUISVILLE GAS And ELECTRIC CO [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	75	49	34
LOUISVILLE GAS And ELECTRIC CO [Member] | Transmission [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 0	$ 0	$ 0

Preferred Securities (Details)

Preferred Securities (Details) - $ / shares	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	10,000,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Preferred Stock [Member] | Rhode Island Energy
Preferred Securities [Line Items]
Preferred Stock, Shares Outstanding	3,000,000
PPL Electric Utilities Corp [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	20,629,936
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Louisville Gas And Electric Co [Member] | Preferred Stock [Member]
Preferred Securities [Line Items]
Shares authorized	1,720,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Par value of stock	$ 25
Louisville Gas And Electric Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	6,750,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Kentucky Utilities Co [Member] | Preferred Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	5,300,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0
Kentucky Utilities Co [Member] | Preference Stock Without Par Value [Member]
Preferred Securities [Line Items]
Shares authorized	2,000,000
Preferred Stock, Shares Issued	0	0	0
Preferred Stock, Shares Outstanding	0	0	0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income (Numerator)
Net income (loss)	$ 756	$ (1,480)	$ 1,469
Less amounts allocated to participating securities	1	0	1
Net Income (Loss) Available to Common Stockholders, Basic	755	(1,480)	1,468
Net Income (Loss) from Continuing Operations Available to Common Shareholders, Diluted	713	18	639
Net income available to PPL common shareowners - Basic	713	18	639
Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Diluted	42	(1,498)	829
Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Basic	42	(1,498)	829
Net income available to PPL common shareowners - Diluted	$ 755	$ (1,480)	$ 1,468
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)	736,027	762,902	768,590
Add incremental non-participating securities:
Share-based payment awards (in shares)	875	1,917	794
Weighted-average shares - Diluted EPS (in shares)	736,902	764,819	769,384
Income from Continuing Operations After Income Taxes, Per Basic Share	$ 0.97	$ 0.03	$ 0.83
Basic EPS - Available to PPL common shareowners:
Net Income (Loss)	1.03	(1.93)	1.91
Income from Continuing Operations After Income Taxes, Per Diluted Share	0.96	0.03	0.83
Income (Loss) from Discontinued Operations (net of income taxes), Per Diluted Shares	0.06	(1.96)	1.08
Diluted EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 1.02	$ (1.93)	$ 1.91
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	124	983
Income (Loss) from Continuing Operations After Income Taxes	$ 714	$ 18	$ 640
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	93	1,783	452

Income and Other Taxes (Tax Ref

Income and Other Taxes (Tax Reform) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 201	$ 503	$ 314
Net Increase in Regulatory Liability	119	(52)	63
Deferred Tax Liabilities, Net	3,000	3,139
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, U.K. Finance Act 2021, Amount		383
Deferred Tax Assets, Valuation Allowance, Increase due to Loss on Extinguishment of Debt	31	31
PPL Electric Utilities Corp [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	174	154	167
Net Increase in Regulatory Liability	59	(96)	40
Deferred Tax Liabilities, Net	1,514	1,668
Louisville Gas And Electric Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	63	54	62
Net Increase in Regulatory Liability	(17)	23	0
Deferred Tax Liabilities, Net	771	751
Kentucky Utilities Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	76	67	63
Net Increase in Regulatory Liability	19	22	$ 26
Deferred Tax Liabilities, Net	$ 896	$ 865

Income and Other Taxes (Deferre

Income and Other Taxes (Deferred Tax Assets and Liabilities and Loss Carryforwards) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	$ 915	$ 521	$ 954
Deferred Tax Assets
Deferred investment tax credits	29	30
Regulatory liabilities	88	94
Income taxes due to customer	448	422
Accrued pension and postretirement costs	86	75
State loss carryforwards	230	483
Deferred Tax Assets, Leases	15	67
Contributions in aid of construction	114	120
Leases	72	84
Valuation allowances	(213)	(462)
Total deferred tax assets	1,022	928
Deferred Tax Liabilities
Domestic plant - net	3,609	3,812
Regulatory assets	337	180
Deferred Tax Liabilities Prepayments	46	0
Domestic - other	30	75
Total deferred tax liabilities	4,022	4,067
Net deferred tax liability	3,000	3,139
Loss carryforwards
State loss carryforwards	230	483
Deferred tax asset tax credit carryforwards	68	15
Deferred Tax Assets, Goodwill and Intangible Assets	85	0
Federal [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset tax credit carryforwards	3
State [Member]
Deferred Tax Assets
State loss carryforwards	230
Loss carryforwards
Net operating losses	5,830
State loss carryforwards	230
Loss carryforward valuation allowance on net operating losses	(213)
State [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset tax credit carryforwards	1
Other Noncurrent Assets [Member]
Deferred Tax Liabilities
Deferred Tax Assets, State Taxes	6	12
PPL Electric Utilities Corp [Member]
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	699	599	664
Deferred Tax Assets
Regulatory liabilities	36	52
Income taxes due to customer	193	154
Accrued pension and postretirement costs	27	14
Contributions in aid of construction	87	95
Leases	18	21
Total deferred tax assets	361	336
Deferred Tax Liabilities
Domestic plant - net	1,745	1,891
Regulatory assets	93	74
Deferred Tax Liabilities Prepayments	35	0
Domestic - other	2	39
Total deferred tax liabilities	1,875	2,004
Net deferred tax liability	1,514	1,668
Louisville Gas And Electric Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	335	303	306
Deferred Tax Assets
Deferred investment tax credits	8	8
Regulatory liabilities	18	18
Income taxes due to customer	119	125
Deferred Tax Assets, Lease Liabilities	4	4
State tax credit carryforwards	9	11
Contributions in aid of construction	17	15
Leases	8	11
Valuation allowances	(9)	(11)
Total deferred tax assets	174	181
Deferred Tax Liabilities
Domestic plant - net	869	854
Regulatory assets	69	65
Lease right-of-use assets	3	4
Domestic - other	4	9
Total deferred tax liabilities	945	932
Net deferred tax liability	771	751
Louisville Gas And Electric Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	9
Valuation allowances	(9)
Kentucky Utilities Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	398	363	$ 343
Deferred Tax Assets
Deferred investment tax credits	21	22
Regulatory liabilities	23	23
Income taxes due to customer	136	143
Deferred Tax Assets, Lease Liabilities	5	7
State tax credit carryforwards	4	4
Contributions in aid of construction	9	9
Leases	4	4
Valuation allowances	(3)	(3)
Total deferred tax assets	199	209
Deferred Tax Liabilities
Domestic plant - net	1,028	1,012
Regulatory assets	56	41
Accrued pension and postretirement costs	6	13
Lease right-of-use assets	5	6
Domestic - other	0	2
Total deferred tax liabilities	1,095	1,074
Net deferred tax liability	896	$ 865
Kentucky Utilities Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	4
Valuation allowances	$ (3)

Income and Other Taxes (Credit

Income and Other Taxes (Credit Carryforwards and Valuation Allowances and Reserves) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Credit carryforwards
Deferred tax asset tax credit carryforwards	$ 68	$ 15
Deferred Tax Assets, Valuation Allowances	213	462
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	213	462
SEC Schedule 12-09, Valuation Allowance, Deduction, Tax Rate Change	213
SEC Schedule 12-09, Valuation Allowance, Deduction, Expiration of NOL Carryforward	36
Deferred Tax Assets, Valuation Allowance, Increase due to Loss on Extinguishment of Debt	31	31
Investment Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	20
Credit Carryforward Valuation Allowance Investment Tax Credit	0
Foreign Tax Credit [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	32
Credit Carryforward Valuation Allowance Foreign Tax Credits	0
Recycling Tax Credit [Member] | State [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	12
Credit Carryforward Valuation Allowance Other	0
Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	3
Credit Carryforward Valuation Allowance Other	0
Other [Member] | State [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	1
Credit Carryforward Valuation Allowance Other	0
Valuation Allowance Of Deferred Tax Assets [Member]
Valuation Allowances and Reserves (Details) [Roll Forward]
Balance at beginning of period	462	536	$ 514
Additions charged to income	10	48	26
Additions charged to other accounts	0	0	0
Deductions	259	122	4
Balance at end of period	213	462	$ 536
SEC Schedule 12-09, Valuation Allowance, Deduction, Business Disposition		113
Louisville Gas And Electric Co [Member]
Credit carryforwards
State tax credit carryforwards	9	11
Deferred Tax Assets, Valuation Allowances	9	11
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	9	11
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	9
Deferred Tax Assets, Valuation Allowances	9
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	9
Kentucky Utilities Co [Member]
Credit carryforwards
State tax credit carryforwards	4	4
Deferred Tax Assets, Valuation Allowances	3	3
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	3	$ 3
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	4
Deferred Tax Assets, Valuation Allowances	3
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	3
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Year 2028 [Member]
Credit carryforwards
State tax credit carryforwards	3
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Indefinite [Member]
Credit carryforwards
State tax credit carryforwards	$ 1

Income and Other Taxes (Income

Income and Other Taxes (Income Tax Expense and Reconciliation of Income Tax Expense) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Tax Expense (Benefit)
Current - Federal		$ (2)	$ (1)	$ (8)
Current - State		24	36	24
Current - Foreign		0	(1)	(2)
Total Current Expense		22	34	14
Deferred - Federal		122	28	135
Deferred - State		68	105	94
Deferred - Foreign		0	383	101
Total Deferred Expense (Benefit), excluding operating loss carry forwards		190	516	330
Amortization of investment tax credit		(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal		2	12	6
Deferred - State		(10)	(56)	(33)
Total Tax Expense (Benefit) of Operating Loss Carryforwards		(8)	(44)	(27)
Total income tax from continuing operations		201	503	314
Income tax expense [Abstract]
Total income tax expense - Federal		119	36	130
Total income tax expense - State		82	85	85
Total income tax expense - Foreign		0	382	99
Total income tax from continuing operations		201	503	314
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Income tax related to other comprehensive income		11	150	(19)
Total income tax expense (benefits) excluded from income taxes from continuing operations		(31)	1,569	169
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate		192	109	200
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		68	23	48
Valuation allowance adjustments		9	48	24
Federal and state income tax return adjustments		(1)	(3)	(9)
Impact of the United Kingdom Finance Acts on deferred tax balances		0	383	101
Depreciation and other items not normalized		(8)	(5)	(5)
Amortization of excess deferred federal and state income taxes		(54)	(54)	(43)
Other		(10)	(4)	(9)
Total increase (decrease)		9	394	114
Total income tax from continuing operations		$ 201	$ 503	$ 314
Effective income tax rate		22%	96.50%	32.90%
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized		$ 5	$ 15	$ 24
Taxes, other than income
State gross receipts		175	113	100
Domestic property and other		157	94	80
Total		332	207	180
Effective Income Tax Rate Reconciliation, Change in Enacted Tax Rate, U.K. Finance Act 2020, Amount				106
Deferred Tax Assets, Valuation Allowances		213	462
Reclassification from AOCI due to sale of UK utility business		0	660	0
Nondeductible officers salary		5	6	7
Deferred Tax Benefit
Taxes, other than income
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	$ 5
WPD [Member]
Taxes, other than income
Income tax related to Discontinued Operations		(42)	759	188
Foreign Tax Authority [Member]
Income Tax Expense (Benefit)
Deferred - Foreign				106
PPL Electric Utilities Corp [Member]
Income Tax Expense (Benefit)
Current - Federal		63	40	61
Current - State		20	35	23
Total Current Expense		83	75	84
Deferred - Federal		60	59	45
Deferred - State		31	20	38
Total Deferred Expense (Benefit), excluding operating loss carry forwards		91	79	83
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations		174	154	167
Income tax expense [Abstract]
Total income tax expense - Federal		123	99	106
Total income tax expense - State		51	55	61
Total income tax from continuing operations		174	154	167
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate		147	126	139
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		54	46	52
Federal and state income tax return adjustments		(1)	0	(4)
Depreciation and other items not normalized		(7)	(5)	(5)
Amortization of excess deferred federal and state income taxes		(12)	(14)	(16)
Other		2	1	1
Total increase (decrease)		27	28	28
Total income tax from continuing operations		$ 174	$ 154	$ 167
Effective income tax rate		24.90%	25.70%	25.20%
Taxes, other than income
State gross receipts		$ 142	$ 113	$ 100
Domestic property and other		7	7	7
Total		149	120	107
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount		(9)	0	0
PPL Electric Utilities Corp [Member] | Deferred Tax Benefit
Taxes, other than income
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	$ 9	9
Louisville Gas And Electric Co [Member]
Income Tax Expense (Benefit)
Current - Federal		60	41	53
Current - State		9	5	7
Total Current Expense		69	46	60
Deferred - Federal		(10)	1	(4)
Deferred - State		5	8	7
Total Deferred Expense (Benefit), excluding operating loss carry forwards		(5)	9	3
Amortization of investment tax credit		(1)	(1)	(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations		63	54	62
Income tax expense [Abstract]
Total income tax expense - Federal		49	41	48
Total income tax expense - State		14	13	14
Total income tax from continuing operations		63	54	62
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate		70	64	64
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		13	12	12
Amortization of excess deferred federal and state income taxes		(18)	(20)	(11)
Other		(2)	(2)	(3)
Total increase (decrease)		(7)	(10)	(2)
Total income tax from continuing operations		$ 63	$ 54	$ 62
Effective income tax rate		18.80%	17.80%	20.30%
Taxes, other than income
Domestic property and other		$ 48	$ 46	$ 40
Total		48	46	40
Deferred Tax Assets, Valuation Allowances		9	11
Kentucky Utilities Co [Member]
Income Tax Expense (Benefit)
Current - Federal		63	58	40
Current - State		11	8	3
Total Current Expense		74	66	43
Deferred - Federal		(3)	(4)	11
Deferred - State		7	7	11
Total Deferred Expense (Benefit), excluding operating loss carry forwards		4	3	22
Amortization of investment tax credit		(2)	(2)	(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations		76	67	63
Income tax expense [Abstract]
Total income tax expense - Federal		58	52	49
Total income tax expense - State		18	15	14
Total income tax from continuing operations		76	67	63
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate		84	76	72
Increase (decrease) due to:
State income taxes, net of federal income tax benefit		16	14	14
Amortization of investment tax credit		(2)	(2)	(2)
Amortization of excess deferred federal and state income taxes		(21)	(20)	(17)
Other		(1)	(1)	(4)
Total increase (decrease)		(8)	(9)	(9)
Total income tax from continuing operations		$ 76	$ 67	$ 63
Effective income tax rate		19.10%	18.40%	18.40%
Taxes, other than income
Domestic property and other		$ 45	$ 41	$ 37
Total		45	41	$ 37
Deferred Tax Assets, Valuation Allowances		$ 3	$ 3

Income and Other Taxes (Unrecog

Income and Other Taxes (Unrecognized to End) (Details) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($) Integer	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer		4
Deferred Income Tax Expense (Benefit)		$ 190	$ 516	$ 330
Increase (Decrease) in Regulatory Assets and Liabilities		$ 119	(52)	63
Deferred Tax Benefit
Income Tax Examination (Details) [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	$ 5
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2018 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2017 and prior
Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2017 and prior
United Kingdom - Foreign [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2019 and prior
PPL Electric [Member] | Regulated Deferred Income Taxes Reduction
Income Tax Examination (Details) [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	270
PPL Electric [Member] | Deferred Tax Benefit
Income Tax Examination (Details) [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	9
PPL Electric Utilities Corp [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer		3
Deferred Income Tax Expense (Benefit)		$ 91	79	83
Increase (Decrease) in Regulatory Assets and Liabilities		59	(96)	40
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount		(9)	0	0
PPL Electric Utilities Corp [Member] | Regulated Deferred Income Taxes Reduction
Income Tax Examination (Details) [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	270
PPL Electric Utilities Corp [Member] | Deferred Tax Benefit
Income Tax Examination (Details) [Line Items]
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	$ 9	$ 9
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2018 and prior
PPL Electric Utilities Corp [Member] | Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2017 and prior
PPL Electric Utilities Corp [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2017 and prior
Louisville Gas And Electric Co [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer		2
Deferred Income Tax Expense (Benefit)		$ (5)	9	3
Increase (Decrease) in Regulatory Assets and Liabilities		$ (17)	23	0
Louisville Gas And Electric Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2018 and prior
Louisville Gas And Electric Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2017 and prior
Kentucky Utilities Co [Member]
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer		2
Deferred Income Tax Expense (Benefit)		$ 4	3	22
Increase (Decrease) in Regulatory Assets and Liabilities		$ 19	$ 22	$ 26
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2018 and prior
Kentucky Utilities Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination		2017 and prior

Utility Rate Regulation (Regula

Utility Rate Regulation (Regulatory Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 1,819	$ 1,236
Current Regulatory Assets	258	64
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	107	98
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	46	54
Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	41	21
Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	5	11
Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	118	11
Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	69	6
Current Regulatory Assets	34	21
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	778	523
Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	21	24
Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	7	18
Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	63	70
Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	212	228
Rate Adjstment mechanism
Regulatory Assets [Line Items]
Current Regulatory Assets	96	0
AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	295	302
Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	38	11
Net Metering
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	61	0
Environmental Cost Recovery Mechanism
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	102	0
Taxes recoverable through future rates
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	47	0
Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	3	0
Dervative Instruments
Regulatory Assets [Line Items]
Current Regulatory Assets	41	0
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	568	488
Current Regulatory Assets	13	22
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	5	11
PPL Electric Utilities Corp [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Current Regulatory Assets	5	11
PPL Electric Utilities Corp [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	353	256
PPL Electric Utilities Corp [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	3	4
PPL Electric Utilities Corp [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	212	228
PPL Electric Utilities Corp [Member] | Rate Adjstment mechanism
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Net Metering
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery Mechanism
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Taxes recoverable through future rates
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	3	0
PPL Electric Utilities Corp [Member] | Dervative Instruments
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	373	337
Current Regulatory Assets	23	33
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	57	54
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	12	15
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	13	21
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	3
Louisville Gas And Electric Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	7	8
Louisville Gas And Electric Co [Member] | Generation formula rate
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	14	4
Current Regulatory Assets	1	5
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	209	164
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	11	12
Louisville Gas And Electric Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	7	18
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	37	41
Louisville Gas And Electric Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	76	75
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	9	4
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	442	411
Current Regulatory Assets	32	9
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period	50	44
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	34	39
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	3	3
Kentucky Utilities Co [Member] | Generation formula rate
Regulatory Assets [Line Items]
Current Regulatory Assets	0	2
Kentucky Utilities Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	13	2
Current Regulatory Assets	3	0
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	140	103
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	7	8
Kentucky Utilities Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	26	29
Kentucky Utilities Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	219	227
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 29	$ 7

Utility Rate Regulation (Regu_2

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions	May 21, 2020	Dec. 31, 2022	Dec. 31, 2021
Regulatory Liabilities [Line Items]
Current regulatory liabilities		$ 238	$ 182
Noncurrent regulatory liabilities		3,412	2,422
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		37	10
Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	17
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		12	0
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		15	22
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		14	10
Regulatory Liability due to ROE Reserve
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	73
Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	27
Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		950	639
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		26	35
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		2,094	1,591
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		187	95
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		60	62
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		27	2
Noncurrent regulatory liabilities		63	0
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		14	21
Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities		96	0
Energy efficiency
Regulatory Liabilities [Line Items]
Current regulatory liabilities		23	0
Noncurrent regulatory liabilities		32	0
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		85	153
Noncurrent regulatory liabilities		820	559
Return on equity	11.18%
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		37	10
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	17
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		12	0
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		15	22
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		14	10
PPL Electric Utilities Corp [Member] | Regulatory Liability due to ROE Reserve
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	73
PPL Electric Utilities Corp [Member] | Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		775	531
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		45	28
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
Noncurrent regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		7	21
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
PPL Electric Utilities Corp [Member] | Energy efficiency
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	0
Noncurrent regulatory liabilities		0	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		7	21
Noncurrent regulatory liabilities		833	818
Louisville Gas And Electric Co [Member] | Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	21
Louisville Gas And Electric Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		287	262
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		18	24
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		477	491
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		21	10
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		30	31
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		7	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		6	8
Noncurrent regulatory liabilities		1,029	1,045
Kentucky Utilities Co [Member] | Economic relief billing credit
Regulatory Liabilities [Line Items]
Current regulatory liabilities		0	6
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		389	377
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		8	11
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		546	569
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		56	57
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities		30	31
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities		$ 6	$ 2

Utility Rate Regulation (Regu_3

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions		12 Months Ended
	May 21, 2020	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities		$ 119	$ (52)	$ 63
Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 107	98
PPL Electric [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities - Storm Costs (Numeric) [Abstract]
Period over which storm costs will be recovered (in years)		3 years
PPL Electric [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		5 years
PPL Electric [Member] | Storm Damage Expense Rider [Member]
Regulatory Assets and Liabilities - Storm Damage Expense Rider (Numeric) [Abstract]
Maximum reportable storm damage expenses to be recovered annually through base rates		$ 20
PPL Electric [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]
Maximum amount of costs that can be recovered under the Act 129 Phase III plan		$ 313
Period over which program costs can be recovered for Phase III (in years)		5 years
LGE [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
LGE [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		18 months
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		9.35%
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
KU [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		9.35%
KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
PPL Electric Utilities Corp [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities		$ 59	(96)	40
Return on equity	11.18%
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets and Liabilities - Storm Costs (Numeric) [Abstract]
Period over which storm costs will be recovered (in years)		3 years
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		5 years
PPL Electric Utilities Corp [Member] | Storm Damage Expense Rider [Member]
Regulatory Assets and Liabilities - Storm Damage Expense Rider (Numeric) [Abstract]
Maximum reportable storm damage expenses to be recovered annually through base rates		$ 20
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Assets and Liabilities - Act 129 Compliance Rider (Numeric) [Abstract]
Maximum amount of costs that can be recovered under the Act 129 Phase III plan		$ 313
Period over which program costs can be recovered for Phase III (in years)		5 years
Louisville Gas And Electric Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities		$ (17)	23	0
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 57	54
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		18 months
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		9.35%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
Kentucky Utilities Co [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities		$ 19	22	$ 26
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		15 years
Regulatory Assets and Liabilities - Defined Benefit Plans (Numeric) [Abstract]
Deferred recovery of the difference between pension costs calculated with pension accounting policy and pension cost using 15 year amortization period		$ 50	$ 44
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Return on equity		9.35%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Assets and Liabilities (Numeric) [Line Items]
Regulatory Asset Amortization Period		12 months

Utility Rate Regulation (Regu_4

Utility Rate Regulation (Regulatory Matters) (Details) $ in Millions								3 Months Ended	11 Months Ended	12 Months Ended
	Jan. 27, 2023 USD ($)	Dec. 23, 2022 USD ($) mi	Dec. 15, 2022 MW	Nov. 18, 2022 USD ($)	May 21, 2020	Oct. 16, 2018	Aug. 24, 2018	Mar. 31, 2015	Nov. 30, 2021 USD ($)	Dec. 31, 2022 USD ($) MW
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
CPCN NGCC Combustion Turbine Facilities, Power | MW			621
CPCN Solar Photovoltaic Facility to be constructed, Power | MW			120
CPCN Solar Photovoltaic Facility to be Acquired, Power | MW			120
CPCN 4-Hour Battery Energy Storage Facility to be Constructed, Power | MW			125
CPCN New and Adjusted Energy Efficiency Programs, Overall Power Need Reduction | MW			100
Total Capacity of Power-Purchase Agreements Not Subject to KPSC Approval, Power | MW			637
New NGCC LG&E Planned Ownership Percentage			0.31
New Solar Units LG&E Planned Ownership Percentage			0.37
New NGCC KU Planned Ownership Percentage			0.69
New Solar Units KU Planned Ownership Percentage			0.63
Mill Creek 1 Unit, Generation Capacity, Power | MW										300
E. W. Brown 3 Unit, Generating Capacity, Power | MW										412
Mill Creek 2 Unit, Generation Capacity, Power | MW										297
Ghent 2 Unit, Generation Capacity, Power | MW										486
LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity										9.35%
LGE [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Amortization period for the deferred recovery of a regulatory asset										12 months
KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity										9.35%
KU [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Amortization period for the deferred recovery of a regulatory asset										12 months
PPL Electric Utilities Corp [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity					11.18%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, After Tax									$ 55
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 12-31-2020
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									28
Regulatory Liability due to ROE Reserve, After Tax									20
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 11-30-2021
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									73
Regulatory Liability due to ROE Reserve, After Tax									52
Rhode Island Energy | Rhode Island Public Uitilty Commission
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity							9.275%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Estimated Net present value				$ 188
Net Present Value benefit of the AMF program				$ 729
Benefit-cost ratio yield of the AMF program				3.90%
Amount of capital Investment to spend on the Electrical ISR plan		$ 328
Capital Investment to spend on the FY 2024 Gas ISR Plan		389
Capital Investment for the 2024 Gas ISR plan included in the GMP filing										$ 82
Amount of capital Investment to spend on the Electrical ISR plan		$ 328
Distance of Gas Piping to be Abandoned, FY 2024 Gas ISR, Miles | mi		123
Rhode Island Energy | Rhode Island Public Uitilty Commission | Vegetation Management
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Amount of capital Investment to spend on the Electrical ISR plan		$ 24
Amount of capital Investment to spend on the Electrical ISR plan		24
Rhode Island Energy | Rhode Island Public Uitilty Commission | Other O&M
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Amount of capital Investment to spend on the Electrical ISR plan		6
Amount of capital Investment to spend on the Electrical ISR plan		$ 6
Rhode Island Energy | Rhode Island Public Uitilty Commission | Common equity percentage related to approved rate
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Percentage of common equity used on allowed ROE							5,100%
Rhode Island Energy | Federal Energy Regulatory Commission
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Initial minimum base ROE to be reset by the FERC								11.14%
Minimum base ROE reset by FERC								10.57%
New ROE proposed by NETO and approved by FERC						10.41%
Maximum Base ROE reset by FERC								11.74%
Rhode Island Energy | Federal Energy Regulatory Commission | Amount remitted on the authorized ROE
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Amount of ROE remitted by NEP										$ 122
Rhode Island Energy | Federal Energy Regulatory Commission | Maximum ROE authorized
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
FERC Granted ROE										11.74%
Rhode Island Energy | Subsequent Event [Member] | Rhode Island Public Uitilty Commission
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Supplemental Capital Investment to spend on the FY 2024 Gas ISR Plan	$ 187
Supplemental Capital Investment to spend on the FY 2024 Electrical ISR Plan	176
Rhode Island Energy | Subsequent Event [Member] | Rhode Island Public Uitilty Commission | Vegetation Management
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Supplemental Capital Investment to spend on the FY 2024 Electrical ISR Plan	14
Rhode Island Energy | Subsequent Event [Member] | Rhode Island Public Uitilty Commission | Other O&M
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Supplemental Capital Investment to spend on the FY 2024 Electrical ISR Plan	$ 3
PPL Electric Utilities Corp [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity					11.18%
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									78
Regulatory Liability due to ROE Reserve, After Tax									55
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 12-31-2020
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									28
Regulatory Liability due to ROE Reserve, After Tax									20
PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 11-30-2021
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									73
Regulatory Liability due to ROE Reserve, After Tax									52
PPL Electric Utilities Corp [Member] | PPL Electric [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Act 129 Recovery Period Under Phase IV Plan										5 years
PPL Electric Utilities Corp [Member] | PPL Electric Utilities Corp [Member]
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									78
PPL Electric Utilities Corp [Member] | PPL Electric Utilities Corp [Member] | Period of 05-21-2020 to 11-30-2021
Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]
Regulatory Liability due to ROE Reserve, Before Tax									$ 73
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity										9.35%
Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Amortization period for the deferred recovery of a regulatory asset										12 months
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Return on equity										9.35%
Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Environmental Cost Recovery [Member]
Regulatory Matters - Kentucky Activities - Rate Case Proceedings (Numeric) [Abstract]
Amortization period for the deferred recovery of a regulatory asset										12 months

Utility Rate Regulation (Other)

Utility Rate Regulation (Other) (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.3	$ 1.2	$ 1.1
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.3	$ 1.2	$ 1.1

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Dec. 31, 2022	Sep. 16, 2022	Jul. 29, 2022	Mar. 31, 2022	Feb. 28, 2022	Dec. 31, 2021
PPL Capital Funding [Member]
Financing Activities [Line Items]
Capacity	$ 1,450
Borrowed	0					$ 0
Letters of credit and commercial paper issued	619					15
Unused capacity	831
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	1,250
Borrowed	0					0
Letters of credit and commercial paper issued	561					0
Unused capacity	$ 689
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Financing Activities [Line Items]
Capacity	100			$ 100	$ 50
Borrowed	0					0
Letters of credit and commercial paper issued	0					0
Unused capacity	$ 100
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 30
PPL Capital Funding [Member] | Bilateral Credit Facility
Financing Activities [Line Items]
Capacity	100			$ 100	$ 50
Borrowed	0					0
Letters of credit and commercial paper issued	58					15
Unused capacity	$ 42
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
PPL Electric [Member]
Financing Activities [Line Items]
Capacity	$ 900
Borrowed	250					0
Letters of credit and commercial paper issued	146					1
Unused capacity	504
PPL Electric [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	650
Borrowed	0					0
Letters of credit and commercial paper issued	146					1
Unused capacity	$ 504
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
PPL Electric [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	250	$ 250
Borrowed	250	$ 250				0
Letters of credit and commercial paper issued	0					0
Unused capacity	$ 0
Interest rate on outstanding borrowing		3.77%
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
LGE [Member]
Financing Activities [Line Items]
Capacity	$ 800
Borrowed	300					0
Letters of credit and commercial paper issued	180					69
Unused capacity	320
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	500
Borrowed	0					0
Letters of credit and commercial paper issued	180					69
Unused capacity	$ 320
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
LGE [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	300		$ 300
Borrowed	300		$ 300			0
Letters of credit and commercial paper issued	0					0
Unused capacity	$ 0
Interest rate on outstanding borrowing			3.23%
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
KU [Member]
Financing Activities [Line Items]
Capacity	$ 700
Borrowed	300					0
Letters of credit and commercial paper issued	101					0
Unused capacity	299
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0					0
Letters of credit and commercial paper issued	101					0
Unused capacity	$ 299
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
KU [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	300		$ 300
Borrowed	300		$ 300			0
Letters of credit and commercial paper issued	0					0
Unused capacity	$ 0
Interest rate on outstanding borrowing			3.23%
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
PPL Electric Utilities Corp [Member]
Financing Activities [Line Items]
Capacity	$ 900
Borrowed	250					0
Letters of credit and commercial paper issued	146					1
Unused capacity	504
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	650
Borrowed	0					0
Letters of credit and commercial paper issued	146					1
Unused capacity	$ 504
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
PPL Electric Utilities Corp [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	250	$ 250
Borrowed	250	$ 250				0
Letters of credit and commercial paper issued	0					0
Unused capacity	$ 0
Interest rate on outstanding borrowing		3.77%
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Louisville Gas And Electric Co [Member]
Financing Activities [Line Items]
Capacity	$ 800
Borrowed	300					0
Letters of credit and commercial paper issued	180					69
Unused capacity	320
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	500
Borrowed	0					0
Letters of credit and commercial paper issued	180					69
Unused capacity	$ 320
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	300		$ 300
Borrowed	300		$ 300			0
Letters of credit and commercial paper issued	0					0
Unused capacity	$ 0
Interest rate on outstanding borrowing			3.23%
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Kentucky Utilities Co [Member]
Financing Activities [Line Items]
Capacity	$ 700
Borrowed	300					0
Letters of credit and commercial paper issued	101					0
Unused capacity	299
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity	400
Borrowed	0					0
Letters of credit and commercial paper issued	101					0
Unused capacity	$ 299
Maximum percentage of debt to total capitalization allowed under the credit facility	70%
Potential capacity increase	$ 250
Kentucky Utilities Co [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Capacity	300		$ 300
Borrowed	300		$ 300			0
Letters of credit and commercial paper issued	0					$ 0
Unused capacity	$ 0
Interest rate on outstanding borrowing			3.23%
Maximum percentage of debt to total capitalization allowed under the credit facility	70%

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Dec. 31, 2022	Aug. 31, 2022	Dec. 31, 2021
Short-term Debt [Line Items]
Capacity	$ 2,900
Commercial paper issuances	987		$ 69
Unused capacity	$ 1,913
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.84%
Capacity	$ 1,350
Commercial paper issuances	561		$ 0
Unused capacity	$ 789
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.74%
Capacity	$ 650
Commercial paper issuances	145		$ 0
Unused capacity	$ 505
LGE [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.94%		0.31%
Capacity	$ 500	$ 500
Commercial paper issuances	180		$ 69
Unused capacity	$ 320
KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.90%
Capacity	$ 400	400
Commercial paper issuances	101		$ 0
Unused capacity	$ 299
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.74%
Capacity	$ 650
Commercial paper issuances	145		$ 0
Unused capacity	$ 505
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.94%		0.31%
Capacity	$ 500	500
Commercial paper issuances	180		$ 69
Unused capacity	$ 320
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.90%
Capacity	$ 400	$ 400
Commercial paper issuances	101		$ 0
Unused capacity	$ 299

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Sep. 30, 2022	Sep. 16, 2022	Aug. 31, 2022	Jul. 29, 2022
Debt Instrument [Line Items]
Principal outstanding	$ 13,353	$ 11,251
Unamortized premium and (discount), net	(32)	(34)
Unamortized debt issuance costs	(78)	(77)
Total Long-term Debt	13,243	11,140
Less current portion of Long-term debt	354	474
Long-term Debt	12,889	10,666
Aggregate maturities of long-term debt (Details) [Abstract]
2022	354
2023	1,501
2024	551
2025	904
2026	303
Thereafter	9,740
Loss on Extinguishment of Debt	$ 0	(395)	$ 0
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	3.95%
Principal outstanding	$ 3,066	1,566
Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	4.06%
Principal outstanding	$ 8,957	9,205
Junior Subordinated Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	7.39%
Principal outstanding	$ 480	480
Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	5.21%
Principal outstanding	$ 850	0
First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate amount of tax-exempt revenue bonds in a term rate mode	782
PPL Capital Funding [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	1,450
PPL Electric [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	900
PPL Electric [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	250				$ 250
Interest rate on outstanding borrowing					3.77%
PPL Electric [Member] | LCIDA Pollution Control Revenue Refunding Bonds 2016 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 108
Stated interest rate						2.63%
PPL Electric [Member] | LCIDA Pollution Control Revenue Refunding Bonds 2016 Series A | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 116
Stated interest rate				3%
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Currently Able To Be Called
Debt Instrument [Line Items]
Principal outstanding	250
PPL Electric [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien	11,800	11,300
LGE [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	800
LGE [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	300						$ 300
Interest rate on outstanding borrowing							3.23%
LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien	$ 5,800	5,700
LGE [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode	1 year
Aggregate amount of tax-exempt revenue bonds in a variable rate mode	$ 66
KU [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	700
KU [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	300						$ 300
Interest rate on outstanding borrowing							3.23%
KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien	$ 7,100	6,900
KU [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode	1 year
Aggregate amount of tax-exempt revenue bonds in a variable rate mode	$ 33
PPL Electric Utilities Corp [Member]
Debt Instrument [Line Items]
Principal outstanding	4,539	4,539
Unamortized discount	(22)	(22)
Unamortized debt issuance costs	(31)	(33)
Total Long-term Debt	4,486	4,484
Less current portion of Long-term debt	340	474
Long-term Debt	4,146	4,010
Aggregate maturities of long-term debt (Details) [Abstract]
2022	340
2023	900
2024	0
2025	0
2026	108
Thereafter	3,191
Capacity	900
PPL Electric Utilities Corp [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	$ 250				$ 250
Interest rate on outstanding borrowing					3.77%
PPL Electric Utilities Corp [Member] | LCIDA Pollution Control Revenue Refunding Bonds 2016 Series B | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 108
Stated interest rate						2.63%
PPL Electric Utilities Corp [Member] | LCIDA Pollution Control Revenue Refunding Bonds 2016 Series A | Remarketed [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount				$ 116
Stated interest rate				3%
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	4.26%
Principal outstanding	$ 4,289	4,539
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Currently Able To Be Called
Debt Instrument [Line Items]
Principal outstanding	250
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member] | Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien	$ 11,800	11,300
PPL Electric Utilities Corp [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	5.17%
Principal outstanding	$ 250	0
Louisville Gas And Electric Co [Member]
Debt Instrument [Line Items]
Principal outstanding	2,324	2,024
Unamortized discount	(4)	(4)
Unamortized debt issuance costs	(13)	(14)
Total Long-term Debt	2,307	2,006
Less current portion of Long-term debt	0	0
Long-term Debt	2,307	2,006
Aggregate maturities of long-term debt (Details) [Abstract]
2022	0
2023	300
2024	300
2025	90
2026	195
Thereafter	1,439
Capacity	800
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	$ 300						$ 300
Interest rate on outstanding borrowing							3.23%
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	5.22%
Principal outstanding	$ 300	0
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	3.70%
Principal outstanding	$ 2,024	2,024
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien	$ 5,800	5,700
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode	1 year
Aggregate amount of tax-exempt revenue bonds in a term rate mode	$ 473
Aggregate amount of tax-exempt revenue bonds in a variable rate mode	66
Kentucky Utilities Co [Member]
Debt Instrument [Line Items]
Principal outstanding	2,942	2,642
Debt Instrument, Unamortized Premium	5	5
Unamortized discount	(9)	(9)
Unamortized debt issuance costs	(18)	(20)
Total Long-term Debt	2,920	2,618
Less current portion of Long-term debt	13	0
Long-term Debt	2,907	2,618
Aggregate maturities of long-term debt (Details) [Abstract]
2022	13
2023	300
2024	250
2025	164
2026	0
Thereafter	2,215
Capacity	700
Kentucky Utilities Co [Member] | Term Loan Credit Facility [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity	$ 300						$ 300
Interest rate on outstanding borrowing							3.23%
Kentucky Utilities Co [Member] | Term Loan Credit Facility [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	5.22%
Principal outstanding	$ 300	0
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate	4%
Principal outstanding	$ 2,642	2,642
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien	$ 7,100	$ 6,900
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member] | Tax Exempt Revenue Bonds [Member]
Long-term Debt (Numeric) [Abstract]
Minimum length of time to convert interest rate mode	1 year
Aggregate amount of tax-exempt revenue bonds in a term rate mode	$ 309
Aggregate amount of tax-exempt revenue bonds in a variable rate mode	$ 33

Financing Activities Financing

Financing Activities Financing Activities- Equity Securities (Details) - USD ($) shares in Thousands, $ in Billions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Aug. 01, 2021
Equity Programs [Line Items]
Stock Repurchase Program, Authorized Amount					$ 3
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]	123	983	1,674
Treasury stock		1,252
Treasury Stock
Equity Programs [Line Items]
Treasury Stock, Value, Acquired, Cost Method		$ 0	$ 1
[1]Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.

Financing Activities - Distribu

Financing Activities - Distributions and Capital Contributions (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended		12 Months Ended
	Feb. 28, 2023	Nov. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)		$ 0.225	$ 0.875	$ 1.660	$ 1.660
Annualized current quarterly common stock dividend (in dollars per share)		$ 0.90
Deferred Interest Payment			$ 0
Preferred Stock, Value, Outstanding			$ 3
Preferred Stock, Dividend Preference or Restrictions			Pursuant to the preferred stock arrangement, as long as any preferred stock is outstanding, certain restrictions on payment of common stock dividends would come into effect if the common stock equity of RIE was, or by reason of payment of such dividends became, less than 25% of total capitalization of RIE.
Subsequent Event [Member]
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)	$ 0.24
Louisville Gas And Electric Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			$ 1,400
Unrestricted assets at the end of period			$ 1,800
Minimum adjusted equity to total capitalization in order to pay dividends			30%
Kentucky Utilities Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			$ 1,900
Unrestricted assets at the end of period			$ 2,100
Minimum adjusted equity to total capitalization in order to pay dividends			30%

Acquisitions, Development and_3

Acquisitions, Development and Divestitures - Acquisitions (Details) - USD ($) $ in Millions		1 Months Ended	3 Months Ended	4 Months Ended	6 Months Ended		7 Months Ended	12 Months Ended			25 Months Ended
	May 25, 2022	Jun. 30, 2022	Jun. 30, 2022	Sep. 30, 2022	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Jun. 30, 2024
Disclosure [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-Term Debt		$ 1,500	$ 1,500		$ 1,500
Operating Revenues								$ 7,902	$ 5,783	$ 5,474
Net income (loss)								756	(1,480)	1,469
Business Acquisition, Pro Forma Revenue								8,667	7,478
Business Acquisition, Pro Forma Net Income (Loss)								790	159
Business Combination, Integration Related Costs								223	38
Transition Service Agreement Expense								123
Goodwill recognized during the period								1,586	0
Goodwill							$ 2,248	2,248	716
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables, Gross	$ 255
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, AR Reserve	60
Business Combination, Transaction Costs Expense								18
Payments to Acquire Businesses, Gross					5,300
Disposal Group [Line Items]
Income (Loss) from Discontinued Operations (net of income taxes)								42	(1,498)	829
Forecast [Member]
Disclosure [Line Items]
Business Combination, Integration Related Costs											$ 408
Corporate And Other [Member]
Disclosure [Line Items]
Operating Revenues								23	33	38
Net income (loss)								(274)	(895)	(275)
Goodwill, Purchase Accounting Adjustments								5
Goodwill recognized during the period								861	0
Goodwill							861	861	53	53
Rhode Island Energy
Disclosure [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Cash and Equivalents	154
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables	195
Business Acquisition, Recognized Identifiable Assets Acquired and Liabilities Assumed, Unbilled Revenues	54
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Regulatory Assets	75
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Other	65
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets	642
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment	3,988
Public Utilities, Customer Bill Credit Agreement, Total	50
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Regulatory Assets	395
Goodwill, Business Combination	1,586
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets	166
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets	6,135
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets	6,777
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Long-Term Debt	14
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Accounts Payable	180
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Taxes Accrued	44
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities, Other	198
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Liabilities	675
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-Term Debt	1,496
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Regulatory Liabilities	643
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Other	143
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities	2,282
Business Combination, Consideration Transferred		$ 3,820
Operating Revenues							1,038
Net income (loss)							(44)
Acquisition commitment write off expenses								98
RICCREF Contribution Expense			2.5
Accounts Receivable Forgiven, AR Reserve								23
Accounts Receivable Forgiven, net				$ 21
Accounts Receivable Forgiven, Gross				44
Public Utilities, Customer Bill Credit Agreement, Net of Tax	40
Business Combination, Regulatory Assets Expensed					20
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Regulatory Liabilities	239
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Price Risk Management Assets	99
Rhode Island Energy | Electric Customer
Disclosure [Line Items]
Public Utilities, Customer Bill Credit Agreement, Total	33
Rhode Island Energy | Natural Gas Customer
Disclosure [Line Items]
Public Utilities, Customer Bill Credit Agreement, Total	$ 17
Rhode Island Energy | Accounts Receivable and Regulatory Asset write off
Disclosure [Line Items]
Acquisition commitment write off expenses								43
Rhode Island Energy | Accrued expenditures for the RIAG and decarbonization goals
Disclosure [Line Items]
Acquisition commitment write off expenses								5
Rhode Island Energy | RIPUC regulatory liability
Disclosure [Line Items]
Regulatory Liabilities				50			$ 50	50
Rhode Island Energy | Rhode Island Energy TSA
Disclosure [Line Items]
Other Nonrecurring (Income) Expense								181
Rhode Island Energy | Accrual for TSA Markup
Disclosure [Line Items]
Other Nonrecurring (Income) Expense								3
Rhode Island Energy | Accrual for RIAG Evaluation Fund
Disclosure [Line Items]
Other Nonrecurring (Income) Expense			$ 2.5
WPD [Member]
Disposal Group [Line Items]
Income tax related to Discontinued Operations								(42)	759	188
Transaction Costs | Additional Costs Related to Purchase, Agreed not to seek recovery
Disclosure [Line Items]
Business Combination, Separately Recognized Transactions, Expenses and Losses Recognized								27
Transaction Costs | Utilities Operating Expense, Maintenance, Operations, and Other Costs and Expenses | Additional Costs Related to Purchase, Agreed not to seek recovery
Disclosure [Line Items]
Business Combination, Separately Recognized Transactions, Expenses and Losses Recognized								18
Disposal Group, Held-for-sale or Disposed of by Sale, Not Discontinued Operations | Safari Holdings LLC, Consolidated
Disposal Group [Line Items]
Gain (loss) on disposition of business, net of tax								(46)
Goodwill from Disposal Group				$ 53
Loss on Sale								60
Discontinued Operations, Disposed of by Sale | WPD [Member]
Disposal Group [Line Items]
Income (Loss) from Discontinued Operations (net of income taxes)									(1,498)
Discontinued Operations, Held-for-sale | WPD [Member]
Disposal Group [Line Items]
Sale proceeds, net of realized foreign currency hedge losses						$ 10,700
Net Proceeds From Divestiture Of Businesses						$ 10,400
Operating Revenues related to discontinued operations								0	1,344	2,133
Operating Expense related to discontinued operations								0	467	916
Other Income (Expense) - net related to discontinued operations								0	202	167
Interest Expense related to discontinued operations								0	209	367
Income from Discontinued Operations, before Income Tax								0	870	1,017
Loss on Sale								0	(1,609)	0
Income tax related to Discontinued Operations								(42)	759	188
Income (Loss) from Discontinued Operations (net of income taxes)								$ 42	$ (1,498)	$ 829
Narragansett Electric
Disclosure [Line Items]
Business Combination, Consideration Transferred					$ 3,800

Leases - Lessee (Details)

Leases - Lessee (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Lease, Cost [Abstract]
Operating lease cost	$ 20	$ 24	$ 28
Short-term lease cost	6	6	7
Total lease cost	26	30	35
Operating cash flows from operating leases	26	23	24
Right-of-use asset obtained in exchange for new operating lease liabilities	15	12	17
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	24
2023	17
2024	12
2025	5
2026	4
Thereafter	7
Total	$ 69
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.10%
Weighted-average remaining lease term (in years)	4 years
Current lease liabilities	$ 22
Non-current lease liabilities	42
Right-of-use assets	$ 60
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other deferred credits and noncurrent liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other noncurrent assets
Louisville Gas And Electric Co [Member]
Lease, Cost [Abstract]
Operating lease cost	$ 6	6	8
Short-term lease cost	1	1	1
Total lease cost	7	7	9
Operating cash flows from operating leases	8	6	7
Right-of-use asset obtained in exchange for new operating lease liabilities	4	4	6
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	6
2023	5
2024	3
2025	1
2026	1
Thereafter	0
Total	$ 16
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.17%
Weighted-average remaining lease term (in years)	3 years
Current lease liabilities	$ 6
Non-current lease liabilities	9
Right-of-use assets	$ 13
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other deferred credits and noncurrent liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other noncurrent assets
Louisville Gas And Electric Co [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	1 year
Louisville Gas And Electric Co [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	10 years
Kentucky Utilities Co [Member]
Lease, Cost [Abstract]
Operating lease cost	$ 9	10	13
Short-term lease cost	2	1	1
Total lease cost	11	11	14
Operating cash flows from operating leases	12	10	11
Right-of-use asset obtained in exchange for new operating lease liabilities	5	$ 7	$ 9
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	9
2023	7
2024	4
2025	1
2026	0
Thereafter	0
Total	$ 21
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate	3.40%
Weighted-average remaining lease term (in years)	3 years
Current lease liabilities	$ 8
Non-current lease liabilities	12
Right-of-use assets	$ 19
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other deferred credits and noncurrent liabilities
Operating Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other noncurrent assets
Kentucky Utilities Co [Member] | Minimum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	1 year
Kentucky Utilities Co [Member] | Maximum [Member]
Lessee, Lease, Description [Line Items]
Lessee, Operating Lease, Renewal Term	10 years

Leases Leases - Lessor (Details

Leases Leases - Lessor (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Lessor, Lease, Description [Line Items]
Lease income recognized	$ 6	$ 11	$ 16
Louisville Gas And Electric Co [Member]
Lessor, Lease, Description [Line Items]
Lease income recognized	2	5	6
Kentucky Utilities Co [Member]
Lessor, Lease, Description [Line Items]
Lease income recognized	$ 0	$ 5	$ 9

Stock-Based Compensation (Detai

Stock-Based Compensation (Details)	12 Months Ended
	Dec. 31, 2022 USD ($) Integer $ / shares shares	Dec. 31, 2021 USD ($) $ / shares shares	Dec. 31, 2020 USD ($) $ / shares shares
All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	1,004,583
Granted (in shares)	620,708
Vested (in shares)	(427,095)
Forfeited (in shares)	(15,779)
Nonvested, end of period (in shares)	1,182,417	1,004,583
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 31.19
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	27.52	$ 28	$ 35.30
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	31.55
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	29.61
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 29.16	$ 31.19
Total fair value of units vested during the period | $	$ 12,000,000	$ 8,000,000	$ 19,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years
All Plans [Member] | Total Shareowner Return Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	633,773
Granted (in shares)	298,795
Vested (in shares)	0		0
Forfeited (in shares)	(245,861)
Nonvested, end of period (in shares)	686,707	633,773
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 34.68
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	34.27	$ 32.44	$ 37.63
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	35.48
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 34.21	$ 34.68
Total fair value of units vested during the period | $		$ 2,000,000
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200%
Fair value assumptions and methodology [Abstract]
Expected option life (in years)	3 years	3 years	3 years
Expected stock volatility	22.79%	27.81%	15.64%
All Plans [Member] | Total Shareowner Return Performance Units [Member] | Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	1 year
All Plans [Member] | Total Shareowner Return Performance Units [Member] | Not Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year
All Plans [Member] | Return On Equity Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	722,353
Granted (in shares)	257,199
Vested (in shares)	(470,182)
Nonvested, end of period (in shares)	509,370	722,353
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 31.28
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.81	$ 30.08	$ 34.95
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	30.76
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 31.53	$ 31.28
Total fair value of units vested during the period | $	$ 12,000,000	$ 16,000,000	$ 8,000,000
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200%
All Plans [Member] | Stock Options [Member]
Stock option activity [Roll Forward]
Outstanding at beginning of period (in shares)	766,002
Exercised (in shares)	(594,450)
Weighted average remaining contractual term (in years)	1 month 6 days
Outstanding at end of period (in shares)	171,552	766,002
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
Weighted-average exercise price per share at beginning of period (in dollars per share) | $ / shares	$ 26.57
Weighted average exercise price per share, exercised (in dollars per share) | $ / shares	26.44
Weighted average exercise price per share at end of period (in dollars per share) | $ / shares	$ 27.04	$ 26.57
Aggregate total intrinsic value | $	$ 0
Cash received from exercise of stock options | $	18,000,000	$ 10,000,000	8,000,000
All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	36,000,000	34,000,000	28,000,000
Income tax benefit | $	10,000,000	$ 10,000,000	$ 8,000,000
Unrecognized compensation expense | $	$ 23,000,000
Weighted-average period for recognition | Integer	1.8
All Plans [Member] | Earnings Growth Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	0
Granted (in shares)	141,880
Nonvested, end of period (in shares)	141,880	0
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 0
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	29.29
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 29.29	$ 0
All Plans [Member] | Environmental Social and Governance Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	0
Granted (in shares)	141,880
Nonvested, end of period (in shares)	141,880	0
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 0
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	29.29
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 29.29	$ 0
Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	15,000,000
Annual grant limit options (in shares)	2,000,000
Annual grant limit for individual participants - performance based awards (in shares)	750,000
Annual grant limit for individual participants - performance based awards | $	$ 15,000,000
Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2%
Annual grant limit options (in shares)	3,000,000
PPL Electric Utilities Corp [Member] | All Plans [Member] | Restricted Shares And Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	131,287
Transfer between registrants	(30,353)
Granted (in shares)	51,832
Vested (in shares)	(41,233)
Forfeited (in shares)	(1,747)
Nonvested, end of period (in shares)	109,786	131,287
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 31.50
Weighted-average grant date fair value per share, transfer between registrants (in dollars per share) | $ / shares	30.03
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	26.66	$ 27.96	$ 35.37
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	32.19
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	32.19
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 28.91	$ 31.50
Total fair value of units vested during the period | $	$ 1,000,000	$ 1,000,000	$ 3,000,000
Fair value assumptions and methodology [Abstract]
Award vesting period (in years)	3 years
PPL Electric Utilities Corp [Member] | All Plans [Member] | Total Shareowner Return Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	15,354
Granted (in shares)	14,238
Forfeited (in shares)	(3,113)
Nonvested, end of period (in shares)	26,479	15,354
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 34.36
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	34.42	$ 32.92	$ 38.64
Weighted-average grant date fair value per share, forfeited (in dollars per share) | $ / shares	35.58
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 34.25	$ 34.36
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Total Shareowner Return Performance Units [Member] | Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	1 year
PPL Electric Utilities Corp [Member] | All Plans [Member] | Total Shareowner Return Performance Units [Member] | Not Retirement Eligible [Member]
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Period over which performance units fair value is recognized (in years)	3 years
Minimum period after which employee stock options become exercisable (in years)	1 year
PPL Electric Utilities Corp [Member] | All Plans [Member] | Return On Equity Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	15,354
Granted (in shares)	3,663
Vested (in shares)	(6,311)
Nonvested, end of period (in shares)	12,706	15,354
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 30.27
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	30.70	$ 29.39	$ 35.59
Weighted-average grant date fair value per share, vested (in dollars per share) | $ / shares	30.78
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 30.14	$ 30.27
Total fair value of units vested during the period | $	$ 0	$ 0	$ 1,000,000
Period over which performance units fair value is recognized (in years)	3 years
Maximum payout percentage of target award	200%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Performance Units [Member]
Fair value assumptions and methodology [Abstract]
Expected option life (in years)	3 years	3 years	3 years
Expected stock volatility	22.79%	27.81%	15.64%
PPL Electric Utilities Corp [Member] | All Plans [Member] | Stock Options [Member]
Stock options - additional disclosures [Abstract]
Period after which, employee stock options expire (in years)	10 years
PPL Electric Utilities Corp [Member] | All Plans [Member] | All Awards [Member]
Aggregate disclosures [Abstract]
Compensation expense | $	$ 2,000,000	$ 11,000,000	$ 10,000,000
Income tax benefit | $	1,000,000	$ 3,000,000	$ 3,000,000
Unrecognized compensation expense | $	$ 2,000,000
Weighted-average period for recognition | Integer	1.8
PPL Electric Utilities Corp [Member] | All Plans [Member] | Earnings Growth Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	0
Granted (in shares)	6,888
Nonvested, end of period (in shares)	6,888	0
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 0
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	29.35
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 29.35	$ 0
PPL Electric Utilities Corp [Member] | All Plans [Member] | Environmental Social and Governance Performance Units [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested [Roll Forward]
Nonvested, beginning of period (in shares)	0
Granted (in shares)	6,888
Nonvested, end of period (in shares)	6,888	0
Awards, Equity Instruments Other than Options, additional disclosures (Details) [Abstract]
Weighted-average grant date fair value per share, nonvested, beginning of period (in dollars per share) | $ / shares	$ 0
Weighted-average grant date fair value per share, granted (in dollars per share) | $ / shares	29.35
Weighted-average grant date fair value per share, nonvested - end of period (in dollars per share) | $ / shares	$ 29.35	$ 0
PPL Electric Utilities Corp [Member] | Stock Incentive Plan [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	15,000,000
Annual grant limit options (in shares)	2,000,000
Annual grant limit for individual participants - performance based awards (in shares)	750,000
Annual grant limit for individual participants - performance based awards | $	$ 15,000,000
PPL Electric Utilities Corp [Member] | Incentive Compensation Plan For Key Employees [Member]
Stock-Based Compensation [Line Items]
Maximum number of shares approved for awards under the plan (in shares)	14,199,796
Annual grant limit total as % of PPL outstanding PPL common stock on first day of each calendar year	2%
Annual grant limit options (in shares)	3,000,000

Retirement and Postemployment_3

Retirement and Postemployment Benefits (Net Period Defined Benefit Costs (Credits) and Other Changes in Plan Assets and Benefit Obligations) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	$ 51	$ 56	$ 56
Interest cost	144	121	146
Expected return on plan assets	(276)	(255)	(246)
Amortization of:
Prior service cost (credit)	8	8	9
Actuarial (gain) loss	51	93	89
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(22)	23	54
Settlements	23	18	23
Net Periodic Defined Benefit Costs (Credits)	1	41	77
Net (loss)/gain allocated at acquisition	33	0	0
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	(23)	(18)	(23)
Net (gain) loss	242	42	(221)
Prior service costs (credit)	0	3	1
Amortization of: [Abstract]
Prior service (cost) credit	(8)	(8)	(9)
Actuarial gain (loss)	(51)	(93)	(89)
Total recognized in OCI and regulatory assets/liabilities	193	(74)	(341)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	194	(33)	(264)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	142	(70)	(428)
Regulatory assets/liabilities	51	(4)	87
Total recognized in OCI and regulatory assets/liabilities	193	(74)	(341)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		12	40
Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	7	6	6
Interest cost	20	16	19
Expected return on plan assets	(28)	(23)	(21)
Amortization of:
Prior service cost (credit)	1	1	1
Actuarial (gain) loss	(5)	(1)	0
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(5)	(1)	5
Settlements	0	0	0
Net Periodic Defined Benefit Costs (Credits)	(5)	(1)	5
Net (loss)/gain allocated at acquisition	(49)	0	0
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	0	(53)	(6)
Prior service costs (credit)	0	0	5
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	(1)
Actuarial gain (loss)	5	1	0
Total recognized in OCI and regulatory assets/liabilities	(45)	(53)	(2)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	(50)	(54)	3
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	13	(42)	(12)
Regulatory assets/liabilities	(58)	(11)	10
Total recognized in OCI and regulatory assets/liabilities	(45)	(53)	(2)
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		(1)	4
PPL Electric Utilities Corp [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		(9)	(2)
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts		(1)	2
Louisville Gas And Electric Co [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	0	(1)	4
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	2	2	2
Kentucky Utilities Co [Member] | Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	(3)	(3)	(1)
Kentucky Utilities Co [Member] | Other Postretirement Benefits Plan [Member]
Net Periodic Defined Benefit Costs (Credits) Charged to Operating Expense or Regulatory Assets, Excluding Amounts Charged to Construction and Other Non-expense Accounts (Details) [Abstract]
Net periodic defined benefit costs (credits) charged to operating expense or regulatory assets, excluding amounts charged to construction and other non-expense accounts	$ 0	$ 0	$ 0

Retirement and Postemployment_4

Retirement and Postemployment Benefits (Weighted-Average Assumptions, Cost Trend Rates and Funded Status) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	5.80%	3.15%
Benefit obligations valuation rate of compensation increase	3.77%	3.76%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	3.35%	2.92%	3.64%
Net periodic benefit costs rate of compensation increase	3.74%	3.76%	3.79%
Net periodic benefit costs expected return on plan assets	7.25%	7.25%	7.25%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	6.50%	6.25%	6.50%
Health care cost trend rate assumed for next year, cost	6.25%	6.50%	6.60%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), obligations	5%	5%	5%
Rate to which the cost trend rate is assumed to decline (the ultimate trend rate), cost	5%	5%	5%
Year that the rate reaches the ultimate trend rate, obligations	2029	2027	2027
Year that the rate reaches the ultimate trend rate, cost	2027	2027	2024
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 3,989	$ 4,251
Service cost	51	56	$ 56
Interest cost	144	121	146
Participant contributions	0	0
Plan Amendments	0	2
Actuarial (gain) loss	(1,026)	(88)
Acquisition	553	0
Settlements	(111)	(106)
Gross benefits paid	(267)	(247)
Benefit Obligation, end of period	3,333	3,989	4,251
Change in Plan Assets [Roll Forward]
Balance at beginning of period	3,887	4,068
Actual return on plan assets	(992)	125
Employer contributions	9	47
Participant contributions	0	0
Acquisition	623	0
Settlements	(111)	(106)
Gross benefits paid	(267)	(247)
Balance at end of period	3,149	3,887	$ 4,068
Funded Status, end of period	(184)	(102)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	33	91
Current liability	(10)	(10)
Noncurrent liability	(207)	(183)
Net amount recognized, end of period	(184)	(102)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	14	22
Net actuarial (gain) loss	827	626
Total	841	648
Total accumulated benefit obligation for defined benefit pension plans	3,197	3,786
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	183	239
Regulatory assets/liabilities	658	409
Total	841	648
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	2,818	193
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	2,601	0
Accumulated benefit obligation	1,720	177
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	$ 1,581	$ 0
Other Postretirement Benefits Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	5.81%	3.13%
Benefit obligations valuation rate of compensation increase	3.78%	3.77%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	3.54%	2.84%	3.60%
Net periodic benefit costs rate of compensation increase	2.84%	3.75%	3.76%
Net periodic benefit costs expected return on plan assets	6.52%	6.48%	6.44%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 504	$ 573
Service cost	7	6	$ 6
Interest cost	20	16	19
Participant contributions	9	14
Plan Amendments	0	0
Actuarial (gain) loss	(114)	(50)
Acquisition	163	0
Settlements	0	0
Gross benefits paid	(55)	(55)
Benefit Obligation, end of period	534	504	573
Change in Plan Assets [Roll Forward]
Balance at beginning of period	367	367
Actual return on plan assets	(86)	25
Employer contributions	19	18
Participant contributions	7	11
Acquisition	160	0
Settlements	0	0
Gross benefits paid	(50)	(54)
Balance at end of period	417	367	$ 367
Funded Status, end of period	(117)	(137)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	9	0
Current liability	(14)	(15)
Noncurrent liability	(112)	(122)
Net amount recognized, end of period	(117)	(137)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	11	12
Net actuarial (gain) loss	(95)	(51)
Total	(84)	(39)
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	13	(2)
Regulatory assets/liabilities	(97)	(37)
Total	(84)	(39)
PPL Electric Utilities Corp [Member]
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	0	50
PPL Electric Utilities Corp [Member] | Pension Plan [Member] | PPL Services Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	(34)	42
PPL Electric Utilities Corp [Member] | Other Postretirement Benefits Plan [Member] | PPL Services Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	(60)	(78)
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	41	85
Louisville Gas And Electric Co [Member] | Other Postretirement Benefits Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	(41)	(51)
Kentucky Utilities Co [Member] | Pension Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	44	75
Kentucky Utilities Co [Member] | Other Postretirement Benefits Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	$ (9)	$ (6)

Retirement and Postemployment_5

Retirement and Postemployment Benefits (Plan Assets and Expected Cash Flows) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Pension Plan [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,149	$ 3,887
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,887	4,068
Balance at end of period	3,149	3,887
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	9	$ 47
Expected amount of benefit payments in the next period for non-qualified plans	10
Estimated Future Benefit Payments (Details) [Abstract]
2022	282
2023	281
2024	283
2025	280
2026	275
2027-2030	$ 1,327
Pension Plan [Member] | Master Trust [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	100%	100%
Target Allocations (Details ) [Abstract]
Target asset allocation	100%
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)	10 years
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership	$ 116
Number Of Days Notice Required To Redeem Shares	45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,149	$ 3,887
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,887
Balance at end of period	$ 3,149	$ 3,887
Pension Plan [Member] | Master Trust [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	100%	100%
Target Allocations (Details ) [Abstract]
Target asset allocation	100%
Assumptions Used in Calculations (Numeric) [Abstract]
The limited lives of four partnership of private equity investments (in years)	10 years
The amount of potential liability that maybe required to be funded by the master trust during life of the partnership	$ 116
Number Of Days Notice Required To Redeem Shares	45 days
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 3,149	$ 3,887
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,887
Balance at end of period	3,149	3,887
Pension Plan [Member] | Master Trust [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	493	587
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	587
Balance at end of period	493	587
Pension Plan [Member] | Master Trust [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	493	587
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	587
Balance at end of period	493	587
Pension Plan [Member] | Master Trust [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	840	1,069
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,069
Balance at end of period	840	1,069
Pension Plan [Member] | Master Trust [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	840	1,069
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,069
Balance at end of period	840	1,069
Pension Plan [Member] | Master Trust [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	16	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20
Balance at end of period	16	20
Pension Plan [Member] | Master Trust [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	16	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20
Balance at end of period	16	20
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	306	266
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	306	266
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	306	266
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	306	266
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Cash And Cash Equivalents [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	574	754
Measured at fair value not using net asset value per share	34	41
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	574	754
Measured at fair value not using net asset value per share	34	41
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	34	41
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	34	41
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Equity Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | International Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	403	511
Pension Plan [Member] | Master Trust [Member] | International Equity Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	403	511
Pension Plan [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	526	677
Pension Plan [Member] | Master Trust [Member] | Commingled Debt Equity Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	526	677
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	153	281
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	153	281
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	153	280
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	153	280
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	1
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	1
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | US Treasury And US Government Sponsored Agency Debt Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	834	1,039
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	834	1,039
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	818	1,019
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	818	1,019
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	16	20
Fair value at end of period	16	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20	15
Purchases, sales and settlements	(4)	5
Balance at end of period	16	20
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	16	20
Fair value at end of period	16	20
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	20	15
Purchases, sales and settlements	(4)	5
Balance at end of period	16	20
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member] | LGE [Member]
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Actual return on plan assets relating to assets still held at the reporting date	(2)
Actual return on plan assets relating to assets sold during the period	2
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	14
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	14
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	14
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	14	14
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Other Debt Securities [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	60	69
Pension Plan [Member] | Master Trust [Member] | Real Estate Alternative Investments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	60	69
Pension Plan [Member] | Master Trust [Member] | Total Trust Assets Prior to Adjustments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	3,208	4,017
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,017
Balance at end of period	3,208	4,017
Pension Plan [Member] | Master Trust [Member] | Total Trust Assets Prior to Adjustments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	3,208	4,017
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	4,017
Balance at end of period	3,208	4,017
Pension Plan [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	96	92
Pension Plan [Member] | Master Trust [Member] | Private Equity Alternative Investments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	96	92
Pension Plan [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	194	236
Pension Plan [Member] | Master Trust [Member] | Hedge Fund Of Funds Alternative Investments [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	194	236
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	8	35
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	8	35
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | Level 1 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	8	35
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | Level 2 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	8	35
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Derivatives [Member] | Level 3 [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Pension Plan [Member] | Master Trust [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	67	25
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	25
Balance at end of period	67	25
Pension Plan [Member] | Master Trust [Member] | Receivables And Payables Net [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	67	25
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	25
Balance at end of period	67	25
Pension Plan [Member] | Master Trust [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	(126)	(155)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(155)
Balance at end of period	(126)	(155)
Pension Plan [Member] | Master Trust [Member] | Account 401 H [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	(126)	(155)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(155)
Balance at end of period	(126)	(155)
Pension Plan [Member] | Master Trust [Member] | Private credit partnership [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	6	2
Pension Plan [Member] | Master Trust [Member] | Private credit partnership [Member] | LKE [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	$ 6	$ 2
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	55%	55%
Target Allocations (Details ) [Abstract]
Target asset allocation	55%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	55%	55%
Target Allocations (Details ) [Abstract]
Target asset allocation	55%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	31%	32%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Equity Securities [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	31%	32%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	13%	13%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	13%	13%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	11%	10%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	11%	10%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	43%	43%
Target Allocations (Details ) [Abstract]
Target asset allocation	43%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	43%	43%
Target Allocations (Details ) [Abstract]
Target asset allocation	43%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	33%	35%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Debt Securities [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	33%	35%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	10%	8%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	10%	8%
Pension Plan [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	2%	2%
Target Allocations (Details ) [Abstract]
Target asset allocation	2%
Pension Plan [Member] | Master Trust [Member] | Liquidity Portfolio [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	2%	2%
Target Allocations (Details ) [Abstract]
Target asset allocation	2%
Other Postretirement Benefits Plan [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	100%	100%
Target Allocations (Details ) [Abstract]
Target asset allocation	100%
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 417	$ 367
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	367	367
Balance at end of period	417	367
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	19	18
Amount to be contributed to plan in the next fiscal year	27
Estimated Future Benefit Payments (Details) [Abstract]
2022	51
2023	50
2024	49
2025	48
2026	48
2027-2030	225
Expected Federal Subsidy (Details) [Abstract]
Federal subsidy 2022	0
Federal subsidy 2023	0
Federal subsidy 2024	0
Federal subsidy 2025	0
Federal subsidy 2026	0
Federal subsidy 2027-2030	1
Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	145	6
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	6
Balance at end of period	145	6
Other Postretirement Benefits Plan [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	0	38
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	38
Balance at end of period	0	38
Other Postretirement Benefits Plan [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	0	0
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	0
Balance at end of period	$ 0	$ 0
Other Postretirement Benefits Plan [Member] | Cash And Cash Equivalents [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	7%	3%
Target Allocations (Details ) [Abstract]
Target asset allocation	6%
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member]
Assumptions Used in Calculations (Numeric) [Abstract]
Number of months from date of purchase that investment must mature	13 months
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	$ 19	$ 6
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	19	6
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Money Market Funds [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	$ 0	$ 0
Other Postretirement Benefits Plan [Member] | Equity Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	45%	45%
Target Allocations (Details ) [Abstract]
Target asset allocation	44%
Other Postretirement Benefits Plan [Member] | United States Large Cap Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	$ 71	$ 96
Other Postretirement Benefits Plan [Member] | Commingled Debt Equity Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	$ 77	$ 75
Other Postretirement Benefits Plan [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	48%	52%
Target Allocations (Details ) [Abstract]
Target asset allocation	50%
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	$ 0	$ 38
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | Level 2 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	38
Other Postretirement Benefits Plan [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value not using net asset value per share	0	0
Other Postretirement Benefits Plan [Member] | Total Trust Assets Prior to Adjustments [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	293	215
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	215
Balance at end of period	293	215
Other Postretirement Benefits Plan [Member] | Receivables And Payables Net [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	(2)	(3)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(3)
Balance at end of period	(2)	(3)
Other Postretirement Benefits Plan [Member] | Account 401 H [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	126	155
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	155
Balance at end of period	126	$ 155
Other Postretirement Benefits Plan [Member] | Global equity exchange traded-fund [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	61
Other Postretirement Benefits Plan [Member] | Global equity exchange traded-fund [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	61
Other Postretirement Benefits Plan [Member] | Long-term bond exchange-traded fund [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	65
Other Postretirement Benefits Plan [Member] | Long-term bond exchange-traded fund [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Measured at fair value using net asset value per share	65
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member]
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Actual return on plan assets relating to assets still held at the reporting date	(2)
Actual return on plan assets relating to assets sold during the period	$ 2

Retirement and Postemployment_6

Retirement and Postemployment Benefits (Savings Plans and Employee Stock Ownership Plan) (Details) - Deferred Savings Plans 401K [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 36	$ 29	$ 29
PPL Electric Utilities Corp [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	6	5	6
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	7	7	6
Kentucky Utilities Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 5	$ 5	$ 5

Jointly Owned Facilities (Detai

Jointly Owned Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75%	75%
Electric plant	$ 455	$ 457
Accumulated depreciation	94	79
Construction work in progress	$ 1	$ 0
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75%	75%
Electric plant	$ 1,372	$ 1,360
Accumulated depreciation	276	247
Construction work in progress	$ 148	$ 121
Louisville Gas And Electric Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	38%	38%
Electric plant	$ 53	$ 53
Accumulated depreciation	25	24
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	53%	53%
Electric plant	$ 51	$ 51
Accumulated depreciation	27	25
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75%	75%
Electric plant	$ 455	$ 457
Accumulated depreciation	94	79
Construction work in progress	$ 1	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	14.25%	14.25%
Electric plant	$ 384	$ 379
Accumulated depreciation	66	57
Construction work in progress	$ 78	$ 64
Louisville Gas And Electric Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	29%	29%
Electric plant	$ 36	$ 36
Accumulated depreciation	16	15
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	37%	37%
Electric plant	$ 81	$ 81
Accumulated depreciation	36	34
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	22%	22%
Electric plant	$ 126	$ 125
Accumulated depreciation	21	19
Construction work in progress	$ 2	$ 0
Louisville Gas And Electric Co [Member] | E W Brown Solar Unit [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	39%	39%
Electric plant	$ 10	$ 10
Accumulated depreciation	3	2
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Jointly Owned Solar Share [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	44%	44%
Electric plant	$ 3	$ 2
Accumulated depreciation	0	0
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | E W Brown Units 6 And 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	62%	62%
Electric plant	$ 87	$ 88
Accumulated depreciation	42	40
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Paddys Run Unit 13 And E W Brown Unit 5 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	47%	47%
Electric plant	$ 45	$ 45
Accumulated depreciation	23	22
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	60.75%	60.75%
Electric plant	$ 987	$ 981
Accumulated depreciation	210	190
Construction work in progress	$ 70	$ 57
Kentucky Utilities Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	71%	71%
Electric plant	$ 84	$ 84
Accumulated depreciation	38	36
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Trimble County Units 7 Through 10 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	63%	63%
Electric plant	$ 133	$ 133
Accumulated depreciation	61	57
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	78%	78%
Electric plant	$ 446	$ 444
Accumulated depreciation	77	70
Construction work in progress	$ 6	$ 0
Kentucky Utilities Co [Member] | E W Brown Solar Unit [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	61%	61%
Electric plant	$ 16	$ 16
Accumulated depreciation	5	4
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Jointly Owned Solar Share [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	56%	56%
Electric plant	$ 4	$ 3
Accumulated depreciation	0	0
Construction work in progress	$ 0	$ 0

Commitments and Contingencies_2

Commitments and Contingencies (Energy Purchases, Energy Sales, Other Commitments and Legal Matters) (Details) $ in Millions		12 Months Ended
	Nov. 18, 2014 USD ($)	Dec. 31, 2022 USD ($) MW	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Jul. 01, 2022 MW	Dec. 06, 2018 MW	Apr. 09, 2018 MW	Oct. 01, 2015 MW	Jun. 01, 2015	Dec. 31, 2014 MW	May 01, 2012 MW	Jul. 01, 2011 MW	Jun. 30, 2010 MW
Claim By Former Affiliate [Abstract]
Restructuring And Related Activities Ownership Percentage By Riverstone									35%
Proceeds from Divestiture of Businesses and Interests in Affiliates	$ 900
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
LTCS Renewable Energy Contract, Deepwater Agreement, Power | MW													30
LTCS Renewable Energy Contract, Three-State Procurement, Power | MW							36.75
LTCS Renewable Energy Contract, Offshore Wind Energy Procurement, Power | MW						408
LTCS Renewable Energy Contracting Capacity Requirement | MW										90
LTCS Renewable Energy Contract, First Solicitation, Power | MW												3.2
LTCS Renewable Energy Contract, Second Solicitation, Power | MW											3.9
LTCS Renewable Energy Contract, Third Solicitation, Power | MW								80
Amount of MW Required to Meet LTCS Renewable Energy Contracting Capacity Requirement | MW		12
Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
ACES Renewable Energy Contracting Capacity Requirement | MW					600
Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
ACES Renewable Energy Contracting Capacity Requirement | MW					1,000
Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023		$ 34
2024		32
2025		32
2026		32
2027		32
Thereafter		265
Total		427
Purchases		30	$ 19	$ 18
Rhode Island Energy | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023		471
Thereafter		279
Total		995
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
2024-2025		172
2026-2027		73
Louisville Gas And Electric Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023		24
2024		22
2025		22
2026		22
2027		22
Thereafter		184
Total		296
Purchases		21	13	12
Kentucky Utilities Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023		10
2024		10
2025		10
2026		10
2027		10
Thereafter		81
Total		131
Purchases		9	6	$ 6
PPL Electric Additional Sites [Member] | PPL Electric [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies		11	10
PPL Electric Additional Sites [Member] | PPL Electric Utilities Corp [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies		$ 11	$ 10

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Matter and Other) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2019 customers	Dec. 31, 2021 USD ($)
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Period RIE Environmental Remediation Costs To Be Incurred Over	30 years
Period Over Which Distribution Adjustment Charge-related Costs Are amortized	10 years
Number of customers impacted by Aquidneck Island loss of gas supply | customers		7,500
Electric Rates [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental Costs Recognized, Recovery Credited to Expense	$ 3
Gas Rates [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental Costs Recognized, Recovery Credited to Expense	1
RIE Environmental Remediation
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	100
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	11		$ 10
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	$ 11		$ 10

Commitments and Contingencies_4

Commitments and Contingencies (Guarantees and Other Assurances) (Details) - 12 months ended Dec. 31, 2022 £ in Millions, $ in Millions	USD ($)	GBP (£)
Guarantor Obligations [Line Items]
Maximum Aggregate Liability for Safari Indemnification	$ 140
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage	225
Indemnification Cap, Surrenders of Tax Losses | £		£ 50
Indemnification for Safari sale/leaseback	25
Guarantee Maximum Exposure for Safari Indemnification	148
Guarantee Maximum Exposure PPAs	55
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business
Guarantor Obligations [Line Items]
Maximum exposure	50
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee of payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings
Guarantor Obligations [Line Items]
Maximum exposure	148
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee of payment obligations under certain power purchase agreements related to the sale of Safari Holdings
Guarantor Obligations [Line Items]
Maximum exposure	55
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings
Guarantor Obligations [Line Items]
Maximum exposure	140
LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	89
Louisville Gas And Electric Co [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	62
Kentucky Utilities Co [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	27
LGE [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	62
KU [Member] | LGE And KU Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Contingent potential proportionate share of OVEC's outstanding debt	$ 27

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable, Related Parties, Current	$ 0	$ 499
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	241	54	$ 50
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable		11
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Accounts receivable from affiliates [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable		10
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Other Noncurrent Assets [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable		1
PPL Electric Utilities Corp [Member] | PPL EU Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	0	222	176
PPL Electric Utilities Corp [Member] | PPL Energy Funding [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	1,200
Notes Receivable, Related Parties, Current	0	499
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc.
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	500
Notes Receivable, Related Parties, Current	0	0
Louisville Gas And Electric Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	0	324
Louisville Gas And Electric Co [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	13	3	2
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	0	324
Intercompany Money Pool Agreement Unused Borrowing Capacity	250
Louisville Gas And Electric Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	153	169	170
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	0	294
Kentucky Utilities Co [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	14	3	2
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes payable to affiliates	0	294
Intercompany Money Pool Agreement Unused Borrowing Capacity	250
Kentucky Utilities Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 171	$ 179	$ 180

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Other Income [Line Items]
Defined benefit plans - non-service credits	$ 47	$ 21	$ (2)
Interest income	4	12	9
Allowance for funds used during construction - equity component	22	18	20
Other Expense [Line Items]
Charitable contributions	(14)	(14)	(3)
Miscellaneous	(5)	(22)	(22)
Other Income (Expense) - net	54	15	2
PPL Electric Utilities Corp [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	15	9	4
Interest income	3	0	2
Allowance for funds used during construction - equity component	16	18	19
Other Expense [Line Items]
Charitable contributions	(3)	(3)	(3)
Miscellaneous	(1)	(3)	(4)
Other Income (Expense) - net	$ 30	$ 21	$ 18

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Level 3 [Member] | Rhode Island Regulated
Price risk management liabilities:
Gas contracts, Liability	$ 56	$ 0
Gas Contracts Included in Regulatory Assets	56
Recurring [Member]
Price risk management liabilities:
Cash and cash equivalents	356	3,571
Restricted cash and cash equivalents	1	1
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	357	3,572
Money market fund	1	2
Commingled debt fund measured at NAV	13	22
Commingled equity fund measured at NAV	11	21
Total special use funds	25	45
Gas Purchase Contract, Fair Value Disclosure	25	0
Total Assets	407	3,617
Interest rate swaps	7	18
Gas contracts, Liability	66	0
Liability value	73	18
Recurring [Member] | PPL Electric Utilities Corp [Member]
Price risk management liabilities:
Cash and cash equivalents	25	21
Total Assets	25	21
Recurring [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Price risk management liabilities:
Cash and cash equivalents	93	9
Total Assets	93	9
Interest rate swaps	7	18
Liability value	7	18
Recurring [Member] | Kentucky Utilities Co [Member]
Price risk management liabilities:
Cash and cash equivalents	21	13
Total Assets	21	13
Recurring [Member] | Level 1 [Member]
Price risk management liabilities:
Cash and cash equivalents	356	3,571
Restricted cash and cash equivalents	1	1
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	357	3,572
Money market fund	1	2
Total special use funds	1	2
Gas Purchase Contract, Fair Value Disclosure	0	0
Total Assets	358	3,574
Interest rate swaps	0	0
Gas contracts, Liability	0	0
Liability value	0	0
Recurring [Member] | Level 1 [Member] | PPL Electric Utilities Corp [Member]
Price risk management liabilities:
Cash and cash equivalents	25	21
Total Assets	25	21
Recurring [Member] | Level 1 [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Price risk management liabilities:
Cash and cash equivalents	93	9
Total Assets	93	9
Interest rate swaps	0	0
Liability value	0	0
Recurring [Member] | Level 1 [Member] | Kentucky Utilities Co [Member]
Price risk management liabilities:
Cash and cash equivalents	21	13
Total Assets	21	13
Recurring [Member] | Level 2 [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	0	0
Money market fund	0	0
Total special use funds	0	0
Gas Purchase Contract, Fair Value Disclosure	25	0
Total Assets	25	0
Interest rate swaps	7	18
Gas contracts, Liability	10	0
Liability value	17	18
Recurring [Member] | Level 2 [Member] | PPL Electric Utilities Corp [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Total Assets	0	0
Recurring [Member] | Level 2 [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Total Assets	0	0
Interest rate swaps	7	18
Liability value	7	18
Recurring [Member] | Level 2 [Member] | Kentucky Utilities Co [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Total Assets	0	0
Recurring [Member] | Level 3 [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	0	0
Money market fund	0	0
Total special use funds	0	0
Gas Purchase Contract, Fair Value Disclosure	0	0
Total Assets	0	0
Interest rate swaps	0	0
Gas contracts, Liability	56	0
Liability value	56	0
Recurring [Member] | Level 3 [Member] | PPL Electric Utilities Corp [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Total Assets	0	0
Recurring [Member] | Level 3 [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Total Assets	0	0
Interest rate swaps	0	0
Liability value	0	0
Recurring [Member] | Level 3 [Member] | Kentucky Utilities Co [Member]
Price risk management liabilities:
Cash and cash equivalents	0	0
Total Assets	0	0
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	13,243	11,140
Carrying Amount [Member] | PPL Electric Utilities Corp [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	4,486	4,484
Carrying Amount [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,307	2,006
Carrying Amount [Member] | Kentucky Utilities Co [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,920	2,618
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	12,239	12,955
Fair Value [Member] | PPL Electric Utilities Corp [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	4,259	5,272
Fair Value [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,128	2,363
Fair Value [Member] | Kentucky Utilities Co [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 2,616	$ 3,120

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	$ 0	$ 0
Cash Collateral Posted Under Master Netting Arrangements	4	0
Louisville Gas And Electric Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash Collateral Posted Under Master Netting Arrangements	0	0
Kentucky Utilities Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash Collateral Obligation Under Master Netting Arrangement	0	0
Cash Collateral Posted Under Master Netting Arrangements	$ 0	$ 0

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities (Risk Disclosures) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Cash Flow Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Gain (Loss) on Discontinuation of Interest Rate Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	$ 0	$ 0	$ 0
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	64
Rhode Island Energy | Economic Hedges [Member] | Gas Contract
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	15
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk And Foreign Currency Risk [Line Items]
Derivative, Notional Amount	$ 64

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities (Fair Values) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Derivatives Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 0	$ 0
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	0
Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	25	0
Liability value	73	18
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	20	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Asset value	20	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Asset value	5	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	63	1
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	1
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	62	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	10	17
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	6	17
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	4	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	7	18
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	1
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	1	1
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	6	17
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	$ 6	$ 17

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Derivative Instruments Gain Loss [Line Items]
Interest Expense	$ 513	$ 918	$ 634
Other Income (Expense) - net	54	15	2
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Income (Loss) from Discontinued Operations (net of income taxes)	42	(1,498)	829
Cash Flow Hedges [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(3)	(30)	(32)
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	0	(50)	(24)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	0	0	(9)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(3)	11	(8)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(3)	11	(8)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Discontinued Operations (net of income taxes)
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income		(2)	(2)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income		(2)	(2)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI		(50)	(15)
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Other Income (Expense) Net [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0
Hedged Items	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0	0	0
Hedged Items	0	0	0
Cash Flow Hedges [Member] | Cross Currency Swaps [Member] | Discontinued Operations (net of income taxes)
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income		(39)	(22)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income		(39)	(22)
Hedged Items		39	22
Net Investment Hedges [Member] | Foreign Currency Contracts [Member] | Discontinued Operations (net of income taxes)
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI		1	1
Derivatives Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Gas Contract | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Gas Contract | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0	0
Derivatives Designated As Hedging Instruments [Member] | Gas Contract | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Designated As Hedging Instruments [Member] | Gas Contract | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0	0
Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	39	(268)	(103)
Gain (loss) recognized as regulatory liabilities/assets	50	5	(2)
Asset value	25	0
Liability value	73	18
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	20	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	63	1
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	5	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	10	17
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ (2)	(2)	(5)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	$ 0	0
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1	1
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	6	17
Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	11	5	(2)
Derivatives Not Designated As Hedging Instruments [Member] | Foreign Currency Contracts [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ 0	(266)	(98)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Income (Loss) from Discontinued Operations (net of income taxes)
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ 41	0	0
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Energy purchases
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	$ 20	0
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	62	0
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	5	0
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	4	0
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Regulatory Assets Current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	39	0	0
Louisville Gas And Electric Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	89	81	87
Other Income (Expense) - net	4	(5)	(1)
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Liability value	7	18
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1	1
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	6	17
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	$ (2)	(2)	(5)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	$ 0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1	1
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	6	17
Louisville Gas And Electric Co [Member] | Derivatives Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	11	5	(2)
Kentucky Utilities Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense	117	109	113
Other Income (Expense) - net	$ 8	$ 4	$ 3

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities (Offsetting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	$ 0	$ 0
Cash collateral pledged eligible for offset - liabilities	4	0
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	25	0
Derivative instruments eligible for offset - assets	20	0
Cash collateral received eligible for offset - assets	0	0
Net assets	5	0
Gross liabilities	73	18
Derivative instruments eligible for offset - liabilities	62	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	11	18
Louisville Gas And Electric Co [Member]
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	0	0
Derivative instruments eligible for offset - assets	0	0
Cash collateral received eligible for offset - assets	0	0
Net assets	0	0
Gross liabilities	7	18
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	7	18
Kentucky Utilities Co [Member]
Offsetting Assets And Liabilities [Line Items]
Cash collateral received eligible for offset - assets	0	0
Cash collateral pledged eligible for offset - liabilities	$ 0	$ 0

Goodwill and Other Intangible_3

Goodwill and Other Intangible Assets (Goodwill) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	$ 716
Goodwill recognized during the period	1,586	$ 0
Sale of Safari Holdings	(53)	0
Balance at end of period	2,248	716
Goodwill		715	$ 715
Kentucky Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	662	662
Goodwill recognized during the period	0	0
Sale of Safari Holdings	0	0
Balance at end of period	662	662
Corporate And Other [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	53	53
Goodwill recognized during the period	861	0
Sale of Safari Holdings	(53)	0
Balance at end of period	861	53
Rhode Island Regulated
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	0	0
Goodwill recognized during the period	725	0
Sale of Safari Holdings	0	0
Balance at end of period	$ 725	$ 0

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets (Other Intangibles - Finite-Lived) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Subject to amortization: [Abstract]
Gross carrying amount	$ 548	$ 551
Accumulated amortization	238	231
Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	125	125
Accumulated amortization	99	90
Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	407	406
Accumulated amortization	138	135
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	2	20
Accumulated amortization	1	6
Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	5	9	$ 7
Forecasted amortization in 2021	5
Forecasted amortization in 2022	5
Forecasted amortization in 2023	5
Forecasted amortization in 2024	4
Forecasted amortization in 2025	4
Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	9	8	8
Forecasted amortization in 2021	9
Forecasted amortization in 2022	8
Forecasted amortization in 2023	8
Forecasted amortization in 2024	2
Forecasted amortization in 2025	0
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	14	17	15
Forecasted amortization in 2021	14
Forecasted amortization in 2022	13
Forecasted amortization in 2023	13
Forecasted amortization in 2024	6
Forecasted amortization in 2025	4
Renewable energy credit
Subject to amortization: [Abstract]
Gross carrying amount	14	0
Accumulated amortization	0	0
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount	387	384
Accumulated amortization	135	131
PPL Electric Utilities Corp [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	385	382
Accumulated amortization	134	130
PPL Electric Utilities Corp [Member] | Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	2	2
Accumulated amortization	1	1
PPL Electric Utilities Corp [Member] | Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	4	4	4
Forecasted amortization in 2021	4
Forecasted amortization in 2022	4
Forecasted amortization in 2023	4
Forecasted amortization in 2024	4
Forecasted amortization in 2025	4
Louisville Gas And Electric Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	93	93
Accumulated amortization	69	63
Louisville Gas And Electric Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	7	7
Accumulated amortization	1	1
Louisville Gas And Electric Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	86	86
Accumulated amortization	68	62
Louisville Gas And Electric Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	6	5	6
Forecasted amortization in 2021	6
Forecasted amortization in 2022	6
Forecasted amortization in 2023	6
Forecasted amortization in 2024	1
Forecasted amortization in 2025	0
Kentucky Utilities Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	55	55
Accumulated amortization	34	32
Kentucky Utilities Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	16	16
Accumulated amortization	3	4
Kentucky Utilities Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	39	39
Accumulated amortization	31	28
Kentucky Utilities Co [Member] | Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	0	1	0
Kentucky Utilities Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	3	$ 3	$ 2
Forecasted amortization in 2021	3
Forecasted amortization in 2022	2
Forecasted amortization in 2023	2
Forecasted amortization in 2024	1
Forecasted amortization in 2025	$ 0

Goodwill and Other Intangible_5

Goodwill and Other Intangible Assets (Other Intangibles - Indefinite-Lived) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	$ 17	$ 23
Gross carrying amount - other intangible assets	565	574
Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	5	9	$ 7
Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	17	17
Other [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	0	6
PPL Electric Utilities Corp [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets	404	401
PPL Electric Utilities Corp [Member] | Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	4	4	4
PPL Electric Utilities Corp [Member] | Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	17	17
Kentucky Utilities Co [Member] | Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	$ 0	$ 1	$ 0

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 189	$ 182
Asset Retirement Obligation acquired in an acquisition	10	0
Accretion	6	16
Obligations incurred	2	0
Changes in estimated cash flow or settlement date	15	56
Obligations settled	(45)	(65)
Balance at End of Period	177	189
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	84	67
Asset Retirement Obligation acquired in an acquisition	0	0
Accretion	3	5
Obligations incurred	2	0
Changes in estimated cash flow or settlement date	12	40
Obligations settled	(15)	(28)
Balance at End of Period	86	84
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	105	115
Asset Retirement Obligation acquired in an acquisition	0	0
Accretion	3	11
Obligations incurred	0	0
Changes in estimated cash flow or settlement date	4	16
Obligations settled	(30)	(37)
Balance at End of Period	$ 82	$ 105

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	$ (157)	$ (4,220)	$ (4,358)
Amounts arising during the year	12	332	(94)
Reclassifications from AOCI	21	153	232
Net OCI during the year	33	4,063	138
Balance at end of year	(124)	(157)	(4,220)
Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI		3,578
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	(1,158)	(1,425)
Amounts arising during the year	0	372	267
Reclassifications from AOCI	0	0	0
Net OCI during the year	0	1,158	267
Balance at end of year	0	0	(1,158)
Foreign Currency Translation Adjustments [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI		786
Qualifying Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	1	0	(5)
Amounts arising during the year	0	(39)	(19)
Reclassifications from AOCI	2	25	24
Net OCI during the year	2	1	5
Balance at end of year	3	1	0
Qualifying Derivatives [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI		15
Equity Investees AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	0	0
Amounts arising during the year	2	0	0
Reclassifications from AOCI	0	0	0
Net OCI during the year	2	0	0
Balance at end of year	2	0	0
Equity Investees AOCI [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI		0
Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(6)	(16)	(18)
Amounts arising during the year	(1)	0	(1)
Reclassifications from AOCI	2	2	3
Net OCI during the year	1	10	2
Balance at end of year	(5)	(6)	(16)
Prior Service Costs [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI		8
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(152)	(3,046)	(2,910)
Amounts arising during the year	11	(1)	(341)
Reclassifications from AOCI	17	126	205
Net OCI during the year	28	2,894	(136)
Balance at end of year	$ (124)	(152)	$ (3,046)
Defined Benefit Plans Actuarial Gain (Loss) [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Accumulated Other Comprehensive Income (Loss) [Line Items]
Reclassifications from AOCI		$ 2,769

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Affected Line Item on the Statements of Income
Interest Expense	$ (513)	$ (918)	$ (634)
Other Income (Expense) - net	54	15	2
Total Pre-tax	915	521	954
Income Taxes	(201)	(503)	(314)
Income (Loss) from Discontinued Operations (net of income taxes)	42	(1,498)	829
Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income Taxes	0	(660)	0
Income (Loss) from Discontinued Operations (net of income taxes)	0	(3,578)	0
Income from Discontinued Operations, before Income Tax	0	(4,238)	0
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total After-Tax	(21)	(3,731)	(232)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(3)	(30)	(32)
Income Taxes	1	5	8
Total After-Tax	(2)	(25)	(24)
Qualifying Derivatives [Member] | Interest Rate Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Interest Expense	(3)	11	(8)
Income (Loss) from Discontinued Operations (net of income taxes)	0	(2)	(2)
Qualifying Derivatives [Member] | Cross Currency Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Income (Loss) from Discontinued Operations (net of income taxes)	0	39	22
Defined Benefit Plans [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income (Loss) from Discontinued Operations (net of income taxes)	0	(3,577)	0
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(27)	(162)	(260)
Income Taxes	8	34	52
Total After-Tax	(19)	(128)	(208)
Defined Benefit Plans [Member] | Prior Service Costs [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(3)	(3)	(4)
Defined Benefit Plans [Member] | Net Actuarial Loss [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(24)	(159)	(256)
Accumulated Foreign Currency Adjustment Attributable to Parent [Member] | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income (Loss) from Discontinued Operations (net of income taxes)	0	(646)	0
Accumulated Gain (Loss), Net, Cash Flow Hedge, Parent | Reclassification out of Accumulated Other Comprehensive Income (Loss) due to Sale of U.K, Utility Business
Affected Line Item on the Statements of Income
Income (Loss) from Discontinued Operations (net of income taxes)	$ 0	$ (15)	$ 0

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Details) $ in Millions	Dec. 31, 2022 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 60
Current lease liabilities	22
Non-current lease liabilities	42
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	13
Current lease liabilities	6
Non-current lease liabilities	9
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	19
Current lease liabilities	8
Non-current lease liabilities	$ 12