PPL (PPL) 10-K 13 Feb 25 2021 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2024	Jan. 31, 2025	Jun. 30, 2023
Document Entity Information [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2024
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	645 Hamilton Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101
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		738,294,081
Entity Public Float			$ 20,399,126,544
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 2025 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, 2024 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	827 Hausman Road
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18104-9392
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Operating Revenues
Operating Revenues		$ 8,462	$ 8,312	$ 7,902
Operation
Fuel		783	733	931
Energy purchases		1,679	1,841	1,686
Other operation and maintenance		2,607	2,462	2,398
Depreciation		1,279	1,254	1,181
Taxes, other than income		374	392	332
Total Operating Expenses		6,722	6,682	6,528
Operating Income		1,740	1,630	1,374
Other Income (Expense) - net		114	(40)	54
Interest Expense, Operating and Nonoperating		738	666	513
Income from Continuing Operations Before Income Taxes		1,116	924	915
Income Taxes		228	184	201
Income from Continuing Operations After Income Taxes		888	740	714
Income (Loss) from Discontinued Operations (net of income taxes)		0	0	42
Net income (Loss)		$ 888	$ 740	$ 756
Earnings per Share of Common Stock [Abstract]
Income from Continuing Operations After Income Taxes, Per Basic Share		$ 1.20	$ 1	$ 0.97
Income (Loss) from Discontinued Operation ( net of income taxes), Per Basic Shares		0	0	0.06
Net Income (Loss) Available to PPL Common , Per Basic shares		1.20	1	1.03
Income from Continuing Operations After Income Taxes, Per Diluted Share		1.20	1	0.96
Net Income (Loss) Available to PPL Common Shareowners, Per Diluted Shares		1.20	1	1.02
Income (Loss) from Discontinued Operations (net of income taxes), Per Diluted Shares		$ 0	$ 0	$ 0.06
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic		737,756	737,036	736,027
Diluted		739,853	738,166	736,902
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 2,876	$ 3,008	$ 3,030
Operation
Energy purchases		721	992	1,048
Other operation and maintenance		705	605	605
Depreciation		401	397	393
Taxes, other than income		131	143	149
Total Operating Expenses		1,958	2,137	2,195
Operating Income		918	871	835
Other Income (Expense) - net		45	39	30
Interest Expense, Operating and Nonoperating		246	223	171
Income from Continuing Operations Before Income Taxes		750	687	699
Income Taxes		176	168	174
Net income (Loss)	[1]	574	519	525
PPL Electric Utilities Corp [Member] | Related Party
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Interest income		33	0	5
Louisville Gas And Electric Co [Member]
Operating Revenues
Operating Revenues		1,648	1,613	1,798
Operation
Fuel		308	286	346
Energy purchases		151	168	245
Energy purchases from affiliate		20	12	25
Other operation and maintenance		349	364	416
Depreciation		305	302	298
Taxes, other than income		49	48	48
Total Operating Expenses		1,182	1,180	1,378
Operating Income		466	433	420
Other Income (Expense) - net		12	3	4
Interest Expense, Operating and Nonoperating		105	102	89
Income from Continuing Operations Before Income Taxes		374	335	335
Income Taxes		77	69	63
Net income (Loss)	[2]	297	266	272
Louisville Gas And Electric Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		1,617	1,580	1,762
Louisville Gas And Electric Co [Member] | Related Party
Operating Revenues
Retail and wholesale		31	33	36
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Interest income		1	1	0
Kentucky Utilities Co [Member]
Operating Revenues
Operating Revenues		1,964	1,884	2,074
Operation
Fuel		476	447	585
Energy purchases		25	24	28
Energy purchases from affiliate		31	33	36
Other operation and maintenance		413	427	487
Depreciation		403	392	386
Taxes, other than income		49	45	45
Total Operating Expenses		1,397	1,368	1,567
Operating Income		567	516	507
Other Income (Expense) - net		15	8	8
Income from Continuing Operations Before Income Taxes		445	389	398
Income Taxes		89	77	76
Net income (Loss)	[3]	356	312	322
Kentucky Utilities Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		1,944	1,872	2,049
Operation
Interest Expense, Operating and Nonoperating		137	134	117
Kentucky Utilities Co [Member] | Related Party
Operating Revenues
Retail and wholesale		20	12	25
Operation
Interest Expense, Operating and Nonoperating		$ 0	$ 1	$ 0
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Net income (loss)	$ 888	$ 740	$ 756
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investee's other comprehensive income after tax	1	1	2
Defined benefit plans:
Prior service costs, net of tax	0	0	(1)
Net actuarial gain (loss), net of tax	(22)	(41)	11
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	3	3	2
Defined benefit plans:
Prior service costs, net of tax	1	1	2
Net actuarial (gain) loss, net of tax	(4)	(3)	17
Total other comprehensive income (loss)	(21)	(39)	33
Comprehensive income	$ 867	$ 701	$ 789

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
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	8	15	(2)
Tax effect of qualifying derivatives reclassified from AOCI	0	0	(1)
Tax effect of defined benefit plans - prior service costs reclassified from AOCI	0	(1)	(1)
Tax effect of defined benefit plans - net actuarial (gain) loss reclassified from AOCI	0	0	(7)
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Cash Flows from Operating Activities
Net income (loss)		$ 888	$ 740	$ 756
Loss (income) from discontinued operations (net of income taxes)		0	0	(42)
Income from Continuing Operations After Income Taxes		888	740	714
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		1,279	1,254	1,181
Amortization		78	81	52
Defined benefit plans - expense (income)		(72)	(73)	(16)
Deferred income taxes and investment tax credits		196	322	179
Loss on sale of Safari Holdings		0	0	60
Stock compensation expense		46	33	37
Other		(17)	(29)	14
Change in current assets and current liabilities
Accounts receivable		254	(170)	(176)
Accounts payable		(41)	(72)	358
Unbilled Revenues		(57)	128	(197)
Fuel, materials and supplies		(2)	(60)	(90)
Prepayments		(34)	1	(13)
Taxes payable		(27)	6	(80)
Regulatory assets and liabilities, net		(68)	(37)	(119)
Other		(65)	38	(76)
Defined benefits plans - funding		(10)	(13)	(12)
Other operating activities
Proceeds from transfer of excess benefit plan funds		13	0	0
Other assets		(96)	(69)	(126)
Other liabilities		42	(349)	39
Net cash provided by operating activities		2,340	1,758	1,730
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(2,805)	(2,390)	(2,155)
Proceeds from sale of Safari Holdings, net of cash divested		0	0	146
Acquisition of Narragansett Electric, net of cash acquired		0	0	(3,660)
Other investing activities		(13)	7	15
Net cash provided by (used in) investing activities		(2,818)	(2,383)	(5,654)
Cash Flows from Financing Activities
Issuance of long-term debt		1,894	3,252	850
Retirement of long-term debt		0	(1,854)	(264)
Payment of common stock dividends		(747)	(704)	(787)
Net increase (decrease) in short-term debt		(689)	7	916
Other investing activities		(23)	(51)	(6)
Net cash provided by (used in) financing activities		435	650	709
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(43)	25	(3,215)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		382	357	3,572
Cash, Cash Equivalents and Restricted Cash at End of Period		339	382	357
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		670	604	462
Income taxes - net		(123)	281	163
Accrued expenditures for property, plant and equipment at December 31,		358	220	269
Accrued interest		33	27	1
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	574	519	525
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		401	397	393
Amortization		45	41	22
Defined benefit plans - expense (income)		(39)	(42)	(23)
Deferred income taxes and investment tax credits		129	46	91
Other		1	(24)	(11)
Change in current assets and current liabilities
Accounts receivable		89	(78)	(47)
Accounts payable		64	13	46
Unbilled Revenues		(10)	75	(95)
Fuel, materials and supplies		6	(30)	(11)
Prepayments		(32)	2	(2)
Taxes payable		(49)	15	5
Regulatory assets and liabilities, net		(101)	(38)	(59)
Other		(25)	9	(19)
Defined benefits plans - funding		0	(5)	0
Other operating activities
Other assets		(32)	3	(47)
Other liabilities		9	1	(11)
Net cash provided by operating activities		1,042	912	757
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,229)	(956)	(886)
Expenditures for intangible assets		(9)	(6)	(2)
Net (increase) decrease in notes receivable from affiliate		(222)	0	499
Other investing activities		5	4	2
Net cash provided by (used in) investing activities		(1,455)	(958)	(387)
Cash Flows from Financing Activities
Issuance of long-term debt		649	1,329	250
Retirement of long-term debt		0	(1,240)	(250)
Contributions from parent		688	206	0
Payment of common stock dividends to parent		(375)	(323)	(340)
Return of Capital to Parent		(60)	(250)	(170)
Net increase (decrease) in short-term debt		(509)	364	145
Debt Issuance Costs		(7)	(14)	0
Other investing activities		0	0	(1)
Net cash provided by (used in) financing activities		386	72	(366)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(27)	26	4
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51	25	21
Cash, Cash Equivalents and Restricted Cash at End of Period		24	51	25
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		224	205	164
Income taxes - net		83	92	111
Accrued expenditures for property, plant and equipment at December 31,		173	122	133
Accrued interest		12	8	0
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[2]	297	266	272
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		305	302	298
Amortization		16	14	5
Deferred income taxes and investment tax credits		6	(14)	(6)
Other		(6)	(7)	4
Change in current assets and current liabilities
Accounts receivable		(25)	40	(19)
Accounts receivable from affiliates		(11)	7	(5)
Accounts payable		12	(40)	22
Accounts payable to affiliates		15	(8)	30
Unbilled Revenues		1	24	(32)
Fuel, materials and supplies		(13)	24	(28)
Taxes payable		(1)	0	7
Regulatory assets and liabilities, net		(3)	25	17
Other		0	1	5
Defined benefits plans - funding		0	1	(2)
Other operating activities
Expenditures for asset retirement obligations		(11)	(11)	(13)
Other assets		(27)	(21)	(8)
Other liabilities		(1)	1	(4)
Net cash provided by operating activities		554	609	543
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(444)	(378)	(371)
Other investing activities		0	0	(11)
Net cash provided by (used in) investing activities		(444)	(378)	(360)
Cash Flows from Financing Activities
Issuance of long-term debt		0	464	300
Retirement of long-term debt		0	(300)	0
Net increase (decrease) in short-term debt		25	(179)	110
Contributions from parent		65	67	90
Payment of common stock dividends to parent		(187)	(166)	(275)
Return of Capital to Parent		(76)	(161)	0
Other investing activities		0	(5)	0
Net cash provided by (used in) financing activities		(130)	(280)	(99)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(20)	(49)	84
Proceeds from (Repayments of) Related Party Debt		43	0	(324)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		44	93	9
Cash, Cash Equivalents and Restricted Cash at End of Period		24	44	93
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		101	93	83
Income taxes - net		73	84	57
Accrued expenditures for property, plant and equipment at December 31,		64	30	43
Accrued interest		0	5	0
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	356	312	322
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation		403	392	386
Amortization		21	20	18
Defined benefit plans - expense (income)		(5)	(5)	(4)
Deferred income taxes and investment tax credits		(15)	(10)	2
Other		(4)	(2)	3
Change in current assets and current liabilities
Accounts receivable		(21)	16	(16)
Accounts payable		(23)	(26)	26
Accounts payable to affiliates		29	(24)	37
Unbilled Revenues		(5)	17	(23)
Fuel, materials and supplies		14	(17)	(41)
Taxes payable		5	5	7
Regulatory assets and liabilities, net		23	25	(19)
Other		(5)	(4)	(3)
Defined benefits plans - funding		0	0	(1)
Other operating activities
Expenditures for asset retirement obligations		(10)	(28)	(29)
Other assets		(41)	(25)	(1)
Other liabilities		1	(4)	(4)
Net cash provided by operating activities		723	647	661
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(643)	(572)	(547)
Other investing activities		0	6	0
Net cash provided by (used in) investing activities		(643)	(566)	(547)
Cash Flows from Financing Activities
Issuance of long-term debt		0	459	300
Retirement of long-term debt		0	(313)	0
Net increase (decrease) in short-term debt		47	(8)	101
Contributions from parent		126	76	84
Payment of common stock dividends to parent		(232)	(190)	(296)
Return of Capital to Parent		(103)	(84)	0
Other investing activities		0	(4)	(1)
Net cash provided by (used in) financing activities		(89)	(64)	(106)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(9)	17	8
Proceeds from (Repayments of) Related Party Debt		73	0	(294)
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		38	21	13
Cash, Cash Equivalents and Restricted Cash at End of Period		29	38	21
Supplemental Disclosures of Cash Flow Information:
Interest - net of amount capitalized		135	125	112
Income taxes - net		102	78	78
Accrued expenditures for property, plant and equipment at December 31,		74	38	56
Accrued interest		$ 0	$ 5	$ 1
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions		Dec. 31, 2024	Dec. 31, 2023
Current Assets
Cash and cash equivalents		$ 306	$ 331
Accounts receivable (less reserve:)
Customer		961	950
Other		76	271
Unbilled revenues		485	428
Fuel, materials and supplies		511	505
Prepayments		136	103
Regulatory assets		320	293
Other current assets		85	51
Total Current Assets		2,880	2,932
Property, Plant and Equipment
Regulated utility plant		40,391	38,608
Less: accumulated depreciation - regulated utility plant		9,682	9,156
Regulated utility plant, net		30,709	29,452
Non-regulated property, plant and equipment		79	72
Less: accumulated depreciation - non-regulated property, plant and equipment		29	23
Non-regulated property, plant and equipment, net		50	49
Construction work in progress		2,390	1,917
Property, Plant and Equipment, net		33,149	31,418
Other Noncurrent Assets
Regulatory assets		2,060	1,874
Goodwill		2,247	2,247
Other intangibles		314	306
Other noncurrent assets		419	459
Total Other Noncurrent Assets		5,040	4,886
Total Assets		41,069	39,236
Current Liabilities
Short-term debt		303	992
Long-term debt due within one year		551	1
Accounts payable		1,196	1,104
Taxes		103	130
Interest		157	124
Dividends		186	173
Regulatory liabilities		223	225
Other current liabilities		614	591
Total Current Liabilities		3,333	3,340
Long-term Debt [Abstract]
Long-term Debt		15,952	14,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,356	3,105
Investment tax credits		111	114
Accrued pension obligations		317	275
Asset retirement obligations		136	133
Regulatory liabilities		3,335	3,340
Other deferred credits and noncurrent liabilities		452	385
Total Deferred Credits and Other Noncurrent Liabilities		7,707	7,352
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,346	12,326
Earnings reinvested		2,835	2,710
Accumulated other comprehensive loss		(184)	(163)
Total Equity		14,077	13,933
Total Liabilities and Equity		$ 41,069	$ 39,236
Common stock par value		$ 0.01	$ 0.01
Treasury Stock		$ (928)	$ (948)
PPL Electric Utilities Corp [Member]
Current Assets
Cash and cash equivalents		24	51
Accounts receivable (less reserve:)
Notes Receivable from Affiliate		$ 222	$ 0
Financing Receivable, after Allowance for Credit Loss, Related Party [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Other		$ 8	$ 8
Unbilled revenues		159	149
Fuel, materials and supplies		104	99
Prepayments		74	44
Regulatory assets		133	57
Other current assets		30	17
Total Current Assets		1,117	869
Property, Plant and Equipment
Regulated utility plant		16,469	15,575
Less: accumulated depreciation - regulated utility plant		4,052	3,822
Regulated utility plant, net		12,417	11,753
Construction work in progress		898	680
Property, Plant and Equipment, net		13,315	12,433
Other Noncurrent Assets
Regulatory assets		673	598
Other intangibles		274	269
Other noncurrent assets		96	125
Total Other Noncurrent Assets		1,043	992
Total Assets		15,475	14,294
Current Liabilities
Short-term debt		0	509
Long-term debt due within one year		0	0
Taxes		2	51
Interest		55	43
Regulatory liabilities		57	91
Other current liabilities		83	100
Total Current Liabilities		806	1,292
Long-term Debt [Abstract]
Long-term Debt		5,214	4,567
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,726	1,573
Regulatory liabilities		839	836
Other deferred credits and noncurrent liabilities		160	123
Total Deferred Credits and Other Noncurrent Liabilities		2,725	2,532
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,668	4,040
Earnings reinvested		1,698	1,499
Total Shareowners' Common Equity		6,730	5,903
Total Liabilities and Equity		$ 15,475	$ 14,294
Common stock no par value		$ 0	$ 0
PPL Electric Utilities Corp [Member] | Related Party
Accounts receivable (less reserve:)
Customer		$ 10	$ 10
Current Liabilities
Accounts payable		44	44
PPL Electric Utilities Corp [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		353	434
Current Liabilities
Accounts payable		565	454
Louisville Gas And Electric Co [Member]
Current Assets
Cash and cash equivalents		8	18
Accounts receivable (less reserve:)
Other		23	17
Unbilled revenues		87	88
Fuel, materials and supplies		157	143
Prepayments		9	11
Regulatory assets		8	7
Other current assets		2	0
Total Current Assets		468	429
Property, Plant and Equipment
Regulated utility plant		7,748	7,669
Less: accumulated depreciation - regulated utility plant		1,643	1,549
Regulated utility plant, net		6,105	6,120
Construction work in progress		443	312
Property, Plant and Equipment, net		6,548	6,432
Other Noncurrent Assets
Regulatory assets		491	395
Goodwill		389	389
Other intangibles		12	18
Other noncurrent assets		84	90
Total Other Noncurrent Assets		976	892
Total Assets		7,992	7,753
Current Liabilities
Short-term debt		25	0
Notes Payable with affiliates		$ 43	$ 0
Notes Payable, Related Party [Extensible Enumeration]		Related Party	Affiliated Entity [Member]
Long-term debt due within one year		$ 300	$ 0
Taxes		40	41
Interest		21	21
Asset Retirement Obligations		11	13
Customer deposits		36	34
Regulatory liabilities		14	16
Other current liabilities		50	48
Total Current Liabilities		762	337
Long-term Debt [Abstract]
Long-term Debt		2,171	2,469
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		803	776
Investment tax credits		30	31
Price risk management liabilities		3	6
Asset retirement obligations		73	72
Regulatory liabilities		815	827
Other deferred credits and noncurrent liabilities		64	63
Total Deferred Credits and Other Noncurrent Liabilities		1,788	1,775
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,982	1,993
Earnings reinvested		865	755
Total Shareowners' Common Equity		3,271	3,172
Total Liabilities and Equity		$ 7,992	$ 7,753
Common stock no par value		$ 0	$ 0
Louisville Gas And Electric Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		$ 40	$ 29
Current Liabilities
Accounts payable		64	49
Louisville Gas And Electric Co [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		134	116
Current Liabilities
Accounts payable		158	115
Kentucky Utilities Co [Member]
Current Assets
Cash and cash equivalents		13	14
Accounts receivable (less reserve:)
Customer		160	143
Other		22	12
Unbilled revenues		102	97
Fuel, materials and supplies		173	185
Prepayments		11	13
Regulatory assets		1	3
Other current assets		9	1
Total Current Assets		491	468
Property, Plant and Equipment
Regulated utility plant		10,419	9,896
Less: accumulated depreciation - regulated utility plant		2,652	2,476
Regulated utility plant, net		7,767	7,420
Construction work in progress		567	604
Property, Plant and Equipment, net		8,334	8,024
Other Noncurrent Assets
Regulatory assets		458	439
Goodwill		607	607
Other intangibles		28	19
Other noncurrent assets		155	157
Total Other Noncurrent Assets		1,248	1,222
Total Assets		10,073	9,714
Current Liabilities
Short-term debt		140	93
Notes Payable with affiliates		$ 73	$ 0
Notes Payable, Related Party [Extensible Enumeration]		Related Party	Affiliated Entity [Member]
Long-term debt due within one year		$ 250	$ 0
Taxes		37	32
Interest		24	24
Asset Retirement Obligations		10	13
Customer deposits		39	35
Regulatory liabilities		22	1
Other current liabilities		58	52
Total Current Liabilities		849	402
Long-term Debt [Abstract]
Long-term Debt		2,816	3,064
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		924	912
Investment tax credits		81	83
Asset retirement obligations		54	53
Regulatory liabilities		1,009	1,018
Other deferred credits and noncurrent liabilities		41	30
Total Deferred Credits and Other Noncurrent Liabilities		2,109	2,096
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		3,056	3,033
Earnings reinvested		935	811
Total Shareowners' Common Equity		4,299	4,152
Total Liabilities and Equity		$ 10,073	$ 9,714
Common stock no par value		$ 0	$ 0
Kentucky Utilities Co [Member] | Related Party
Current Liabilities
Accounts payable		$ 100	$ 72
Kentucky Utilities Co [Member] | Nonrelated Party
Current Liabilities
Accounts payable		$ 96	$ 80
[1] 1,560,000 shares authorized; 770,215 shares issued and 738,033 shares outstanding at December 31, 2024. 1,560,000 shares authorized; 770,013 shares issued and 737,130 shares outstanding at December 31, 2023. 75,000 shares authorized; 21,294 shares issued and outstanding at December 31, 2024 and December 31, 2023.

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 147	$ 123
Unbilled Revenues, Reserve	6	4
Other Noncurrent Assets [Abstract]
Accounts Receivable, Allowance for Credit Loss, Noncurrent	$ 1	$ 2
Equity
Common stock par value	$ 0.01	$ 0.01
Common stock shares authorized	1,560,000	1,560,000
Common stock shares issued	770,215	770,013
Common stock shares outstanding	738,033	737,130
PPL Electric Utilities Corp [Member]
Receivables Net Current [Abstract]
Accounts receivable reserve for uncollectible accounts	$ 37	$ 46
Unbilled Revenues, Reserve	3	2
Other Noncurrent Assets [Abstract]
Accounts Receivable, Allowance for Credit Loss, Noncurrent	$ 1	$ 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	$ 3	$ 6
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	$ 2	$ 2
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	Common Stock [Member]		Additional Paid-in Capital	Earnings Reinvested	Accumulated Other Comprehensive Loss	Treasury Stock	Preferred stock	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		$ 13,723	$ 8		$ 12,303	$ 2,572	$ (157)	$ (1,003)	$ 0
Dividends Declared Per Share of Common Stock		$ 0.875
Balance at beginning of period - shares at Dec. 31, 2021			735,112	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Balance at beginning of period at Dec. 31, 2021										$ 5,736		$ 364		$ 4,254	$ 1,118	$ 3,079		$ 424		$ 1,997	$ 658	$ 3,928		$ 308		$ 2,957	$ 663
Common stock shares issued	[1]		123
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	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Balance at end of period at Dec. 31, 2022										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
Common stock issued		5			5
Stock-based compensation		9			9
Dividends		(647)				(647)
Stock Issued During Period, Value, Reissued Treasury Stock		36						$ 36
Stock Issued During Period, Shares, Treasury Stock Reissued								1,252
Total Equity		$ 13,918	$ 8		12,317	2,681	(124)	$ (967)	3
Dividends Declared Per Share of Common Stock		$ 0.960
Net income (loss)		$ 740				740				519	[5]				519	266	[6]				266	312	[7]				312
Capital contributions from parent										206				206		67				67		76				76
Return of Capital to Parent										(250)				(250)		(161)				(161)		(84)				(84)
Cash dividends declared on common stock										$ (323)					(323)	$ (166)					(166)	$ (190)					(190)
Other comprehensive income (loss)		$ (39)					(39)
Balance at end of period - shares at Dec. 31, 2023		737,130	737,130	[1]						66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2023										$ 5,903		$ 364		4,040	1,499	$ 3,172		$ 424		1,993	755	$ 4,152		$ 308		3,033	811
Stock-based compensation		$ 5			5
Dividends		(711)				(711)
Stock Issued During Period, Value, Reissued Treasury Stock		23			4			$ 19
Stock Issued During Period, Shares, Treasury Stock Reissued								643
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests									(3)
Total Equity		$ 13,933	$ 8		12,326	2,710	(163)	$ (948)	0
Dividends Declared Per Share of Common Stock		$ 1.03
Common stock shares issued	[1]		202
Net income (loss)		$ 888				888				574	[5]				574	297	[6]				297	356	[7]				356
Capital contributions from parent										688				688		65				65		126				126
Return of Capital to Parent										(60)				(60)		(76)				(76)		(103)				(103)
Cash dividends declared on common stock										$ (375)					(375)	$ (187)					(187)	$ (232)					(232)
Other comprehensive income (loss)		$ (21)					(21)
Balance at end of period - shares at Dec. 31, 2024		738,033	738,033	[1]						66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Dec. 31, 2024										$ 6,730		$ 364		$ 4,668	$ 1,698	$ 3,271		$ 424		$ 1,982	$ 865	$ 4,299		$ 308		$ 3,056	$ 935
Common stock issued		$ 0
Stock-based compensation		13			13
Dividends		(763)				(763)
Stock Issued During Period, Value, Reissued Treasury Stock		27			7			$ 20
Stock Issued During Period, Shares, Treasury Stock Reissued								701
Total Equity		$ 14,077	$ 8		$ 12,346	$ 2,835	$ (184)	$ (928)	$ 0
[1] Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting. Shares in thousands. All common shares of PPL Electric stock are owned by PPL. Shares in thousands. All common shares of LG&E stock are owned by LKE. Shares in thousands. All common shares of KU stock are owned by LKE. Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONSOLIDATED STATEMENTS OF EQ_2

CONSOLIDATED STATEMENTS OF EQUITY (Parenthetical)	12 Months Ended
	Dec. 31, 2024 vote $ / shares	Dec. 31, 2023 vote $ / shares	Dec. 31, 2022 vote $ / shares
Vote per share of PPL's common stock | vote	1	1	1
Current quarterly common stock dividend (in dollars per share) | $ / shares	$ 1.03	$ 0.960	$ 0.875

Quarterly Financial Data (Unaud

Quarterly Financial Data (Unaudited) (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 8,462	$ 8,312	$ 7,902
Operating income		$ 1,740	$ 1,630	$ 1,374
Net income (loss) available to PPL common shareowners: [Abstract]
Net Income (Loss) Available to PPL Common , Per Basic shares		$ 1.20	$ 1	$ 1.03
Net Income (Loss) Available to PPL Common Shareowners, Per Diluted Shares		1.20	1	1.02
Dividends declared per share of common stock (in dollars per share)	$ 0.2575	$ 1.03	$ 0.960	$ 0.875
PPL Electric Utilities Corp [Member]
Quarterly Financial Information Disclosure [Line Items]
Operating Revenues		$ 2,876	$ 3,008	$ 3,030
Operating income		$ 918	$ 871	$ 835

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2024
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 2022. PPL has elected to separately report the cash flows of continuing and discontinued operations on the Statements of Cash Flows for 2022. 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 11 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. 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. See Notes 15 and 16 for additional information on derivatives. (PPL and PPL Electric) To meet their obligations as last resort providers of electricity supply 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. 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 price 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 applicable tariff price. 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. 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 (a) Balance at PPL 2024 $ 130 $ 109 $ 85 $ 154 (c) 2023 95 87 52 130 (c) 2022 69 78 52 95 (c) PPL Electric 2024 $ 50 $ 56 $ 65 $ 41 (b) 2023 33 52 35 50 (b) 2022 35 27 29 33 (b) LG&E 2024 $ 6 $ 4 $ 7 $ 3 2023 4 4 2 6 2022 3 6 5 4 Additions Balance at Charged to Income Deductions (a) Balance at KU 2024 $ 2 $ 4 $ 4 $ 2 2023 3 3 4 2 2022 3 6 6 3 (a) Primarily related to uncollectible accounts written off. (b) Includes $2 million, $3 million and $3 million related to other accounts receivable at December 31, 2024, 2023 and 2022. (c) Includes $39 million, $41 million and $36 million related to other accounts receivable at December 31, 2024, 2023 and 2022. Cash (All Registrants) Cash Equivalents All highly liquid investments with original maturities of three months or less are considered to be cash equivalents. (PPL, LG&E and KU) 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 15 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 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. AFUDC is capitalized at LG&E and KU for certain projects as part of the construction cost of approved projects. LG&E and KU are generally provided a return on construction work in progress for other projects. 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. The Registrants 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: 2024 2023 2022 PPL $ 20 $ 12 $ 7 PPL Electric 9 7 5 LG&E 3 1 — KU 4 1 — Depreciation 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: 2024 2023 2022 PPL 3.20 % 3.26 % 3.21 % PPL Electric 2.52 % 2.62 % 2.75 % LG&E 4.02 % 4.00 % 4.16 % KU 3.86 % 3.95 % 4.01 % Goodwill and Other Intangible Assets 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, renew or extend terms of an intangible asset are capitalized. 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) 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, 2024, PPL, for its reporting units, and individually, LG&E and KU, elected to perform the qualitative step zero evaluation of goodwill. These evaluations considered the excess of fair value over the carrying value of each reporting unit that was calculated during step one of the quantitative impairment tests performed in the fourth quarter of 2022, and the relevant events and circumstances that occurred since those tests were performed including: • current year financial performance versus the prior year, • changes in planned capital expenditures, • the consistency of forecasted free cash flows, • earnings quality and sustainability, • changes in market participant discount rates, • changes in long-term growth rates, • changes in PPL's market capitalization, and • the overall economic and regulatory environments in which these regulated entities operate. Based on these evaluations, management concluded it was not more likely than not that the fair value of these reporting units was less than their carrying value. As such, the step one quantitative impairment test was not performed and no impairment was recognized. ( 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 18 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 and its subsidiaries, excluding RIE, use 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. RIE uses the standard amortization method under GAAP for recognition of gains and losses for its defined benefit pension plan. See Note 7 for a discussion of the regulatory treatment of defined benefit costs and Note 10 for a discussion of defined benefits. Stock-Based Compensation (PPL) 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 recognizes compensation expense for stock-based compensation awards based on the fair value method. Forfeitures of awards are recognized when they occur. 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 uncertain 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 amount of 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, 2024, 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 a

Segment and Related Information

Segment and Related Information	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Segment and Related Information	(PPL) PPL is organized into three segments, broken down by geographic location: Kentucky Regulated, Pennsylvania Regulated, and Rhode Island Regulated. The Kentucky Regulated segment consists primarily of the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated transmission, distribution and sale of natural gas. 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 in May of 2022. "Corporate and Other" primarily includes corporate level financing costs, certain unallocated corporate costs, and certain non-recoverable costs incurred in conjunction with the acquisition of Rhode Island Energy and the financial results of Safari Energy, prior to its sale on November 1, 2022. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results and is not a reportable segment. PPL's CODM is the Corporate Leadership Council (CLC), which is a management committee that is comprised of the Chief Executive Officer, Chief Financial Officer, Chief Operating Officer, Chief Technology Officer, Chief Human Resources Officer and Chief Legal Officer. The CLC uses financial metrics including segment net income, earnings from ongoing operations, earnings per share and return on equity, as well as various operational metrics to assess segment performance and make investment and resource decisions. Segment net income is the measure of segment profit or loss that most closely aligns with GAAP and is being presented for disclosure purposes. The tables below provide information about PPL’s segments and include the reconciliation to consolidated net income for the year ended December 31, 2024: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Operating Revenues from external customers (a) $ 3,562 $ 2,876 $ 2,024 $ 8,462 Reconciliation of revenue Corporate and other revenues — Total consolidated revenues $ 8,462 Less: Fuel 783 — — 783 Energy Purchases 176 721 782 1,679 Operation and maintenance 803 705 731 2,239 Depreciation 710 401 165 1,276 Taxes, other than income 99 131 144 374 Other (income) expense - net (29) (78) (24) (131) Interest expense 240 246 95 581 Income taxes 160 176 22 358 Segment net income $ 620 $ 574 $ 109 $ 1,303 Reconciliation of segment profit or loss to consolidated net income Corporate and other net loss (415) Net Income $ 888 (a) See Note 1 and Note 3 for additional information on Operating Revenues. Other information for the segments and reconciliation to PPL's Consolidated results for the year ended December 31, 2024 are as follows: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Segments Corporate and Other Consolidated Total Other Segment Disclosures Amortization (a) $ 24 $ 45 $ 1 $ 70 $ 8 $ 78 Deferred income taxes and investment tax credits (b) 2 129 38 169 27 196 Expenditures for long lived assets 1,088 1,229 495 2,812 (7) 2,805 (a) 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. (b) Represents a non-cash expense item that is also included in "Income Taxes." The tables below provide information about PPL’s segments and include the reconciliation to consolidated net income for the year ended December 31, 2023: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Operating Revenues from external customers (a) $ 3,452 $ 3,008 $ 1,851 $ 8,311 Reconciliation of revenue Corporate and other revenues 1 Total consolidated revenues $ 8,312 Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Less: Fuel 733 — — 733 Energy Purchases 192 992 658 1,842 Operation and maintenance 826 605 705 2,136 Depreciation 696 397 156 1,249 Taxes, other than income 93 143 156 392 Other (income) expense - net (12) (39) (19) (70) Interest expense 235 223 83 541 Income taxes 137 168 16 321 Segment net income $ 552 $ 519 $ 96 $ 1,167 Reconciliation of segment profit or loss to consolidated net income Corporate and other net loss (427) Net Income $ 740 (a) See Note 1 and Note 3 for additional information on Operating Revenues. Other information for the segments and reconciliation to PPL's Consolidated results for the year ended December 31, 2023 are as follows: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Segments Corporate and Other Consolidated Total Other Segment Disclosures Amortization (a) $ 33 $ 41 $ 1 $ 75 $ 6 $ 81 Deferred income taxes and investment tax credits (b) (17) 46 48 77 245 322 Expenditures for long lived assets 950 956 454 2,360 30 2,390 (a) 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. (b) Represents a non-cash expense item that is also included in "Income Taxes." The tables below provide information about PPL’s segments and include the reconciliation to consolidated net income for the year ended December 31, 2022: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Operating Revenues from external customers (a) $ 3,811 $ 3,030 $ 1,038 $ 7,879 Reconciliation of revenue Corporate and other revenues 23 Total consolidated revenues $ 7,902 Less: Fuel 931 — — 931 Energy Purchases 273 1,048 365 1,686 Operation and maintenance 959 605 531 2,095 Depreciation 685 393 92 1,170 Taxes, other than income 92 149 92 333 Other (income) expense - net (12) (35) (23) (70) Interest expense 205 171 39 415 Income taxes 129 174 (14) 289 Segment net income $ 549 $ 525 $ (44) $ 1,030 Reconciliation of segment profit or loss to consolidated net income Corporate and other net loss (316) Income from discontinued operations (Note 9) 42 Net Income $ 756 (a) See Note 1 and Note 3 for additional information on Operating Revenues. Other information for the segments and reconciliation to PPL's Consolidated results for the year ended December 31, 2022 are as follows: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Segments Corporate and Other Consolidated Total Other Segment Disclosures Amortization (a) $ 23 $ 22 $ 2 $ 47 $ 5 $ 52 Deferred income taxes and investment tax credits (b) 6 91 39 136 43 179 Expenditures for long lived assets 917 889 268 2,074 84 2,158 (a) 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. (b) Represents a non-cash expense item that is also included in "Income Taxes." The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2024 2023 Total Assets Kentucky Regulated $ 17,626 $ 17,029 Pennsylvania Regulated 15,475 14,294 Rhode Island Regulated 7,055 6,515 Corporate and Other (a) 913 1,398 Total $ 41,069 $ 39,236 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill, and the elimination of inter-segment transactions. (PPL Electric) PPL Electric has two operating segments, distribution and transmission, which are aggregated into a single reportable segment. PPL Electric's CODM is the President of PPL Electric. The President uses financial metrics including segment net income, earnings from ongoing operations, earnings per share and return on equity, as well as various operational metrics to assess segment performance and make investment and resource decisions. The significant segment expenses of and measure of profit and loss for PPL Electric regularly provided to the President are included on the face of PPL Electric's Statements of Income. The measure of segment assets is reported on PPL Electric's Balance Sheets as total consolidated assets. The measures of significant non-cash segment expenses as well as expenditures for long lived assets are reported on PPL Electric's Statements of Cash Flows. (LG&E and KU) Each of LG&E and KU operates as a single operating and reportable segment, and the CODM for each of LG&E and KU is its President. The President manages LG&E and KU as a single consolidated entity. Financial metrics including net income, earnings from ongoing operations, earnings per share and return on equity, as well as various operational metrics are used to assess segment performance and make investment and resource decisions. The significant segment expenses of and measure of profit and loss for each of LG&E and KU regularly provided to its President are included on the face of the Statements of Income of LG&E and KU. The measures of segment assets are reported on the Balance Sheets of LG&E and KU as total assets. The measures of significant non-cash segment expenses as well as expenditures for long lived assets are reported on the Statements of Cash Flows of LG&E and KU.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	12 Months Ended
	Dec. 31, 2024
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	3. Revenue from Contracts with Customers (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 from other suppliers where PPL Electric facilitates the delivery. 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. Customers are typically billed monthly and outstanding amounts are normally due within 21 days of date of the bill. 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. Distribution customers are "at will" customers of RIE 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 RIE's retail account contracts. Certain customers have the option to obtain electricity or natural gas from other suppliers where RIE facilitates the delivery. 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). As of January 1, 2023, 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. RIE'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, RIE has no unsatisfied performance obligations. (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: 2024 PPL PPL Electric LG&E KU Operating Revenues (a)(b) $ 8,462 $ 2,876 $ 1,648 $ 1,964 Revenues derived from: Alternative revenue programs (c) 5 (19) 13 16 Other (d) (23) (15) (4) (4) Revenues from Contracts with Customers $ 8,444 $ 2,842 $ 1,657 $ 1,976 2023 PPL PPL Electric LG&E KU Operating Revenues (a)(b) $ 8,312 $ 3,008 $ 1,613 $ 1,884 Revenues derived from: Alternative revenue programs (c) 1 5 (1) (5) Other (d) (23) (15) (4) (4) Revenues from Contracts with Customers $ 8,290 $ 2,998 $ 1,608 $ 1,875 2022 PPL PPL Electric LG&E KU Operating Revenues (a)(b) $ 7,902 $ 3,030 $ 1,798 $ 2,074 Revenues derived from: Alternative revenue programs (c) (92) (56) 9 5 Other (d) (24) (14) (6) (4) Revenues from Contracts with Customers $ 7,786 $ 2,960 $ 1,801 $ 2,075 (a) PPL includes $2,024 million, $1,851 million and $1,038 million for the twelve months ended December 31, 2024, 2023, and 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) PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL conformed the presentation of RIE's and the Rhode Island Regulated segment’s net metering charges with the presentation of the other segments, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases beginning on January 1, 2024. For the year ended December 31, 2024, net metering of $175 million was included in Energy purchases on PPL's Statement of Income. For the years ended December 31, 2023 and 2022, $146 million and $79 million of net metering was presented as a reduction of Operating Revenues on PPL's Statement of Income. (c) 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. (d) 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 2024 PA Regulated $ 1,502 $ 418 $ 47 $ 57 $ — $ — $ 818 $ 2,842 RI Regulated (c) 1,150 593 91 10 — — 176 2,020 KY Regulated 1,510 1,028 635 323 23 63 — 3,582 Total PPL $ 4,162 $ 2,039 $ 773 $ 390 $ 23 $ 63 $ 994 $ 8,444 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers 2023 PA Regulated $ 1,649 $ 444 $ 55 $ 54 $ — $ — $ 796 $ 2,998 RI Regulated 640 228 20 793 — — 170 1,851 KY Regulated 1,458 1,001 637 272 22 50 — 3,440 Corp and Other — — — 1 — — — 1 Total PPL $ 3,747 $ 1,673 $ 712 $ 1,120 $ 22 $ 50 $ 966 $ 8,290 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 PPL Electric 2024 $ 1,502 $ 418 $ 47 $ 57 $ — $ — $ 818 $ 2,842 2023 $ 1,649 $ 444 $ 55 $ 54 $ — $ — $ 796 $ 2,998 2022 $ 1,647 $ 491 $ 85 $ 54 $ — $ — $ 683 $ 2,960 LG&E 2024 $ 754 $ 518 $ 188 $ 147 $ — $ 50 $ — $ 1,657 2023 $ 751 $ 517 $ 189 $ 104 $ — $ 47 $ — $ 1,608 2022 $ 835 $ 551 $ 199 $ 141 $ — $ 75 $ — $ 1,801 KU 2024 $ 756 $ 510 $ 447 $ 176 $ 23 $ 64 $ — $ 1,976 2023 $ 707 $ 484 $ 448 $ 168 $ 22 $ 46 $ — $ 1,875 2022 $ 802 $ 517 $ 463 $ 182 $ 28 $ 83 $ — $ 2,075 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. For the years ended December 31, 2023 and 2022, the Rhode Island Regulated segment primarily includes open access tariff revenues, which are calculated on combined customer classes. (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. (c) PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL disaggregated the 2024 revenues of the Rhode Island Regulated segment in a manner consistent with that of its other segments. This resulted in certain customer revenues for the Rhode Island Regulated segment, which were previously presented in the "Other" category, being presented in the "Residential", "Commercial" or "Industrial" customer classes beginning on January 1, 2024. Applying the previous methodology to 2024 revenues would result in $469 million of Residential, $372 million of Commercial and $88 million of Industrial for the Rhode Island Regulated segment being presented as "Other" for the year ended December 31, 2024. 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: 2024 2023 2022 PPL(a) $ 103 $ 79 $ 70 PPL Electric 52 47 21 LG&E 4 4 6 KU 4 2 6 (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, 2024 $ 39 $ 28 $ 5 $ 6 Contract liabilities as of December 31, 2023 43 29 6 7 Revenue recognized during the year ended December 31, 2024 that was included in the contract liability balance at December 31, 2023 26 12 6 7 Contract liabilities as of December 31, 2023 $ 43 $ 29 $ 6 $ 7 Contract liabilities as of December 31, 2022 34 23 5 6 Revenue recognized during the year ended December 31, 2023 that was included in the contract liability balance at December 31, 2022 21 10 5 6 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 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, 2024
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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022.
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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022.
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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022.
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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022. (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 2024, 2023 or 2022.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2024
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 the number of incremental shares that would be outstanding if potentially dilutive share-based payment awards were converted to common shares as calculated using the Two-Class Method or 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: 2024 2023 2022 Income (Numerator) Income from continuing operations after income taxes $ 888 $ 740 $ 714 Less amounts allocated to participating securities 2 1 1 Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted $ 886 $ 739 $ 713 Income from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ — $ — $ 42 Net income attributable to PPL $ 888 $ 740 756 Less amounts allocated to participating securities 2 1 1 Net income available to PPL common shareowners - Basic and Diluted $ 886 $ 739 $ 755 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,756 737,036 736,027 Add: Dilutive share-based payment awards (a) 2,097 1,130 875 Weighted-average shares - Diluted EPS 739,853 738,166 736,902 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 1.20 $ 1.00 $ 0.97 Income from discontinued operations (net of income taxes) — — 0.06 Net Income available to PPL common shareowners $ 1.20 $ 1.00 $ 1.03 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 1.20 $ 1.00 $ 0.96 Income from discontinued operations (net of income taxes) — — 0.06 Net Income available to PPL common shareowners $ 1.20 $ 1.00 $ 1.02 (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): 2024 2023 DRIP 202 — 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: 2024 2023 2022 Stock-based compensation awards — 243 93

Income and Other Taxes

Income and Other Taxes	12 Months Ended
	Dec. 31, 2024
Income Tax Disclosure [Abstract]
Income and Other Taxes	(PPL) "Income 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: 2024 2023 Deferred Tax Assets Deferred investment tax credits 28 28 Regulatory liabilities 133 123 Income taxes due to customers 418 436 Accrued pension and postretirement costs 112 101 State loss carryforwards 224 253 Federal and state tax credit carryforwards 24 67 Internal Revenue Code Section 197 intangibles 72 78 Contributions in aid of construction 163 149 Bad debt 37 28 Other 114 111 Valuation allowances (224) (245) Total deferred tax assets 1,101 1,129 Deferred Tax Liabilities Plant - net 3,898 3,749 Regulatory assets 432 376 Prepayments 39 47 Goodwill 38 22 Other 38 30 Total deferred tax liabilities 4,445 4,224 Net deferred tax liability $ 3,344 $ 3,095 State deferred taxes are determined by entity and by jurisdiction. As a result, $12 million and $9 million of net deferred tax assets are shown as "Other noncurrent assets" on the Balance Sheets for 2024 and 2023. At December 31, 2024, 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 $ 5,011 $ 224 $ (221) 2025-2044 State charitable contributions 10 1 (1) 2025-2029 Foreign capital loss 8 2 (2) Indefinite Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal - other 14 — 2044 State recycling credit 8 — 2028 State - other 2 — 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 2024 $ 245 $ 3 $ 1 $ 25 (a) $ 224 2023 213 54 (b) — 22 (c) 245 2022 462 10 — 259 (d) 213 (a) In 2024, PPL recorded a $23 million decrease in a valuation allowance on a 2004 state net operating loss carryforward that expired in 2024. (b) PPL has a Pennsylvania net operating loss fully offset by a valuation allowance. In 2023, PPL adjusted the net operating loss and related valuation allowance to be recorded at the current estimate of the applicable rate at which each portion of the net operating loss that will expire and be written off as the rate is reduced annually by one half a percentage point until the rate reaches to 4.99% in 2031. (c) In 2023, PPL recorded a $22 million decrease in a valuation allowance on a 2003 state net operating loss carryforward that expired in 2023. (d) 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. 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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal (a) $ 23 $ (175) $ (2) Current - State 9 37 24 Total Current Expense (Benefit) 32 (138) 22 Deferred - Federal (a) 137 286 122 Deferred - State 64 48 68 Total Deferred Expense (Benefit), excluding operating loss carryforwards 201 334 190 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 1 3 2 Deferred - State (3) (12) (10) Total Tax Expense (Benefit) of Operating Loss Carryforwards (2) (9) (8) Total income tax expense (benefit) $ 228 $ 184 $ 201 Total income tax expense (benefit) - Federal $ 158 $ 111 $ 119 Total income tax expense (benefit) - State 70 73 82 Total income tax expense (benefit) $ 228 $ 184 $ 201 (a) In 2023, PPL purchased approximately $300 million of renewable tax credits and recorded a current tax benefit and a deferred tax expense for utilization of approximately $250 million of the credits in 2023 and prior years, per the three-year carry-back rule. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2024 2023 2022 Discontinued operations $ — $ — $ (42) Other comprehensive income (8) (14) 11 Valuation allowance recorded to other comprehensive income — (1) — Total $ (8) $ (15) $ (31) 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 234 $ 194 $ 192 State income taxes, net of federal income tax benefit 65 58 68 Valuation allowance adjustments (a) 2 12 9 Income tax credits (b) (8) (22) (3) Utility rate-making tax adjustments (c) (21) (10) (8) Amortization of excess deferred federal and state income taxes (45) (48) (54) Other 1 — (3) Total increase (decrease) (6) (10) 9 Total income tax expense (benefit) $ 228 $ 184 $ 201 Effective income tax rate 20.4% 19.9% 22.0% (a) In 2024, 2023, and 2022, PPL recorded deferred income tax expense of $3 million, $11 million and $5 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2023, PPL purchased approximately $300 million of renewable tax credits and recorded a current tax benefit and a deferred tax expense for utilization of approximately $250 million of the credits in 2023 and prior years, per the three-year carry-back rule. (c) Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL utilities and flow through tax impacts. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. 2024 2023 2022 Taxes, other than income State gross earnings and state gross receipts $ 167 $ 195 $ 175 Property and other 207 197 157 Total $ 374 $ 392 $ 332 (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: 2024 2023 Deferred Tax Assets Accrued pension and postretirement costs $ 36 $ 30 Contributions in aid of construction 120 105 Regulatory liabilities 40 43 Income taxes due to customers 184 191 Other 22 27 Total deferred tax assets 402 396 Deferred Tax Liabilities Electric utility plant - net 1,934 1,810 Regulatory assets 160 119 Prepayments 30 36 Other 4 4 Total deferred tax liabilities 2,128 1,969 Net deferred tax liability $ 1,726 $ 1,573 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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal $ 44 $ 91 $ 63 Current - State 4 31 20 Total Current Expense (Benefit) 48 122 83 Deferred - Federal 86 28 60 Deferred - State 42 18 31 Total Deferred Expense (Benefit), excluding operating loss carryforwards 128 46 91 Total income tax expense (benefit) $ 176 $ 168 $ 174 Total income tax expense (benefit) - Federal $ 130 $ 119 $ 123 Total income tax expense (benefit) - State 46 49 51 Total income tax expense (benefit) $ 176 $ 168 $ 174 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 158 $ 144 $ 147 Increase (decrease) due to: State income taxes, net of federal income tax benefit 47 49 54 Utility rate-making tax adjustments (a) (16) (9) (7) Amortization of excess deferred federal income taxes (b) (10) (11) (12) State income tax rate change (c) — — (9) Other (3) (5) 1 Total increase (decrease) 18 24 27 Total income tax expense (benefit) $ 176 $ 168 $ 174 Effective income tax rate 23.5% 24.5% 24.9% (a) Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL utilities and flow through tax impacts. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. (b) In 2024, 2023, and 2022, 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. (c) 2022 includes a deferred tax benefit of $9 million due to the corporate net income tax rate reduction. 2024 2023 2022 Taxes, other than income State gross receipts $ 122 $ 136 $ 142 Property and other 9 7 7 Total $ 131 $ 143 $ 149 (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: 2024 2023 Deferred Tax Assets Contributions in aid of construction $ 18 $ 18 Regulatory liabilities 18 19 Accrued pension and postretirement costs 4 3 Deferred investment tax credits 7 8 Income taxes due to customers 110 115 State tax credit carryforwards 6 8 Lease liabilities 4 4 Valuation allowances (6) (8) Other 6 8 Total deferred tax assets 167 175 Deferred Tax Liabilities Plant - net 875 877 Regulatory assets 88 67 Lease right-of-use assets 4 3 Other 3 4 Total deferred tax liabilities 970 951 Net deferred tax liability $ 803 $ 776 At December 31, 2024, LG&E had $6 million of state credit carryforwards that expire in 2028 and a $6 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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal $ 60 $ 70 $ 60 Current - State 11 13 9 Total Current Expense (Benefit) 71 83 69 Deferred - Federal 1 (15) (10) Deferred - State 6 2 5 Total Deferred Expense (Benefit) 7 (13) (5) Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 77 $ 69 $ 63 Total income tax expense (benefit) - Federal $ 60 $ 54 $ 49 Total income tax expense (benefit) - State 17 15 14 Total income tax expense (benefit) $ 77 $ 69 $ 63 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 79 $ 70 $ 70 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 13 13 Amortization of excess deferred federal and state income taxes (13) (13) (18) Other (3) (1) (2) Total increase (decrease) (2) (1) (7) Total income tax expense (benefit) $ 77 $ 69 $ 63 Effective income tax rate 20.6% 20.6% 18.8% 2024 2023 2022 Taxes, other than income Property and other $ 49 $ 48 $ 48 Total $ 49 $ 48 $ 48 (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: 2024 2023 Deferred Tax Assets Contributions in aid of construction $ 12 $ 10 Regulatory liabilities 29 23 Deferred investment tax credits 20 21 Income taxes due to customers 124 131 State tax credit carryforwards 4 4 Lease liabilities 6 5 Valuation allowances (2) (2) Other 4 5 Total deferred tax assets 197 197 Deferred Tax Liabilities Plant - net 1,053 1,045 Regulatory assets 55 50 Pension and postretirement costs 6 7 Lease right-of-use assets 6 5 Other 1 2 Total deferred tax liabilities 1,121 1,109 Net deferred tax liability $ 924 $ 912 At December 31, 2024, KU had $4 million of state credit carryforwards of which $2 million will expire in 2028 and $2 million that has an indefinite carryforward period. At December 31, 2024, KU had a $2 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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal $ 87 $ 73 $ 63 Current - State 17 13 11 Total Current Expense (Benefit) 104 86 74 Deferred - Federal (15) (11) (3) Deferred - State 2 4 7 Total Deferred Expense (Benefit) (13) (7) 4 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 89 $ 77 $ 76 Total income tax expense (benefit) - Federal $ 70 $ 60 $ 58 Total income tax expense (benefit) - State 19 17 18 Total income tax expense (benefit) $ 89 $ 77 $ 76 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 93 $ 82 $ 84 Increase (decrease) due to: State income taxes, net of federal income tax benefit 16 15 16 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (17) (17) (21) Other (1) (1) (1) Total decrease (4) (5) (8) Total income tax expense (benefit) $ 89 $ 77 $ 76 Effective income tax rate 20.0% 19.8% 19.1% 2024 2023 2022 Taxes, other than income Property and other $ 49 $ 45 $ 45 Total $ 49 $ 45 $ 45 (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, 2024, 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) 2020 and prior 2020 and prior 2020 and prior 2020 and prior Pennsylvania (state) 2020 and prior 2020 and prior Kentucky (state) 2019 and prior 2019 and prior 2019 and prior 2019 and prior Other Transfer of Certain Credits under the Inflation Reduction Act (PPL) The IRS released the final Internal Revenue Code Section 6418 regulations related to the transfer of certain credits under the Inflation Reduction Act. The regulations became effective on July 1, 2024 and did not and are not expected to have a material impact on the financial statements regarding prior or future credit transfers. IRS Revenue Procedure 2023-15 (PPL and LG&E) On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized for tax purposes. PPL and LG&E are currently reviewing the revenue procedure to determine what impact the guidance may have on their financial statements.

Utility Rate Regulation

Utility Rate Regulation	12 Months Ended
	Dec. 31, 2024
Utility Rate Regulation [Line Items]
Utility Rate Regulation	7. Utility Rate Regulation Regulatory Assets and Liabilities (All Registrants) PPL, PPL Electric, LG&E and KU reflect the effects of regulatory actions in the financial statements for their rate-regulated utility operations. Regulatory assets and liabilities are classified as current if, upon initial recognition, the entire amount related to an item will be recovered or refunded within a year of the balance sheet date. (PPL) RIE is subject to the jurisdiction of the RIPUC, the Rhode Island Division of Public Utilities and Carriers, and the FERC. RIE operates under a FERC-approved open access transmission tariff. RIE's base distribution rates are calculated based on recovery of costs as well as a return on rate base. Certain other recovery mechanisms exist to recover expenses and capital investments with a return on rate base separate from the base distribution rate case process. (PPL, LG&E and KU) LG&E is subject to the jurisdiction of the KPSC and the FERC, and KU is subject to the jurisdiction of the KPSC, the VSCC and the FERC. LG&E's and KU's Kentucky base rates are calculated based on recovery of costs as well as a return on capitalization (common equity, long-term debt and short-term debt) including adjustments for certain net investments and costs recovered separately through other means. As such, LG&E and KU generally earn a return on regulatory assets. (PPL and KU) KU's Virginia base rates are calculated based on recovery of costs as well as a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except for regulatory assets and liabilities related to the levelized fuel factor, accumulated deferred income taxes, pension and postretirement benefits, and AROs related to certain CCR impoundments, are excluded from the return on rate base utilized in the calculation of Virginia base rates, no return is earned on the related assets. KU's rates to municipal customers for wholesale power requirements are calculated based on annual updates to a formula rate that utilizes a return on rate base (net utility plant plus working capital less accumulated deferred income taxes and miscellaneous deductions). As all regulatory assets and liabilities, except accumulated deferred income taxes, are excluded from the return on rate base utilized in the development of municipal rates, no return is earned on the related assets. (PPL and PPL Electric) PPL Electric is subject to the jurisdiction of the PAPUC and the FERC. PPL Electric's distribution base rates are calculated based on recovery of costs as well as a return on distribution rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions). PPL Electric's transmission revenues are billed in accordance with a FERC tariff that allows for recovery of transmission costs incurred, a return on transmission-related rate base (net utility plant plus a working capital allowance less plant-related deferred taxes and other miscellaneous additions and deductions) and an automatic annual update. See "Transmission Formula Rate" below for additional information on this tariff. All regulatory assets and liabilities are excluded from distribution and transmission return on investment calculations; therefore, generally no return is earned on PPL Electric's regulatory assets. (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations at December 31: PPL PPL Electric LG&E KU 2024 2023 2024 2023 2024 2023 2024 2023 Current Regulatory Assets: Rate adjustment mechanism $ 95 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 14 14 — — — — — — Derivative instruments 3 51 — — — — — — Smart meter rider 7 6 7 6 — — — — Storm damage expense rider 68 12 68 12 — — — — Transmission service charge 44 43 27 31 — — — — Transmission formula rate 14 5 2 — — — — — ISR deferral 22 11 — — — — — — Gas line tracker 4 — — — 4 — — — TCJA customer refund and recovery 21 — 21 — — — — — DSIC 8 7 8 7 — — — — Other 20 26 — 1 4 7 1 3 Total current regulatory assets $ 320 $ 293 $ 133 $ 57 $ 8 $ 7 $ 1 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 967 $ 887 $ 473 $ 417 $ 226 $ 217 $ 149 $ 136 Plant outage cost 30 38 — — 7 10 23 28 Net metering 147 112 — — — — — — Environmental cost recovery 96 99 — — — — — — Storm costs 113 97 22 — 20 15 29 14 Unamortized loss on debt 20 22 3 3 9 10 6 7 Interest rate swaps 4 7 — — 4 7 — — Terminated interest rate swaps 53 58 — — 31 34 22 24 Accumulated cost of removal of utility plant 173 178 173 178 — — — — AROs 280 289 — — 75 76 205 213 Retired asset recovery 83 — — — 83 — — — Derivative instruments 1 8 — — — — — — Gas line inspections 24 21 — — 22 19 2 2 Advanced metering infrastructure 28 15 — — 14 7 14 8 Other 41 43 2 — — — 8 7 Total noncurrent regulatory assets $ 2,060 $ 1,874 $ 673 $ 598 $ 491 $ 395 $ 458 $ 439 PPL PPL Electric LG&E KU 2024 2023 2024 2023 2024 2023 2024 2023 Current Regulatory Liabilities: Generation supply charge $ 52 $ 51 $ 52 $ 51 $ — $ — $ — $ — TCJA customer refund and recovery — 5 — 5 — — — — Act 129 compliance rider 2 15 2 15 — — — — Transmission formula rate 1 21 — 18 — — — — Rate adjustment mechanism 71 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — DSM 17 1 — — 7 — 10 1 Environmental cost recovery 12 — — — 6 — 6 — Other 43 22 3 2 1 1 6 — Total current regulatory liabilities $ 223 $ 225 $ 57 $ 91 $ 14 $ 16 $ 22 $ 1 PPL PPL Electric LG&E KU 2024 2023 2024 2023 2024 2023 2024 2023 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,022 $ 996 $ — $ — $ 314 $ 306 $ 408 $ 399 Power purchase agreement - OVEC 10 19 — — 7 13 3 6 Net deferred taxes 1,899 1,977 739 763 439 459 498 523 Defined benefit plans 294 252 100 73 24 20 65 59 Terminated interest rate swaps 54 57 — — 27 29 27 28 Energy efficiency 16 5 — — — — — — Other 40 34 — — 4 — 8 3 Total noncurrent regulatory liabilities $ 3,335 $ 3,340 $ 839 $ 836 $ 815 $ 827 $ 1,009 $ 1,018 ` Following is an overview of selected regulatory assets and liabilities detailed in the preceding tables. Specific developments with respect to certain of these regulatory assets and liabilities are discussed in "Regulatory Matters." Defined Benefit Plans (All Registrants) Defined benefit plan regulatory assets and liabilities represent prior service cost and net actuarial gains and losses that will be recovered in defined benefit plans expense through future base rates based upon established regulatory practices and, generally, are amortized over the average remaining service lives of plan participants. These regulatory assets and liabilities are adjusted at least annually or whenever the funded status of defined benefit plans is remeasured. (PPL, LG&E and KU) As a result of previous rate case settlements and orders, the difference between pension cost calculated in accordance with LG&E's and KU's pension accounting policy and pension cost calculated using a 15-year amortization period for actuarial gains and losses and settlements are recorded as a regulatory asset. As of December 31, 2024, the balances were $79 million for PPL, $44 million for LG&E and $35 million for KU. As of December 31, 2023, the balances were $86 million for PPL, $46 million for LG&E and $40 million for KU. (PPL) RIE is subject to a pension rate adjustment mechanism whereby the difference in amounts allowed to be recovered in rates versus actual costs of RIE’s pension and other postretirement benefit plans that are to be recovered from or passed back to customers in future periods, are also recorded as regulatory assets and liabilities. (All Registrants) Storm Costs PPL Electric, LG&E and KU have the ability to request from the PAPUC, the KPSC and the VSCC, as applicable, the authority to treat expenses related to specific extraordinary storms as a regulatory asset and defer such costs for regulatory accounting and reporting purposes. Once such authority is granted, LG&E and KU can request recovery of those expenses in a base rate case and begin amortizing the costs when recovery starts. PPL Electric can recover qualifying expenses caused by major storm events, as defined in its retail tariff, over three years through the Storm Damage Expense Rider commencing in the application year after the storm occurred. LG&E's and KU's regulatory assets for storm costs approved for base rate recovery are being amortized through various dates ending in 2031. As provided in the Amended Settlement Agreement (ASA), RIE has the authority from the RIPUC to treat certain incremental O&M expenses related to specific extraordinary storms as a regulatory asset and defer such costs for regulatory accounting and reporting purposes. Once all expenses for the extraordinary storm have been finalized, RIE files a final accounting of those storm expenses with the RIPUC that is subject to review by the RIPUC and the Rhode Island Division of Public Utilities and Carriers. Unamortized Loss on Debt Unamortized loss on reacquired debt represents losses on long-term debt refinanced, reacquired or redeemed that have been deferred and will be amortized and recovered over either the original life of the extinguished debt or the life of the replacement debt (in the case of refinancing). Such costs are being amortized through 2053 for PPL Electric, through 2042 for KU, and through 2044 for LG&E. Accumulated Cost of Removal of Utility Plant RIE, LG&E and KU charge costs of removal through depreciation expense with an offsetting credit to a regulatory liability. The regulatory liability is relieved as costs are incurred. PPL Electric does not accrue for costs of removal. When costs of removal are incurred, PPL Electric records the costs as a regulatory asset. Such deferral is included in rates and amortized over the subsequent five Net Deferred Taxes Regulatory liabilities associated with net deferred taxes represent the future revenue impact from the adjustment of deferred income taxes required primarily for excess deferred taxes and unamortized investment tax credits, largely a result of the TCJA. (PPL and PPL Electric) Distribution System Improvement Charge (DSIC) The DSIC is authorized under Act 11 and is considered an alternative ratemaking mechanism providing more timely cost recovery of qualifying distribution system capital improvements. DSIC is charged to all customers taking distribution service as a percentage of total distribution revenue (excluding State Tax Adjustment Surcharge). DSIC is capped at 5% of the total amount billed to all customers for distribution service (including reconcilable riders) which provides a safeguard for customers. PPL Electric is permitted to utilize the DSIC mechanism so long as the rolling 12-month ROE for the applicable period does not exceed the PAPUC ROE in the company’s PAPUC quarterly financial report filing. The DSIC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year. Generation Supply Charge (GSC) The GSC is a cost recovery mechanism that permits PPL Electric to recover costs incurred to provide generation supply to PLR customers who receive basic generation supply service. The recovery includes charges for generation supply, as well as administration of the acquisition process. In addition, the GSC contains a reconciliation mechanism whereby any over- or under-recovery from prior periods is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent rate filing period. Transmission Service Charge (TSC) PPL Electric is charged by PJM for transmission service-related costs applicable to its PLR customers. PPL Electric passes these costs on to customers, who receive basic generation supply service through the PAPUC-approved TSC cost recovery mechanism. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year. RIE arranges transmission service on behalf of its customers and bills the costs of those services to customers, pursuant to its Transmission Service Cost Adjustment Provision. The TSC contains a reconciliation mechanism whereby any over- or under-recovery from customers is either refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year. Transmission Formula Rate PPL Electric's transmission revenues are billed in accordance with a FERC-approved Open Access Transmission Tariff that utilizes a formula-based rate recovery mechanism. Under this formula, beginning in 2023, rates are put into effect on January 1st of each year based upon actual expenditures from the most recently filed FERC Form 1, forecasted capital additions, and other data based on PPL Electric’s books and records. 2023 was considered a transitional period as the calendar year rate approved by FERC became effective April 1, 2023. Rates are compared during the year to the estimated annual expenses and capital additions that will be filed in PPL Electric’s annual FERC Form 1, filed under the FERC's Uniform System of Accounts. Under the mechanism, any difference between the revenue requirement in effect and actual expenditures incurred for that year is recorded as a regulatory asset or regulatory liability, and the regulatory asset or regulatory liability is to be recovered from or returned to customers starting one year after the conclusion of the rate year. Storm Damage Expense Rider (SDER) The SDER is a reconcilable automatic adjustment clause under which PPL Electric annually will compare actual storm costs to storm costs allowed in base rates and refund or recover any differences from customers. In the 2015 rate case settlement approved by the PAPUC in November 2015, it was determined that reportable storm damage expenses to be recovered annually through base rates will be set at $20 million. The SDER will recover from or refund to customers the applicable expenses from reportable storms as compared to the $20 million recovered annually through base rates. Act 129 Compliance Rider In compliance with Pennsylvania's Act 129 of 2008 and implementing regulations, PPL Electric is currently in Phase IV of the energy efficiency and conservation plan which was approved in March 2021. Phase IV allows PPL Electric to recover the maximum $313 million over the five Smart Meter Rider (SMR) Act 129 requires each electric distribution company (EDC) with more than 100,000 customers to have a PAPUC approved Smart Meter Technology Procurement and Installation Plan (SMP). As of December 31, 2019, PPL Electric replaced substantially all of its old meters with meters that meet the Act 129 requirements under its SMP. In accordance with Act 129, EDCs are able to recover the costs and earn a return on capital of providing smart metering technology. PPL Electric uses the SMR to recover the costs to implement its SMP. The SMR is a reconciliation mechanism whereby any over- or under-recovery from prior years is refunded to, or recovered from, customers through the adjustment factor determined for the subsequent quarters. Universal Service Rider (USR) The USR provides for recovery of costs associated with universal service programs, OnTrack and Winter Relief Assistance Program (WRAP), provided by PPL Electric to residential customers. OnTrack is a special payment program for low-income households and WRAP provides low-income customers a means to reduce electric bills through energy saving methods. The USR rate is applied to residential customers who receive distribution service. The actual program costs are reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. TCJA Customer Refund and Recovery As a result of the reduced U.S federal corporate income tax rate as enacted by the TCJA, the PAPUC ruled that these tax benefits should be refunded to customers. Timing differences between the recognition of these tax benefits and the refund of the benefit to the customer creates a regulatory liability. PPL Electric's liability is being credited back to distribution customers through a temporary negative surcharge and remains in place until PPL Electric files and the PAPUC approves new base rates. The TCJA is reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. (PPL, LG&E and KU) Fuel Adjustment Clauses LG&E's and KU's retail electric rates contain a fuel adjustment clause, whereby variances in power purchases and the cost of fuel to generate electricity, including transportation costs, from the costs embedded in base rates are adjusted in LG&E's and KU's rates. The KPSC requires formal reviews at six-month intervals to examine past fuel adjustments and at two-year intervals to review past operations of the fuel adjustment clause and, to the extent appropriate, may conduct public hearings and reestablish the fuel charge included in base rates. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered within 12 months. KU also employs a levelized fuel factor mechanism for Virginia customers using an average fuel cost factor based primarily on projected fuel costs and load for the fuel year (12 months ending March 31). The Virginia levelized fuel factor allows fuel recovery based on projected fuel costs for the fuel year plus an adjustment for any under- or over-recovery of fuel expenses from the prior fuel year. The regulatory assets or liabilities represent the amounts that have been under- or over-recovered due to timing or adjustments to the mechanism and are typically recovered or refunded within 12 months. AROs As discussed in Note 1, 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. Power Purchase Agreement - OVEC As a result of purchase accounting associated with PPL's acquisition of LG&E and KU, the fair values of the OVEC power purchase agreement were recorded on the balance sheets of LG&E and KU with offsets to regulatory liabilities. The regulatory liabilities are being amortized using the units-of-production method until March 2026, the expiration date of the agreement at the date of the acquisition. LG&E's and KU's customer rates continue to reflect the original contracts. See Notes 12 and 17 for additional discussion of the power purchase agreement. Interest Rate Swaps LG&E's unrealized gains and losses are recorded as regulatory assets or regulatory liabilities until they are realized as interest expense. Interest expense from existing swaps is realized and recovered over the terms of the associated debt, which matures in 2033. Terminated Interest Rate Swaps Net realized gains and losses on all interest rate swaps are recovered through regulated rates. As such, any gains and losses on these derivatives are included in regulatory assets or liabilities and are primarily recognized in "Interest Expense" on the Statements of Income over the life of the associated debt. Plant Outage Costs From July 1, 2017 through June 30, 2021, plant outage costs were normalized for ratemaking purposes based on an average level of expenses. Plant outage expenses that were greater or less than the average will be collected from or returned to customers, through future base rates. Effective July 1, 2021, under-recovered plant outage costs are being amortized through 2029 for LG&E and KU. Advanced Metering Infrastructure In 2021 orders from the KPSC, LG&E and KU received approval to record regulatory assets comprised of the operating expenses associated with implementation of the AMI project and the incremental difference between AFUDC accrued at LG&E’s and KU’s weighted average cost of capital and that calculated using the methodology approved by the FERC. Recovery of these costs will be determined in the base rate case proceeding following the completion of the AMI implementation project. (PPL) Derivative Instruments Derivative instruments that qualify for recovery from, or refund to, customers through future rates are recorded at fair value, with changes in fair value recorded as regulatory assets or regulatory liabilities in the period in which the change occurs. The balance is reconcilable, and any over- or under-recovery from customers will be refunded or recovered annually in the subsequent year. Energy Efficiency The energy efficiency mechanism is designed to collect the estimated costs of RIE’s energy efficiency plan for the upcoming calendar year. Any differences between revenue billed to customers through RIE's energy efficiency charge and the costs of RIE’s energy efficiency programs, as approved by the RIPUC, are recorded as regulatory assets or regulatory liabilities. The final annual over or under collection is reconciled in the next year's energy efficiency plan filing, as part of the reconciliation factor calculation. RIE may file to change the energy efficiency plan charge at any time should significant over-or under-recoveries occur. Net Metering The net metering mechanism provides for recovery of costs associated with customer-installed on-site generation facilities, including the costs of renewable generation credits. Net metering is reconcilable annually, and any over- or under-recovery from customers will be refunded to, or recovered from, customers through the adjustment factor determined for the subsequent year. Rate Adjustment Mechanisms In addition to commodity costs, RIE is subject to a number of additional rate adjustment mechanisms whereby a regulatory asset or regulatory liability is recognized resulting from differences between actual revenues and the underlying cost being recovered or differences between actual revenues and targeted amounts as approved by the RIPUC. The rate adjustment mechanisms are reconcilable, and any over- or under-recovery from customers are to be refunded or recovered annually in the subsequent year. Renewable Energy Certificates The Renewable Energy Certificates regulatory asset represents deferred costs associated with RIE's compliance obligation with the Rhode Island Renewable Portfolio Standard (RPS). The RPS is legislation established to foster the development of new renewable energy sources. The regulatory asset will be recovered over the next year. Taxes Recoverable through Future Rates Taxes recoverable through future rates represent the portion of future income taxes that are anticipated to be recovered through future rates based upon established regulatory practices. Accordingly, this regulatory asset is recognized when the offsetting deferred tax liability is recognized. For general-purpose financial reporting, this regulatory asset and the deferred tax liability are not offset; rather, each is displayed separately. This regulatory asset is expected to be recovered over the period that the underlying book-tax timing differences reverse and the actual cash taxes are incurred. (PPL, LG&E and KU) Environmental Cost Recovery Kentucky law permits LG&E and KU to recover the costs, including a return of operating expenses and a return of and on capital invested, of complying with the Clean Air Act and those federal, state or local environmental requirements, which apply to coal combustion wastes and by-products from coal-fired electricity generating facilities. The KPSC requires reviews of the past operations of the environmental surcharge for six-month and two-year billing periods to evaluate the related charges, credits and rates of return, as well as to provide for the roll-in of ECR amounts to base rates each two-year period. The KPSC has authorized return on equity of 9.35% for existing approved ECR projects. The ECR regulatory asset or liability represents the amount that has been under- or over-recovered due to timing or adjustments to the mechanism and is typically recovered or refunded within 12 months. RIE's rate plans provide for specific rate allowances for RIE's share of the estimated costs to investigate and perform certain remediation activities at sites with which it may be associated, with variances deferred for future recovery from, or return to, customers. RIE believes future costs, beyond the expiration of current rate plans, will continue to be recovered through rates. The regulatory asset represents the excess of amounts incurred for RIE's actual site investigation and remediation costs versus amounts received in rates. (PPL and LG&E) Gas Supply Clause LG&E's natural gas rates contain a gas supply clause, whereby the expected cost of natural gas supply and variances between actual and expected costs and customer usage from prior periods are adjusted quarterly in LG&E's rates, subject to approval by the KPSC. The gas supply clause previously included a separate natural gas procurement incentive mechanism, which allowed LG&E's rates to be adjusted annually to share savings between the actual cost of gas purchases and market indices, with the shareholders and the customers during each performance-based rate year (12 months ending October 31). The operation of this incentive mechanism expired on October 31, 2024, but savings achieved through October 31, 2024 will be included in LG&E’s rates through October 31, 2026. The regulatory assets or liabilities represent the total amounts that have been under- or over-recovered due to timing or adjustments to the mechanisms and are typically recovered or refunded within 18 months. Retired Asset Recovery (RAR) Rider The RAR rider was established by KPSC orders in 2021 to provide recovery of and return on the remaining investment in certain electric generating units, including the remaining net book value of each unit, materials and supplies that cannot be used at other plants and any associated removal costs, upon their retirement over a ten-year period following retirement. Costs included as of December 31, 2024 represent the remaining net book value and materials and supplies that cannot be used as a result of the retirement of Mill Creek Unit 1. The associated removal costs will be added to the RAR rider regulatory asset or regulatory liability as costs are incurred. Regulatory Matters Rhode Island Activities (PPL) Advanced Metering Functionality (AMF) In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the Amended Settlement Agreement (ASA) approved by the RIPUC in August 2018, and which among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory. On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC for approval of (i) an updated electric Service Quality Plan on December 27, 2023, (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023, and (iii) electric and gas tariff advice filings for RIPUC Automatic Meter Reading/AMF meter opt-out tariff provision on September 19, 2024. The RIPUC approved RIE’s revised service quality metrics with certain modifications on August 1, 2024 and October 30, 2024. In addition, the RIPUC approved RIE’s AMR/AMF opt-out tariff provisions for electric and natural gas with modifications on December 19, 2024 for effect January 1, 2025, and approved the proposed updated fees to be assessed at the start of the AMF roll-out. On January 7, 2025, RIE filed compliance tariffs to reflect the RIPUC’s ruling, which they approved at their January 23, 2025 Open Meeting. Grid Modernization Plan (GMP) RIE filed a new GMP with the RIPUC on December 30, 2022. The new GMP filing consists of a holistic suite of grid modernization investments that will provide RIE with the tools and capability to manage the electric distribution system more granularly considering a range of distributed energy resources adoption levels, accelerated by Rhode Island's climate mandates, while at the same time maintaining a safe and reliable electric distribution system. The GMP is an informational guidance document that supports the grid modernization investments to be proposed in future electric ISR plans. Consequently, RIE did not request approval from the RIPUC for any specific investments or seek cost recovery as part of the GMP; rather, RIE requested the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. At an Open Meeting on November 21, 2024, the RIPUC unanimously ruled that RIE satisfied the requirement to file a GMP. This decision does not represent a ruling on the GMP and the docket will remain open, though RIE does not expect further action on this docket. FY 2025 Gas ISR Plan On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend plus up to an additional $11 million of contingency plan spending in connection with the PHMSA's potential enactment of regulations during FY 2025 that, if enacted would significantly alter RIE's leak detection and repair obligations under federal regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved, the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), plus the potential additional $11 million available if the above-mentioned regulations are implemented by the PHMSA. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. FY 2026 Gas ISR Plan On December 31, 2024, RIE filed its FY 2026 Gas ISR Plan with the RIPUC with a budget that includes $187 million of capital investment spend and up to $15 million of additional contingency plan spend in connection with the PHMSA's potential enactment of regulations during FY 2026 that, if enacted, would significantly alter RIE's leak detection and repair obligations under federal regulations. The Plan also includes proposed spending on curb-to-curb paving of $22 million. A decision from the RIPUC on the Plan is expected by March 31, 2025. RIE cannot predict the outcome of this matter. FY 2025 Electric ISR Plan On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation management O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC app

Financing Activities

Financing Activities	12 Months Ended
	Dec. 31, 2024
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. The following credit facilities were in place at: December 31, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL PPL Capital Funding Syndicated Credit Facility (a) (b) (c) Dec 2028 $ 1,250 $ — $ 138 $ 1,112 $ — $ 390 Bilateral Credit Facility (a) (b) Feb 2025 100 — — 100 — — Bilateral Credit Facility (a) (b) Feb 2025 100 — 15 85 — 13 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 153 $ 1,297 $ — $ 403 PPL Electric Syndicated Credit Facility (a) (b) Dec 2028 650 — 1 649 — 511 Total PPL Electric Credit Facilities $ 650 $ — $ 1 $ 649 $ — $ 511 December 31, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of LG&E Syndicated Credit Facility (a) (b) Dec 2028 500 — 25 475 — — Total LG&E Credit Facilities $ 500 $ — $ 25 $ 475 $ — $ — KU Syndicated Credit Facility (a) (b) Dec 2028 400 — 140 260 — 93 Total KU Credit Facilities $ 400 $ — $ 140 $ 260 $ — $ 93 (a) Each company pays customary fees under its respective facility and borrowings generally bear interest at applicable secured overnight financing rates or base 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, RIE, 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 February 2025 be increased by up to $30 million and that the capacity of its syndicated credit facility be increased by up to $400 million. PPL Electric, LG&E and KU may each request up to a $250 million increase in its syndicated credit facility's capacity, subject to regulatory approval of the increased capacity. Participation in any such increase is at the sole discretion of each lender. (c) Includes a $250 million borrowing sublimit for RIE and a $1 billion sublimit for PPL Capital Funding at December 31, 2024 and 2023. At December 31, 2024, PPL Capital Funding had $138 million of commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million of commercial paper outstanding and RIE had $25 million of commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL. (d) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL) In January 2025, PPL Capital Funding amended and restated its existing $1.25 billion syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $1.5 billion. (PPL and PPL Electric) In January 2025, PPL Electric amended and restated its existing $650 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $750 million. (PPL and LG&E) In January 2025, LG&E amended and restated its existing $500 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $600 million. (PPL and KU) In January 2025, KU amended and restated its existing $400 million syndicated credit facility to extend the termination date from December 6, 2028 to December 6, 2029 and to increase the borrowing capacity under the facility to $600 million. (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, 2024 December 31, 2023 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) 4.76% $ 1,350 $ 138 $ 1,212 5.66% $ 365 RIE (b) 250 — 250 5.72% 25 PPL Electric 650 — 650 5.67% 510 LG&E 4.72% 500 25 475 — KU 4.71% 400 140 260 5.64% 93 Total $ 3,150 $ 303 $ 2,847 $ 993 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility, which, at December 31, 2024, had a total capacity of $1.25 billion and under which they are both borrowers. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. The PPL Capital Funding syndicated credit facility includes a borrowing sublimit for RIE, which at December 31, 2024 was set at $250 million with the remaining $1 billion allocated to PPL Capital Funding. RIE's obligations under the facility are not guaranteed by PPL. The sublimits of each borrower may be decreased or increased at the borrowers’ option up to a prescribed amount such that all borrowings under the syndicated credit facility cannot exceed the size of the credit facility of $1.25 billion. (c) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL Electric, LG&E and KU) See Note 13 for a discussion of intercompany borrowings. Long-term Debt (All Registrants) December 31, Weighted-Average Maturities (d) 2024 2023 PPL Senior Unsecured Notes 4.34 % 2026 - 2047 $ 4,316 $ 3,066 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 4.38 % 2025 - 2053 10,878 10,229 Exchangeable Senior Unsecured Notes 2.88 % 2028 1,000 1,000 Junior Subordinated Notes 7.25 % 2067 480 480 Total Long-term Debt before adjustments 16,674 14,775 Unamortized premium and (discount), net (57) (55) Unamortized debt issuance costs (114) (108) Total Long-term Debt 16,503 14,612 Less current portion of Long-term Debt 551 1 Total Long-term Debt, noncurrent $ 15,952 $ 14,611 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.64 % 2027 - 2053 $ 5,299 $ 4,649 Total Long-term Debt Before Adjustments 5,299 4,649 Unamortized discount (42) (42) Unamortized debt issuance costs (43) (40) Total Long-term Debt 5,214 4,567 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 5,214 $ 4,567 December 31, Weighted-Average Maturities (d) 2024 2023 LG&E Senior Secured Notes/First Mortgage Bonds (a) (c) 4.01 % 2025 - 2049 $ 2,489 $ 2,489 Total Long-term Debt Before Adjustments 2,489 2,489 Unamortized discount (4) (4) Unamortized debt issuance costs (14) (16) Total Long-term Debt 2,471 2,469 Less current portion of Long-term Debt 300 — Total Long-term Debt, noncurrent $ 2,171 $ 2,469 KU Senior Secured Notes/First Mortgage Bonds (a) (c) 4.22 % 2025 - 2050 $ 3,089 $ 3,089 Total Long-term Debt Before Adjustments 3,089 3,089 Unamortized premium 4 5 Unamortized discount (8) (9) Unamortized debt issuance costs (19) (21) Total Long-term Debt 3,066 3,064 Less current portion of Long-term Debt 250 — Total Long-term Debt, noncurrent $ 2,816 $ 3,064 (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 $13.3 billion and $12.4 billion at December 31, 2024 and 2023. 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 $6.0 billion and $5.9 billion at December 31, 2024 and 2023. 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 $7.5 billion and $7.3 billion at December 31, 2024 and 2023. (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 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. (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 SOFR index rate. At December 31, 2024, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $894 million for PPL, comprised of $538 million and $356 million for LG&E and KU. At December 31, 2024, 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, 2024. The aggregate maturities of long-term debt, based on sinking fund requirements, stated maturities or earlier put dates, for the periods 2025 through 2029 and thereafter are as follows: PPL PPL LG&E KU 2025 $ 551 $ — $ 300 $ 250 2026 904 — 90 164 2027 428 108 260 60 2028 1,350 — — — 2029 116 116 — — Thereafter 13,325 5,075 1,839 2,615 Total $ 16,674 $ 5,299 $ 2,489 $ 3,089 (PPL) In March 2024, RIE issued $500 million of 5.35% Senior Notes due 2034. RIE received proceeds of $496 million, net of discounts and underwriting fees, to be used to repay short-term debt and for other general corporate purposes. In August 2024, PPL Capital Funding issued $750 million of 5.25% Senior Notes due 2034. PPL Capital Funding received proceeds of $741 million, net of discounts and underwriting fees, to be used to repay short-term debt and for other general corporate purposes. (PPL and PPL Electric) In January 2024, PPL Electric issued $650 million of 4.85% First Mortgage Bonds due 2034. PPL Electric received proceeds of $644 million, net of discounts and underwriting fees, to be used to repay short-term debt and for other general corporate purposes. (PPL Electric, LG&E and KU) See Note 13 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, other than PPL's guarantee of PPL Capital Funding's obligations, 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) Distributions and Related Restrictions In November 2024, PPL declared its quarterly common stock dividend, payable January 2, 2025, at 25.75 cents per share (equivalent to $1.03 per annum). On February 13, 2025, PPL announced a quarterly common stock dividend of 27.25 cents per share, payable April 1, 2025, to shareowners of record as of March 10, 2025. 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, 2024, no interest payments were deferred. (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, PPL Electric and RIE 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, PPL Electric and RIE 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, 2024, net assets of $1.5 billion for LG&E and $2.0 billion for KU were restricted for purposes of paying dividends to LKE, and net assets of $1.8 billion for LG&E and $2.3 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, 2024
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 entered into a transition services agreement (TSA), pursuant to which the National Grid entities 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 share purchase agreement. The TSA was for an initial two-year term and was completed in the third quarter of 2024. TSA costs of $137 million, $228 million, and $123 million were incurred for the years ended December 31, 2024, 2023, and 2022. 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 did 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 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 $307 million, $262 million, and $181 million for the years ended December 31, 2024, 2023, and 2022. • RIE will not seek to recover any transaction costs related to the Acquisition, which were $28 million through December 31, 2024, including an immaterial amount for the years ended December 31, 2024 and 2023, and $18 million for the year ended December 31, 2022. These amounts were 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 which were $10 million, $7 million, and $3 million for the years ended December 31, 2024, 2023, and 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. Therefore, the fair values of these assets and liabilities equal their carrying values. Accordingly, neither the assets acquired nor liabilities assumed reflect any adjustments related to these amounts. Total goodwill resulting from the acquisition was $1,585 million. 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 $860 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 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 was subject to change during the one-year measurement period as additional information was obtained about the facts and circumstances that existed at closing. Adjustments to certain assets acquired and liabilities assumed during the year ended December 31, 2023 resulted in a decrease in goodwill of $1 million since the purchase price allocation as of December 31, 2022. Final Purchase Price Allocation 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 Noncurrent Assets Property, Plant and Equipment, net 3,992 Regulatory Assets 393 Goodwill 1,585 Other Noncurrent Assets 164 Total Noncurrent Assets 6,134 Total Assets $ 6,776 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 142 Noncurrent Liabilities 2,281 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 Operating Revenues and Net Income (Loss) attributable to PPL, including RIE, as if the Acquisition had occurred prior to January 1, 2022 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 (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%. Developments (PPL, LG&E and KU) Mill Creek Unit 5 Construction In December 2022, LG&E and KU filed a CPCN with the KPSC requesting approval to construct a 640 MW net summer rating Natural Gas Combined Cycle (NGCC) combustion turbine at LG&E’s Mill Creek Generating Station. In November 2023, the KPSC issued an order approving the request as well as the requested AFUDC accounting treatment for associated financing costs relating to the NGCC. The new NGCC facility will be jointly owned by LG&E (31%) and KU (69%). In February 2024, LG&E and KU entered into agreements to begin construction of Mill Creek Unit 5. Total project costs are estimated at approximately $1.0 billion, including AFUDC. Commercial operation of the facility is anticipated to begin in mid-2027. See Note 7 for additional information on the CPCN filing. Divestitures (PPL) 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). Final closing adjustments were completed during the year ended December 31, 2023, resulting in an increase to the loss on sale of $6 million ($5 million net of tax), which was recorded in "Other operation and maintenance" on the Statements of Income for the year ended December 31, 2023. A loss on sale of $60 million ($46 million net of tax benefit) was recorded in "Other operation and maintenance" on the Statements of Income for the year ended December 31, 2022. In connection with the closing of the Transaction, PPL provided certain guarantees and other assurances. Certain of these guarantees and other assurances have been terminated as of January 8, 2024. See Note 12 to the Financial Statements for additional information. Discontinued Operations Summarized Results of Discontinued Operations On June 14, 2021, PPL WPD Limited completed the sale of PPL's U.K. utility business to National Grid Holdings One plc (National Grid U.K.), a subsidiary of National Grid plc. For the year ended December 31, 2022, the operations of the U.K. utility business are included in "Income from Discontinued Operations (net of income taxes)" on the Statements of Income, with the only component being an income tax benefit of $42 million. There were no discontinued operations activities for the years ended December 31, 2024 or 2023.

Leases

Leases	12 Months Ended
	Dec. 31, 2024
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 2025 to 2042, 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 2025 through 2051. RIE has various operating leases, primarily related to buildings, land, and finance leases related to fleet vehicles used to support the electric and gas operations, with lease terms ranging between 1 and 28 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, 2024. 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' leases for the years ended December 31: 2024 2023 2022 PPL Lease cost: Finance lease cost: Amortization of right-of-use assets $ — 1 $ — Interest on lease liabilities — — — Operating lease cost — 26 20 Short-term lease cost — 6 6 Total lease cost $ — $ 33 $ 26 LG&E Lease cost: Operating lease cost $ 5 $ 6 Short-term lease cost 1 1 Total lease cost $ — $ 6 $ 7 KU Lease cost: Operating lease cost $ 10 $ 9 Short-term lease cost 1 2 Total lease cost $ — $ 11 $ 11 The following table provides other key information related to the Registrants' leases at December 31: 2024 2023 2022 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from finance leases $ — — $ — Operating cash flows from operating leases — 25 26 Financing cash flows from finance leases — 1 — Right-of-use asset obtained in exchange for new finance lease liabilities — 7 — Right-of-use asset obtained in exchange for new operating lease liabilities — 47 15 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 8 Right-of-use asset obtained in exchange for new operating lease liabilities 6 4 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9 $ 12 Right-of-use asset obtained in exchange for new operating lease liabilities 10 5 The following table provides the total future minimum rental payments for leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2024. PPL LG&E KU Operating leases Finance leases Operating leases Operating leases 2024 $ — $ — 2025 — — 2026 — — 2027 — — 2028 — — Thereafter — — Total $ — $ — $ — $ — Weighted-average discount rate Weighted-average remaining lease term (in years) Current lease liabilities (a) $ — $ — Non-current lease liabilities (a) — — Right-of-use assets (b) — — (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Operating lease right-of-use assets are included in "Other noncurrent assets" and finance lease right-of-use assets are included in "Property, Plant and Equipment" on the Balance Sheets. 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, 2024. The following table shows the lease income recognized for the years ended December 31: 2024 2023 2022 PPL $ — 4 6 LG&E — — 2 KU — — —

Retirement and Postemployment B

Retirement and Postemployment Benefits	12 Months Ended
	Dec. 31, 2024
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 RIE 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. Effective January 1, 2024, newly hired salaried employees and certain bargaining unit employees of LKE will no longer be eligible for postretirement medical benefits under the LKE Postretirement Plan. 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 2024 2023 2022 2024 2023 2022 Net periodic defined benefit costs (credits): Service cost $ 35 $ 34 $ 51 $ 6 $ 6 $ 7 Interest cost 183 188 144 29 30 20 Expected return on plan assets (299) (309) (276) (30) (30) (28) Amortization of: Prior service cost (credit) 3 6 8 1 1 1 Actuarial (gain) loss 10 2 51 (5) (5) (5) Net periodic defined benefit costs (credits) prior to settlements and termination benefits (68) (79) (22) 1 2 (5) Settlements (a) — — 23 — — — Net periodic defined benefit costs (credits) $ (68) $ (79) $ 1 $ 1 $ 2 $ (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) — — — Net (gain) loss 134 193 242 1 (6) — Prior service cost (credit) (13) 2 — — — — Amortization of: Prior service (cost) credit (3) (6) (8) (1) (1) (1) Actuarial gain (loss) (10) (2) (51) 5 5 5 Total recognized in OCI and regulatory assets/liabilities 108 187 193 5 (2) (45) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 40 $ 108 $ 194 $ 6 $ — $ (50) (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 2024 2023 2022 2024 2023 2022 OCI $ 25 $ 52 $ 142 $ 2 $ — $ 13 Regulatory assets/liabilities 83 135 51 3 (2) (58) Total recognized in OCI and $ 108 $ 187 $ 193 $ 5 $ (2) $ (45) (PPL) PPL uses 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 2024 2023 2024 2023 PPL Discount rate 5.93 % 5.52 % 5.91 % 5.54 % Rate of compensation increase 3.43 % 3.43 % 3.44 % 3.43 % 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 2024 2023 2022 2024 2023 2022 PPL Discount rate 5.52 % 5.52 % 3.35 % 5.54 % 5.54 % 3.54 % Rate of compensation increase 3.43 % 3.43 % 3.74 % 3.43 % 3.43 % 2.84 % Expected return on plan assets 8.25 % 8.25 % 7.25 % 7.28 % 7.38 % 6.52 % (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: 2024 2023 2022 PPL Health care cost trend rate assumed for next year – obligations 7.00 % 6.25 % 6.50 % – cost 6.25 % 6.50 % 6.25 % 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 2033 2029 2029 – cost 2029 2029 2027 The funded status of PPL's plans at December 31 was as follows: Pension Benefits Other Postretirement Benefits 2024 2023 2024 2023 Change in Benefit Obligation Benefit Obligation, beginning of period $ 3,454 $ 3,333 $ 538 $ 534 Service cost 35 34 6 6 Interest cost 183 188 29 30 Participant contributions — — 8 9 Plan amendments (13) 3 — — Actuarial (gain) loss (131) 179 (4) 18 Settlements — (3) — — Gross benefits paid (284) (280) (56) (59) Federal subsidy — — 2 — Benefit Obligation, end of period 3,244 3,454 523 538 Change in Plan Assets Plan assets at fair value, beginning of period 3,176 3,149 438 417 Actual return on plan assets 34 297 25 54 Employer contributions 10 13 14 16 Participant contributions — — 7 7 Transfer out (a) — — (13) — Settlements — (3) — — Gross benefits paid (284) (280) (54) (56) Plan assets at fair value, end of period 2,936 3,176 417 438 Funded Status, end of period $ (308) $ (278) $ (106) $ (100) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 19 $ 7 $ 8 $ 10 Current liability (10) (10) (13) (14) Noncurrent liability (317) (275) (101) (96) Net amount recognized, end of period $ (308) $ (278) $ (106) $ (100) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ (6) $ 11 $ 9 $ 10 Net actuarial (gain) loss 1,164 1,017 (90) (96) Total $ 1,158 $ 1,028 $ (81) $ (86) Total accumulated benefit obligation for defined benefit pension plans $ 3,116 $ 3,312 (a) Transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to be used to pay medical claims of active bargaining unit employees. 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 2024 2023 2024 2023 AOCI $ 283 $ 235 $ 16 $ 14 Regulatory assets/liabilities 875 793 (97) (100) Total $ 1,158 $ 1,028 $ (81) $ (86) The actuarial gain for pension plans in 2024 was primarily related to a change in the discount rate used to measure the benefit obligations of those plans. The actuarial loss for pension plans in 2023 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 2024 2023 Projected benefit obligation $ 2,719 $ 2,891 Fair value of plan assets 2,392 2,606 ABO in excess of plan assets 2024 2023 Accumulated benefit obligation $ 2,618 $ 1,773 Fair value of plan assets 2,392 1,594 (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: 2024 2023 Pension $ (83) $ (65) Other postretirement benefits (60) (55) (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 13 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: 2024 2023 Pension $ 29 $ 34 Other postretirement benefits (44) (44) (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 13 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. 2024 2023 Pension $ 46 $ 51 Other postretirement benefits (8) (9) Plan Assets - Pension Plans (PPL) All of PPL's qualified pension plans 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, RIE 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 2024 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 2024 2024 2023 Target Asset Growth Portfolio 55 % 54 % 55 % Equity securities 30 % 31 % Debt securities (a) 13 % 12 % Alternative investments 12 % 11 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 35 % 36 % Derivatives (b) 8 % 7 % Liquidity Portfolio 2 % 3 % 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, 2024 December 31, 2023 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 $ 212 $ 212 $ — $ — $ 226 $ 226 $ — $ — Equity securities: U.S. Equity 63 63 — — 36 36 — — U.S. Equity fund measured at NAV (a) 461 — — — 542 — — — International equity fund at NAV (a) 376 — — — 431 — — — Commingled debt measured at NAV (a) 461 — — — 528 — — — Debt securities: U.S. Treasury and U.S. government sponsored 150 149 1 — 159 159 — — Corporate 867 — 848 19 915 — 906 9 Other 13 — 13 — 14 — 13 1 Alternative investments: Real estate measured at NAV (a) 72 — — — 61 — — — Private equity measured at NAV (a) 114 — — — 105 — — — Private credit partnerships measured at NAV (a) 16 — — — 13 — — — Hedge funds measured at NAV (a) 181 — — — 192 — — — Derivatives (38) — (38) — 93 — 93 — PPL Services Corporation Master Trust assets, at 2,948 $ 424 $ 824 $ 19 3,315 $ 421 $ 1,012 $ 10 Receivables and payables, net (b) 102 (16) 401(h) accounts restricted for other (114) (124) Total PPL Services Corporation Master Trust $ 2,936 $ 3,175 (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, 2024 is as follows: Corporate Balance at beginning of period $ 10 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 7 Purchases, sales and settlements 4 Balance at end of period $ 19 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2023 is as follows: Corporate Balance at beginning of period $ 16 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 4 Purchases, sales and settlements (8) Balance at end of period $ 10 Cash and cash equivalents include deposits in banks, collateral accounts with brokers, and short-term investment funds, for which the carrying amounts disclosed approximate fair value based on their short-term nature. 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 U.S. real estate properties diversified geographically and across major property types (e.g., office, industrial, retail, etc.). 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, 2024, the Master Trust had unfunded commitments of $59 million that may be required during the lives of the real estate, private equity and private credit 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 a large-cap commingled fund and a global equity exchange-traded fund. 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 2024 2023 2024 Asset Class Equity securities 45 % 46 % 45 % Debt securities (a) 49 % 48 % 49 % Cash and cash equivalents (b) 6 % 6 % 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, 2024 December 31, 2023 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 $ — $ — $ 20 $ 20 $ — $ — Equity securities: Large-cap equity fund measure at NAV (a) 71 — — — 76 — — — Commingled debt fund measured at NAV (a) 78 — — — 84 — — — Global equity exchange-traded fund 70 70 — — 72 72 — — Long-term bond exchange-traded fund 74 74 — — 74 74 — — Total VEBA trust assets, at fair value 312 $ 163 $ — $ — 326 $ 166 $ — $ — Receivables and payables, net (b) (9) (12) 401(h) account assets 114 124 Total other postretirement benefit plan assets $ 417 $ 438 (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. Expected Cash Flows - Defined Benefit Plans (PPL) PPL does not plan to contribute to its pension plans in 2025, 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 2025. PPL is not required to make contributions to its other postretirement benefit plans that are funded through VEBA trusts and 401(h) accounts. However, postretirement benefits for certain non-union employees are not funded in such trusts. PPL pays for these benefits from its general assets and expects to make $13 million of postretirement benefit plan payments for these employees in 2025. 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 2025 $ 304 $ 50 $ — 2026 297 49 — 2027 288 49 — 2028 282 48 — 2029 276 47 — 2030-2034 1,298 218 — 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: 2024 2023 2022 PPL $ 53 $ 48 $ 36 PPL Electric 9 8 6 LG&E 8 8 7 KU 6 6 5

Jointly Owned Facilities

Jointly Owned Facilities	12 Months Ended
	Dec. 31, 2024
Jointly Owned Facilities [Line Items]
Jointly Owned Facilities	(PPL, LG&E and KU) At December 31, 2024 and 2023, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2024 Trimble County Unit 1 75.00 % $ 462 $ 124 $ 1 Trimble County Unit 2 75.00 % 1,549 323 10 December 31, 2023 Trimble County Unit 1 75.00 % $ 464 $ 110 $ — Trimble County Unit 2 75.00 % 1,490 300 49 LG&E December 31, 2024 E.W. Brown Units 6-7 38.00 % $ 53 $ 29 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 30 — Trimble County Unit 1 75.00 % 462 124 1 Trimble County Unit 2 14.25 % 472 79 5 Trimble County Units 5-6 29.00 % 37 19 — Trimble County Units 7-10 37.00 % 82 41 1 Cane Run Unit 7 22.00 % 137 27 — E.W. Brown Solar Unit 39.00 % 10 4 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 10 — 1 Mill Creek 5 31.00 % — — 74 Brown Wind 36.00 % — — — December 31, 2023 E.W. Brown Units 6-7 38.00 % $ 53 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 29 — Trimble County Unit 1 75.00 % 464 110 — Trimble County Unit 2 14.25 % 447 74 25 Trimble County Units 5-6 29.00 % 37 17 — Trimble County Units 7-10 37.00 % 82 39 — Cane Run Unit 7 22.00 % 127 25 3 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 7 — — Mill Creek 5 31.00 % — — 2 Brown Wind 36.00 % — — — Ownership Electric Plant Accumulated Construction KU December 31, 2024 E.W. Brown Units 6-7 62.00 % $ 87 $ 48 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 26 — Trimble County Unit 2 60.75 % 1,077 224 5 Trimble County Units 5-6 71.00 % 87 44 — Trimble County Units 7-10 63.00 % 136 69 1 Cane Run Unit 7 78.00 % 485 95 1 E.W. Brown Solar Unit 61.00 % 16 6 — Solar Share 56.00 % 4 1 — Mercer Solar 63.00 % 16 — 2 Mill Creek 5 69.00 % — — 164 Brown Wind 64.00 % 1 — — December 31, 2023 E.W. Brown Units 6-7 62.00 % $ 87 $ 45 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 25 — Trimble County Unit 2 60.75 % 1,043 227 24 Trimble County Units 5-6 71.00 % 86 41 — Trimble County Units 7-10 63.00 % 135 65 — Cane Run Unit 7 78.00 % 449 90 10 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — Mercer Solar 63.00 % 12 — 1 Mill Creek 5 69.00 % — — 3 Brown Wind 64.00 % 1 — — 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, 2024 and 2023, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2024 Trimble County Unit 1 75.00 % $ 462 $ 124 $ 1 Trimble County Unit 2 75.00 % 1,549 323 10 December 31, 2023 Trimble County Unit 1 75.00 % $ 464 $ 110 $ — Trimble County Unit 2 75.00 % 1,490 300 49 LG&E December 31, 2024 E.W. Brown Units 6-7 38.00 % $ 53 $ 29 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 30 — Trimble County Unit 1 75.00 % 462 124 1 Trimble County Unit 2 14.25 % 472 79 5 Trimble County Units 5-6 29.00 % 37 19 — Trimble County Units 7-10 37.00 % 82 41 1 Cane Run Unit 7 22.00 % 137 27 — E.W. Brown Solar Unit 39.00 % 10 4 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 10 — 1 Mill Creek 5 31.00 % — — 74 Brown Wind 36.00 % — — — December 31, 2023 E.W. Brown Units 6-7 38.00 % $ 53 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 29 — Trimble County Unit 1 75.00 % 464 110 — Trimble County Unit 2 14.25 % 447 74 25 Trimble County Units 5-6 29.00 % 37 17 — Trimble County Units 7-10 37.00 % 82 39 — Cane Run Unit 7 22.00 % 127 25 3 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 7 — — Mill Creek 5 31.00 % — — 2 Brown Wind 36.00 % — — — Ownership Electric Plant Accumulated Construction KU December 31, 2024 E.W. Brown Units 6-7 62.00 % $ 87 $ 48 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 26 — Trimble County Unit 2 60.75 % 1,077 224 5 Trimble County Units 5-6 71.00 % 87 44 — Trimble County Units 7-10 63.00 % 136 69 1 Cane Run Unit 7 78.00 % 485 95 1 E.W. Brown Solar Unit 61.00 % 16 6 — Solar Share 56.00 % 4 1 — Mercer Solar 63.00 % 16 — 2 Mill Creek 5 69.00 % — — 164 Brown Wind 64.00 % 1 — — December 31, 2023 E.W. Brown Units 6-7 62.00 % $ 87 $ 45 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 25 — Trimble County Unit 2 60.75 % 1,043 227 24 Trimble County Units 5-6 71.00 % 86 41 — Trimble County Units 7-10 63.00 % 135 65 — Cane Run Unit 7 78.00 % 449 90 10 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — Mercer Solar 63.00 % 12 — 1 Mill Creek 5 69.00 % — — 3 Brown Wind 64.00 % 1 — — 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, 2024 and 2023, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2024 Trimble County Unit 1 75.00 % $ 462 $ 124 $ 1 Trimble County Unit 2 75.00 % 1,549 323 10 December 31, 2023 Trimble County Unit 1 75.00 % $ 464 $ 110 $ — Trimble County Unit 2 75.00 % 1,490 300 49 LG&E December 31, 2024 E.W. Brown Units 6-7 38.00 % $ 53 $ 29 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 30 — Trimble County Unit 1 75.00 % 462 124 1 Trimble County Unit 2 14.25 % 472 79 5 Trimble County Units 5-6 29.00 % 37 19 — Trimble County Units 7-10 37.00 % 82 41 1 Cane Run Unit 7 22.00 % 137 27 — E.W. Brown Solar Unit 39.00 % 10 4 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 10 — 1 Mill Creek 5 31.00 % — — 74 Brown Wind 36.00 % — — — December 31, 2023 E.W. Brown Units 6-7 38.00 % $ 53 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 29 — Trimble County Unit 1 75.00 % 464 110 — Trimble County Unit 2 14.25 % 447 74 25 Trimble County Units 5-6 29.00 % 37 17 — Trimble County Units 7-10 37.00 % 82 39 — Cane Run Unit 7 22.00 % 127 25 3 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 7 — — Mill Creek 5 31.00 % — — 2 Brown Wind 36.00 % — — — Ownership Electric Plant Accumulated Construction KU December 31, 2024 E.W. Brown Units 6-7 62.00 % $ 87 $ 48 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 26 — Trimble County Unit 2 60.75 % 1,077 224 5 Trimble County Units 5-6 71.00 % 87 44 — Trimble County Units 7-10 63.00 % 136 69 1 Cane Run Unit 7 78.00 % 485 95 1 E.W. Brown Solar Unit 61.00 % 16 6 — Solar Share 56.00 % 4 1 — Mercer Solar 63.00 % 16 — 2 Mill Creek 5 69.00 % — — 164 Brown Wind 64.00 % 1 — — December 31, 2023 E.W. Brown Units 6-7 62.00 % $ 87 $ 45 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 25 — Trimble County Unit 2 60.75 % 1,043 227 24 Trimble County Units 5-6 71.00 % 86 41 — Trimble County Units 7-10 63.00 % 135 65 — Cane Run Unit 7 78.00 % 449 90 10 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — Mercer Solar 63.00 % 12 — 1 Mill Creek 5 69.00 % — — 3 Brown Wind 64.00 % 1 — — 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.

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	12. Commitments and Contingencies Energy Purchase Commitments (PPL, LG&E and KU) 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 2026 Natural Gas Retail Supply 2025 Coal 2030 Coal Transportation and Fleeting Services 2033 Natural Gas Transportation 2055 LG&E and KU have a PPA with OVEC expiring in June 2040. See footnote (d) to the table in "Guarantees and Other Assurances" below for information on the OVEC power purchase contract. Future obligations for power purchases from OVEC are demand payments, comprised of debt-service payments and contractually-required reimbursements of plant operating, maintenance and other expenses, and are projected as follows: LG&E KU Total 2025 $ 25 $ 11 $ 36 2026 27 12 39 2027 27 12 39 2028 25 11 36 2029 25 11 36 Thereafter 177 79 256 Total $ 306 $ 136 $ 442 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2024 2023 2022 LG&E $ 21 $ 20 $ 21 KU 9 9 9 Total $ 30 $ 29 $ 30 (PPL) RIE enters into purchase contracts to supply electricity for electricity distribution operations and for the delivery, storage and supply of natural gas for RIE’s retail natural gas operations. These contracts include the following commitments: Contract Type Maximum Maturity Date Electric power 2027 Gas-related Beyond 2030 RIE’s commitments under these long-term contracts subsequent to December 31, 2024 are summarized in the table below. Total 2025 2026-2027 2028-2029 Thereafter Energy Purchase Obligations $ 936 $ 274 $ 240 $ 122 $ 300 Long-term Contracts for Renewable Energy (PPL) Several of the obligations included in the table above relate to certain long-term contracts for renewable energy, including: • the Deepwater Wind PPA, involving a proposal for a small-scale renewable energy generation project of up to eight offshore wind turbines with an aggregate nameplate capacity of up to 30 MW to benefit the Town of New Shoreham and an underwater cable to Block Island, which entered into service in October 2016; • the Three-State Procurement, involving six clean energy long-term contracts pursuant to the Rhode Island Long-Term Contracting Standard (LTCS) of which 36.427 MW is currently operational and with respect to which RIE collects 2.75% remunerations in the annual payments pursuant to the LTCS; and • the Offshore Wind Energy Procurement, pursuant to a 20-year PPA with Deep Water Wind Rev I, LLC (Revolution Wind), with an expected nameplate capacity of 408 MW expected to be operational in 2026; this contract was approved without remuneration but allows RIE to seek costs incurred under the agreement. In addition, RIE is obligated under the LTCS (as amended in 2014) to annually solicit for renewable projects until 90 MW of renewable contracting capacity has been secured. The RIPUC-approved solicitations currently in service include: (i) a 15-year PPA with Orbit Energy Rhode Island, LLC for a 3.2 MW nameplate anaerobic digester biogas project located in Johnston, Rhode Island, placed in service in 2017, (ii) a 15-year PPA with Black Bear Development Holdings, LLC for a 3.9 MW nameplate run-of-river hydroelectric plant located in Orono, Maine, placed in service in 2013, (iii) a 15-year PPA with Copenhagen Wind Farm, LLC for an 80 MW nameplate land-based wind project located in Denmark, New York, placed in service in 2018, and (iv) a 15-year PPA with Rhode Island LFG Genco, LLC for a 32.1 MW nameplate combined cycle combustion turbine generating facility fueled by a landfill gas project located in Johnston, Rhode Island, placed in service in 2013 . On October 7, 2024, RIE issued an RFP soliciting 20 MW through 150 MW of nameplate capacity of renewable contracting capacity; this solicitation is driven by a terminated PPA and is required in order to fulfill the 90 MW under LTCS. In addition to the LTCS, RIE has conditionally awarded 200 MW under the 2023 Rhode Island Offshore Wind RFP for newly developed offshore wind energy projects, under the Affordable Clean Energy Security Act (ACES), as amended in 2022. RIE is currently in the contract negotiation period. RIE must negotiate in good faith to achieve a commercially reasonable contract and may file such contract with the RIPUC for approval once negotiations are complete, which is tentatively scheduled for March 2025. As approved by the RIPUC, RIE is allowed to pass through commodity-related/purchased power costs to customers and collect remuneration equal to 2.75% for long-term contracts approved prior to January 1, 2022, pursuant to LTCS as amended in 2022, and that have achieved commercial operation. For long-term contracts approved pursuant to LTCS or ACES, both as amended, on or after January 1, 2022, RIE is entitled to financial remuneration equal to 1.0% through December 31, 2026, for those projects that are commercially operating. For long-term contracts approved pursuant to LTCS or ACES on or after January 1, 2027, RIE is not entitled to any financial remuneration, unless otherwise granted by the RIPUC. Also, the 2022 amendments to LTCS and ACES added a provision, which provides that for any calendar year in which RIE’s actual return on equity exceeds the return on equity allowed by the RIPUC in the last general rate case, the RIPUC may adjust any or all remuneration to assure that such remuneration does not result in or contribute toward RIE earning above its allowed return for such calendar year. Legal Matters (All Registrants) PPL and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business. PPL and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted. Narragansett Electric Litigation (PPL) Energy Efficiency Programs Investigation Narragansett Electric, while under the ownership of National Grid, performed an internal investigation into conduct associated with its energy efficiency programs. On June 27, 2022, the RIPUC opened a new docket (RIPUC Docket No. 22-05-EE) to investigate RIE’s actions and the actions of employees of National Grid USA and affiliates during the time RIE was a National Grid USA affiliate being provided services by National Grid USA Service Company, Inc. relating to the manipulation of the reporting of invoices affecting the calculation of past energy efficiency shareholder incentives and the resulting impact on customers. The Rhode Island Attorney General and National Grid USA intervened in the docket and the Rhode Island Division of Public Utilities and Carriers (the Division) is an automatic party in the docket. On January 19, 2023, the Division filed a motion to dismiss RIPUC Docket No. 22-05-EE without prejudice. As grounds for its motion, the Division stated that sufficient evidence exists in the docket to warrant an independent summary investigation by the Division. If the Division finds sufficient grounds, the Division may proceed to a formal hearing regarding the matters under investigation. Upon the conclusion of its investigation, the Division will provide the RIPUC with a report outlining the Division’s findings and final decision. On January 30, 2023, the Rhode Island Attorney General filed an objection to the Division’s motion to dismiss; RIE and National Grid USA each filed responses with the RIPUC requesting that any additional action taken by the RIPUC or the Division be considered after National Grid USA completes its internal investigation report, which National Grid USA filed with the RIPUC on March 10, 2023. On February 24, 2023, the Division initiated the independent summary investigation that it had referenced in its motion to dismiss. The RIPUC held a hearing on March 28, 2023 to hear oral arguments regarding the Division’s motion to dismiss and subsequently denied the motion. On November 27, 2023, the Division filed testimony recommending the RIPUC disallow a portion of the performance incentive awarded from 2012 through 2021. On January 19, 2024, the Division and the Rhode Island Attorney General filed their respective briefs recommending that the RIPUC assess financial penalties on the company. The Division also recommended that the RIPUC consider further regulatory investigations and analysis within each of the energy efficiency dockets from 2012 through 2020, to confirm the accuracy of claimed savings and to document all conduct and actions that would trigger penalties. On April 2, 2024, the RIPUC issued an amended order that expressly expands the scope of the proceeding to address issues of accountability and the question of whether statutory penalties should be assessed against RIE relating to the manipulation of the reporting of invoices affecting the recovery of past shareholder incentives and the resulting impact on RIE’s customers. This RIPUC proceeding remains open and, in parallel, the Division’s summary investigation remains ongoing. In the RIPUC proceeding, RIE and National Grid USA filed testimony on June 14, 2024, supporting their position that the appropriate amount to be refunded to the energy efficiency program is less than $1 million. The Division’s current position is that $11 million is the appropriate amount to be refunded to the energy efficiency program. This testimony does not address potential statutory penalties and the Division’s testimony on potential statutory penalties is due February 28, 2025. The Division’s testimony on accountability and potential statutory penalties is currently due February 21, 2025, and RIE’s and National Grid’s reply testimony will occur at the evidentiary hearings scheduled for March 2025. At this time, it is not possible to predict the final outcome, or determine the total amount of any additional liabilities that may be incurred by RIE in connection with this matter or the Division’s summary investigation. RIE does not expect this matter will have a material adverse effect on its results of operations, financial position or cash flows. E.W. Brown Environmental Assessment ( PPL and KU) KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. The aquatic study and risk assessment are being undertaken pursuant to a 2017 agreed Order with the Kentucky Energy and Environment Cabinet (KEEC). KU conducted sampling of Herrington Lake in 2017 and 2018. In June 2019, KU submitted to the KEEC the required aquatic study and risk assessment, conducted by an independent third-party consultant, finding that discharges from the E.W. Brown plant have not had any significant impact on Herrington Lake and that the water in the lake is safe for recreational use and meets safe drinking water standards. On May 31, 2021, the KEEC approved the report and released a response to public comments. On August 6, 2021, KU submitted a Supplemental Remedial Alternatives Analysis report to the KEEC that outlines proposed additional fish, water, and sediment testing. On February 18, 2022, the KEEC provided approval to KU to proceed with the proposed sampling, which commenced in the spring of 2022. On November 17, 2022, KU submitted a Supplemental Performance Monitoring Report to the KEEC finding that there are no significant unaddressed risks to human health or the environment at the plant. KU revised the Supplemental Performance Monitoring Report on June 8, 2023, in response to KEEC comments from April 24, 2023. On September 1, 2023, the KEEC requested KU to propose additional monitoring or remedial measures. KU submitted a revised Supplemental Performance Monitoring and Corrective Action Completion on December 28, 2023. In August 2024, KU submitted a proposed environmental covenant to the KEEC specifying certain site restrictions. Discussions between KU and the KEEC are ongoing. Water/Waste (PPL, LG&E and KU) ELGs In 2015, the EPA finalized ELGs for wastewater discharge permits for new and existing steam electricity generating facilities. These guidelines require deployment of additional control technologies providing physical, chemical and biological treatment and mandate operational changes including "zero discharge" requirements for certain wastewaters. The implementation date for individual generating stations was to be determined by the states on a case-by-case basis according to criteria provided by the EPA. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. In October 2020, the EPA issued revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). On May 9, 2024, the EPA issued a final rule modifying the 2020 ELG revisions. The rule increases the stringency of previous control technology and zero discharge requirements, revises certain exemptions for generating units planned for retirement, and requires case-by-case limitations for legacy wastewaters based on the best professional judgment of the state regulators. Legal challenges to the final rule have been consolidated before the U.S. Court of Appeals for the Eighth Circuit. The final rule is currently under evaluation by PPL, LG&E, and KU, but could potentially result in significant operational changes and additional controls for LG&E and KU plants. The ELGs are expected to be implemented by the states or applicable permitting authorities in the course of their normal permitting activities. Certain costs are included in the Registrants' capital plans and expected to be recovered from customers through rate recovery mechanisms, but additional costs and recovery will depend on further regulatory developments at the state level. CCRs In 2015, the EPA issued a final rule governing management of CCRs which include fly ash, bottom ash and sulfur dioxide scrubber wastes (2015 CCR Rule). The 2015 CCR Rule imposed extensive new requirements for certain CCR impoundments and landfills, including public notifications, location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements, and specifies restrictions relating to the beneficial use of CCRs. In January 2022, the EPA issued several proposed regulatory determinations, facility notifications, and public announcements which indicate increased scrutiny by the EPA to determine the adequacy of measures taken by facility owners and operators to achieve closure of CCR surface impoundments and landfills. In particular, the agency indicated that it will focus on certain practices which it views as posing a threat of continuing groundwater contamination. On May 8, 2024, the EPA issued a final rule (2024 CCR Rule) establishing regulatory requirements for inactive surface impoundments at inactive electricity generation facilities (legacy impoundments). The 2024 CCR Rule also establishes identification, groundwater monitoring, corrective action, closure, and post-closure care requirements for all CCR management units, as defined in the rule, at regulated CCR facilities regardless of how or when the CCR was placed. The rule also requires LG&E and KU to complete applicability determinations, implement site security measures, initiate weekly inspections and monthly monitoring of the impoundment, create a website, and complete hazard assessments and reports for its legacy impoundments. Additionally, the rule could potentially subject CCR management units that have previously completed remedial action and closure and certain beneficial use projects to additional federal regulatory requirements. Legal challenges to the rule have been filed in the D.C. Circuit Court, and oral argument is expected in the second half of 2025. In connection with the 2015 CCR Rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015. In connection with the 2024 CCR Rule, in the second quarter of 2024, LG&E and KU recognized ARO obligations related to preliminary risk assessments, facility evaluations, feasibility studies and sampling. See Note 18 for additional information. The results of those evaluations, as well as future guidance, regulatory determinations, rulemakings, implementation determinations and other developments could potentially require revisions to current LG&E and KU compliance plans including additional monitoring and remediation at surface impoundments and landfills, the cost of which could be material. PPL, LG&E and KU are unable to predict the outcome of the ongoing litigation, rulemaking, and regulatory determinations or potential impacts on current LG&E and KU compliance plans. PPL, LG&E and KU are currently finalizing or revising closure plans and schedules in accordance with applicable regulations and further material changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are expected to be subject to rate recovery. LG&E and KU received KPSC approval for a compliance plan associated with the 2015 CCR Rule providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR Rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. LG&E and KU have completed planned closure measures at most of the subject impoundments and have commenced post closure groundwater monitoring as required at those facilities. LG&E and KU generally expect to complete all impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery. Superfund and Other Remediation (All Registrants) The Registrants are potentially responsible for investigating and remediating contamination under the federal Superfund program and similar state programs. Actions are under way at certain sites including former manufactured gas plants in Pennsylvania, Rhode Island and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL subsidiaries. Depending on the outcome of investigations at identified sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred. PPL, PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability or range of reasonably possible losses, if any, related to these sites. Such costs, however, are not currently expected to be significant. The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of manufactured gas plant operations. As a result, individual states may establish stricter standards for water quality and soil cleanup, that could require several PPL subsidiaries to take more extensive assessment and remedial actions at former manufactured gas plants. The Registrants cannot reasonably estimate a range of possible losses, if any, related to these matters. (PPL and PPL Electric) PPL Electric is a potentially responsible party for a share of clean-up costs at certain sites. Cleanup actions have been or are being undertaken at these sites as requested by governmental agencies, the costs of which have not been and are not expected to be significant to PPL Electric. At December 31, 2024 and December 31, 2023, PPL Electric had a recorded liability of $8 million and $8 million, representing its best estimate of the probable loss incurred to remediate these sites. (PPL) RIE is a potentially responsible party for a share of clean-up costs at certain sites including former manufactured gas plant facilities formerly owned by the Blackstone Valley Gas and Electric Company and the Rhode Island gas distribution assets of the New England Gas division of Southern Union Company and electric operations at certain RIE facilities. RIE is currently investigating and remediating, as necessary, those sites and certain other properties under agreements with governmental agencies, the costs of which have not been and are not expected to be significant to PPL. At December 31, 2024 and December 31, 2023, RIE had a recorded liability of $98 million and $99 million, representing its best estimate of the remaining costs of environmental remediation activities. These undiscounted costs are expected to be incurred over approximately 30 years and to be subject to rate recovery. However, remediation costs for each site may be materially higher than estimated, depending on changing technologies and regulatory standards, selected end uses for each site, and actual environmental conditions encountered. RIE has recovered amounts from certain insurers and potentially responsible parties, and, where appropriate, may seek additional recovery from other insurers and potentially responsible parties, but it is uncertain whether, and to what extent, such efforts will be successful. The RIPUC has approved two settlement agreements that provide for rate recovery of qualified remediation costs of certain contaminated sites located in Rhode Island and Massachusetts. Rate-recoverable contributions for electric operations of approximately $3 million are added annually to RIE's Environmental Response Fund, established with RIPUC approval in March 2000 to address such costs, along with interest and any recoveries from insurance carriers and other third-parties. In addition, RIE recovers approximately $1 million annually for gas operations under a distribution adjustment charge in which the qualified remediation costs are amortized over 10 years. See Note 7 for additional information on RIE's recorded environmental regulatory assets and liabilities. Regulatory Issues See Note 7 for information on regulatory matters related to utility rate regulation. Electricity - Reliability Standards The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk electric system in North America. The FERC oversees this process and independently enforces the Reliability Standards. The Reliability Standards have the force and effect of law and apply to certain users of the bulk electric system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties for certain violations. PPL Electric, LG&E, KU and RIE monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC. In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and an estimate or range of possible losses cannot be determined. Gas - Security Directives (PPL and LG&E) In May and July of 2021, the Department of Homeland Security’s (DHS) Transportation Security Administration released two security directives applicable to certain notified owners and operators of natural gas pipeline facilities (including local distribution companies) that the Transportation Security Administration has determined to be critical. The Transportation Security Administration has determined that LG&E is within the scope of the directive, while RIE has not been notified of this distinction. The first security directive required notified owners/operators to implement cybersecurity incident reporting to the DHS, designate a cybersecurity coordinator, and perform a gap assessment of current entity cybersecurity practices against certain voluntary Transportation Security Administration security guidelines and report relevant results and proposed mitigation to applicable DHS agencies. The second security directive, revised in July of 2024, requires refinement of the cybersecurity implementation plan and the cybersecurity assessment plan. LG&E does not believe the security directives have had or will have a significant impact on LG&E’s operations or financial condition. Other Guarantees and Other Assurances (All Registrants) In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Examples of such agreements include guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage. (PPL) PPL fully and unconditionally guarantees all of the debt obligations of PPL Capital Funding. (All Registrants) The table below details guarantees provided as of December 31, 2024. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The Registrants believe the probability of expected payment/performance under each of these guarantees is remote, except for the guarantees and indemnifications related to the sale of Safari Holdings, which PPL believes are reasonably possible but not probable of occurring. For reporting purposes, on a consolidated basis, the guarantees of PPL include the guarantees of its subsidiary Registrants. Exposure at December 31, 2024 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 $ 100 (b) 2028 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 (c) Various LG&E and KU LG&E and KU obligation of shortfall related to OVEC (d) (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. (c) 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. PPL's support obligations related to the PPAs were replaced by Aspen Power and terminated on January 8, 2024. (d) 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 $81 million at December 31, 2024, consisting of LG&E's share of $56 million and KU's share of $25 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. The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is remote. PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $231 million. This insurance may be applicable to obligations under certain of these contractual arrangements.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2024
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 the Registrants, their respective subsidiaries 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 LKS 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. PPL 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. 2024 2023 2022 PPL Electric from PPL Services $ 227 $ 222 $ 241 LG&E from LKS 105 115 153 LG&E from PPL Services 66 42 13 KU from LKS 130 150 171 KU from PPL Services 65 48 14 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) CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2024, CEP Reserves had $ 222 million no (LG&E and KU) 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 SOFR. At December 31, 2024, LG&E's money pool unused capacity was $682 million. At December 31, 2024 LG&E had borrowings outstanding of $ 43 million 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 SOFR. At December 31, 2024, KU's money pool unused capacity was $437 million. At December 31, 2024 KU had borrowings outstanding of $ 73 million VEBA Funds Receivable (PPL Electric) 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. In October 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing 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 PPL Electric's 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 $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's balance sheets. There was no intercompany receivable balance associated with these funds at December 31, 2023, as the initial allocation from the 2018 private letter ruling was depleted. 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 10 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 the Registrants, their respective subsidiaries 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 LKS 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. PPL 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. 2024 2023 2022 PPL Electric from PPL Services $ 227 $ 222 $ 241 LG&E from LKS 105 115 153 LG&E from PPL Services 66 42 13 KU from LKS 130 150 171 KU from PPL Services 65 48 14 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) CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2024, CEP Reserves had $ 222 million no (LG&E and KU) 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 SOFR. At December 31, 2024, LG&E's money pool unused capacity was $682 million. At December 31, 2024 LG&E had borrowings outstanding of $ 43 million 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 SOFR. At December 31, 2024, KU's money pool unused capacity was $437 million. At December 31, 2024 KU had borrowings outstanding of $ 73 million VEBA Funds Receivable (PPL Electric) 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. In October 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing 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 PPL Electric's 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 $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's balance sheets. There was no intercompany receivable balance associated with these funds at December 31, 2023, as the initial allocation from the 2018 private letter ruling was depleted. 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 10 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 the Registrants, their respective subsidiaries 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 LKS 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. PPL 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. 2024 2023 2022 PPL Electric from PPL Services $ 227 $ 222 $ 241 LG&E from LKS 105 115 153 LG&E from PPL Services 66 42 13 KU from LKS 130 150 171 KU from PPL Services 65 48 14 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) CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At December 31, 2024, CEP Reserves had $ 222 million no (LG&E and KU) 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 SOFR. At December 31, 2024, LG&E's money pool unused capacity was $682 million. At December 31, 2024 LG&E had borrowings outstanding of $ 43 million 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 SOFR. At December 31, 2024, KU's money pool unused capacity was $437 million. At December 31, 2024 KU had borrowings outstanding of $ 73 million VEBA Funds Receivable (PPL Electric) 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. In October 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited into the existing 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 PPL Electric's 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 $7 million at December 31, 2024, of which $4 million was reflected in "Accounts receivable from affiliates" and $3 million was reflected in "Other noncurrent assets" on PPL Electric's balance sheets. There was no intercompany receivable balance associated with these funds at December 31, 2023, as the initial allocation from the 2018 private letter ruling was depleted. 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 10 for discussions regarding intercompany allocations associated with defined benefits.

Other Income (Expense) - net

Other Income (Expense) - net	12 Months Ended
	Dec. 31, 2024
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: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 42 $ 40 $ 47 Interest income 33 32 4 AFUDC - equity component 47 30 22 Charitable contributions (5) (5) (14) Talen litigation (a) (2) (124) 1 Miscellaneous (1) (13) (6) Other Income (Expense) - net $ 114 $ (40) $ 54 (a) PPL incurred legal expenses related to litigation associated with its former affiliate, Talen Montana, LLC, and certain affiliated entities (collectively, Talen), which was settled in December 2023. (PPL Electric) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 17 $ 20 $ 15 Interest income 8 8 3 AFUDC - equity component 23 16 16 Charitable contributions (4) (3) (3) Miscellaneous 1 (2) (1) Other Income (Expense) - net $ 45 $ 39 $ 30 (LG&E) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 3 $ — $ 3 AFUDC - equity component 8 3 1 Charitable contributions (1) (1) (1) Miscellaneous 2 1 1 Other Income (Expense) - net $ 12 $ 3 $ 4 (KU) The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 8 $ 6 $ 9 AFUDC - equity component 9 3 1 Charitable contributions (1) (1) — Miscellaneous (1) — (2) Other Income (Expense) - net $ 15 $ 8 $ 8

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2024
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, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 306 $ 306 $ — $ — $ 331 $ 331 $ — $ — Restricted cash and cash equivalents (a) 33 33 — — 51 51 — — Total Cash, Cash Equivalents and Restricted Cash (b) 339 339 — — 382 382 — — Special use funds (a): Money market fund 1 1 — — 1 1 — — Commingled debt fund measured at NAV (c) 10 — — — 9 — — — Commingled equity fund measured at NAV (c) 8 — — — 8 — — — Total special use funds 19 1 — — 18 1 — — December 31, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Price risk management assets (d): Gas contracts 9 — 4 5 1 — 1 — Total assets $ 367 $ 340 $ 4 $ 5 $ 401 $ 383 $ 1 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Gas contracts 13 — 10 3 60 — 41 19 Total price risk management liabilities $ 16 $ — $ 13 $ 3 $ 67 $ — $ 48 $ 19 PPL Electric Assets Cash and cash equivalents $ 24 $ 24 $ — $ — $ 51 $ 51 $ — $ — Total assets $ 24 $ 24 $ — $ — $ 51 $ 51 $ — $ — LG&E Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 18 $ 18 $ — $ — Restricted cash and cash equivalents (a) 16 16 — — 26 26 — — Total Cash, Cash Equivalents and Restricted Cash (b) 24 24 — — 44 44 — — Total assets $ 24 $ 24 $ — $ — $ 44 $ 44 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 13 $ 13 $ — $ — $ 14 $ 14 $ — $ — Restricted cash and cash equivalents (a) 16 16 — — 24 24 — — Total Cash, Cash Equivalents and Restricted Cash (b) 29 29 — — 38 38 — — Total assets $ 29 $ 29 $ — $ — $ 38 $ 38 $ — $ — (a) Current portion is included in "Other current assets" and noncurrent 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 assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" "Other deferred credits and noncurrent liabilities" on the Balance Sheets. A reconciliation of net assets classified as Level 3 for the year ended December 31 is as follows: Gas Contracts 2024 Balance at beginning of period $ (19) Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities 2 Settlements 19 Balance at end of period $ 2 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. In 2024, additional excess funds were removed from the PPL Bargaining Unit Retiree Health Plan VEBA and deposited in the existing 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., 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 in 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, 2024 December 31, 2023 Carrying Fair Value Carrying Fair Value PPL $ 16,503 $ 15,562 $ 14,612 $ 14,031 PPL Electric 5,214 4,862 4,567 4,475 LG&E 2,471 2,295 2,469 2,369 KU 3,066 2,750 3,064 2,861 (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, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	16. 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 Vice President-Financial Strategy and Chief Risk Officer, 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 also 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. Additionally, 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 be required 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, LG&E and KU had no cash collateral posted or obligation to return cash collateral under master netting arrangements at December 31, 2024 and 2023. 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 cases. 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, 2024. 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 2024, 2023 and 2022, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At December 31, 2024, 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, 2024, LG&E held contracts with a notional amount of $64 million that mature in 2033. Commodity Price Risk (PPL) Economic Activity RIE enters into 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. See Note 7 for amounts recorded in regulatory assets and regulatory liabilities at December 31, 2024. At December 31, 2024, RIE held contracts with notional volumes of 49 Bcf that range in maturity from 2025 through 2029. 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, 2024 and 2023. 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, 2024 December 31, 2023 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 Gas contracts — — 7 10 — — 1 51 Total current — — 7 10 — — 1 52 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 3 — — — 6 Gas contracts — — 2 3 — — — 9 Total noncurrent — — 2 6 — — — 15 Total derivatives $ — $ — $ 9 $ 16 $ — $ — $ 1 $ 67 (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 2024 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) 2023 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) 2022 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) Derivatives Not Designated as Location of Gain (Loss) Recognized in 2024 2023 2022 Interest rate swaps Interest Expense — — (2) Gas contracts Energy Purchases (40) (19) 41 Other income (expense) - net — $ (1) $ — Total $ (40) $ (20) $ 39 Derivatives Not Designated as Location of Gain (Loss) Recognized as 2024 2023 2022 Gas contracts Regulatory assets - current $ 48 $ 9 $ 39 Regulatory assets - noncurrent 7 (8) — Interest rate swaps Regulatory assets - noncurrent 4 — 11 Total $ 59 $ 1 $ 50 The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2024: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 738 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) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2023: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 666 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) 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 Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 513 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) (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, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ — $ — $ 1 Total current — — — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 3 — 6 Total noncurrent — 3 — 6 Total derivatives $ — $ 3 $ — $ 7 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) 2024 2023 2022 Interest rate swaps Interest Expense $ — $ — $ (2) Derivative Instruments Location of Gain (Loss) 2024 2023 2022 Interest rate swaps Regulatory assets - noncurrent $ 4 $ — $ 11 (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, 2024 Derivatives PPL $ 9 $ 5 $ — $ 4 $ 16 $ 5 $ — $ 11 LG&E — — — — 3 — — 3 December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7 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 would 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, 2024, derivative contracts in a net liability position that contain credit risk-related contingent features was $3 million. The aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $4 million.

Goodwill and Other Intangible A

Goodwill and Other Intangible Assets	12 Months Ended
	Dec. 31, 2024
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Other Intangible Assets	17. 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 2024 2023 2024 2023 2024 2023 2024 2023 Balance at beginning of period (a) $ 662 $ 662 $ 725 $ 725 $ 860 $ 861 $ 2,247 $ 2,248 Goodwill recognized during the period (b) — — — — — (1) — (1) Total $ 662 $ 662 $ 725 $ 725 $ 860 $ 860 $ 2,247 $ 2,247 (a) There were no accumulated impairment losses related to goodwill. (b) Recognized as a result of purchase price allocation adjustments related to the acquisition of RIE. 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, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 125 $ 116 $ 125 $ 107 Renewable Energy Credits 20 — 15 — Land rights and easements 432 147 411 143 Licenses and other 2 — 2 — Total subject to amortization 579 263 553 250 Not subject to amortization due to indefinite life: Land rights and easements 18 — 18 — Total not subject to amortization due to indefinite life 18 — 18 — Total $ 597 $ 263 $ 571 $ 250 (a) Gross carrying amount in 2024 and 2023 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: 2024 2023 2022 Intangible assets with no regulatory offset $ 5 $ 5 $ 5 Intangible assets with regulatory offset 8 9 9 Total $ 13 $ 14 $ 14 Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4 Intangible assets with regulatory offset 8 2 — — — Total $ 12 $ 6 $ 4 $ 4 $ 4 (PPL Electric) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 396 $ 141 $ 389 $ 138 Licenses and other 2 1 2 1 Total subject to amortization 398 142 391 139 Not subject to amortization due to indefinite life: Land rights and easements 18 — 17 — Total $ 416 $ 142 $ 408 $ 139 Intangible assets are shown as "Intangibles" on the Balance Sheets. Amortization expense was as follows: 2024 2023 2022 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 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, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 2 $ 7 $ 2 OVEC power purchase agreement (a) 86 79 86 73 Total subject to amortization $ 93 $ 81 $ 93 $ 75 (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: 2024 2023 2022 Intangible assets with regulatory offset $ 6 $ 6 $ 6 Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 Intangible assets with regulatory offset $ 6 $ 1 $ — $ — $ — (KU) The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 29 $ 4 $ 17 $ 4 OVEC power purchase agreement (a) 39 36 39 33 Total subject to amortization $ 68 $ 40 $ 56 $ 37 (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: 2024 2023 2022 Intangible assets with regulatory offset 2 3 3 Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 Intangible assets with regulatory offset $ 2 $ 1 $ — $ — $ —

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2024
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 12 for information on the CCR rule. LG&E and RIE also have 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, KU, and RIE , 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 2024 2023 2024 2023 2024 2023 ARO at beginning of period $ 158 $ 177 $ 85 $ 86 $ 66 $ 82 Accretion 8 9 4 4 4 5 Obligations incurred 9 2 3 1 6 1 Changes in estimated timing or cost 4 15 3 11 1 6 Obligations settled (24) (39) (11) (11) (13) (28) Other 2 (6) — (6) — ARO at end of period $ 157 $ 158 $ 84 $ 85 $ 64 $ 66

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2024
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, 2021 $ — $ 1 $ — $ (6) $ (152) $ (157) 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) Amounts arising during the year — — 1 — (41) (40) Reclassifications from AOCI — 3 — 1 (3) 1 Net OCI during the year — 3 1 1 (44) (39) December 31, 2023 $ — $ 6 $ 3 $ (4) $ (168) $ (163) Amounts arising during the year — — 1 — (22) (21) Reclassifications from AOCI — 3 — 1 (4) — Net OCI during the year — 3 1 1 (26) (21) December 31, 2024 $ — $ 9 $ 4 $ (3) $ (194) $ (184) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the years ended December 31, 2024, 2023 and 2022. 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 10 for additional information. PPL Details about AOCI 2024 2023 2022 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (3) $ (3) $ (3) Interest Expense Total Pre-tax (3) (3) (3) Income Taxes — — 1 Total After-tax (3) (3) (2) Defined benefit plans Prior service costs (1) (2) (3) Net actuarial loss 4 3 (24) Total Pre-tax 3 1 (27) Income Taxes — 1 8 Total After-tax 3 2 (19) Total reclassifications during the year $ — $ (1) $ (21)

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	12 Months Ended
	Dec. 31, 2024
Accounting Standards Update and Change in Accounting Principle [Abstract]
New Accounting Guidance Pending Adoption	20. New Accounting Guidance Pending Adoption (All Registrants) Improvements to Income Tax Disclosures In December 2023, the FASB issued guidance which requires public business entities to provide additional income tax disclosures including a disaggregated rate reconciliation as well as information on income taxes paid. For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued or made available for issuance. The Registrants are currently assessing the impact of adopting this guidance. Disaggregation of Income Statement Expenses In November 2024, the FASB issued guidance which requires public business entities to provide in the notes to financial statements specified information about certain costs and expenses. This includes the disclosure of amounts of (a) purchases of inventory, (b) employee compensation, (c) depreciation, (d) intangible asset amortization, and (e) depreciation, depletion, and amortization recognized as part of oil and gas-producing activities (DD&A) included in each relevant income statement expense caption. A relevant expense caption is an expense caption included on the face of the income statement within continuing operations that contains any of the specified expense categories (a)-(e). A qualitative description of the amounts remaining in relevant expense captions that are not separately disaggregated must also be disclosed. Additionally, public business entities must disclose the total amount of selling expenses and, in annual reporting periods, the entity’s definition of selling expenses. For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2026, and interim periods reporting periods beginning after December 15, 2027. Early adoption is permitted. The Registrants are currently assessing the impact of adopting this guidance.

Pay vs Performance Disclosure

Pay vs Performance Disclosure - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Pay vs Performance Disclosure
Net income (loss)	$ 888	$ 740	$ 756

Insider Trading Arrangements

Insider Trading Arrangements	12 Months Ended
	Dec. 31, 2024
Trading Arrangements, by Individual
Rule 10b5-1 Arrangement Adopted	true
Non-Rule 10b5-1 Arrangement Adopted	false
Adoption Date	November 26, 2024
Rule 10b5-1 Arrangement Terminated	false
Non-Rule 10b5-1 Arrangement Terminated	false

Cybersecurity Risk Management a

Cybersecurity Risk Management and Strategy Disclosure	12 Months Ended
	Dec. 31, 2024
Cybersecurity Risk Management, Strategy, and Governance [Line Items]
Cybersecurity Risk Management Processes for Assessing, Identifying, and Managing Threats [Text Block]	Processes for Identifying, Assessing and Managing Material Risks from Cybersecurity Threats PPL’s Chief Security Officer (CSO) is responsible for establishing, implementing and executing PPL’s cyber-risk management strategy for PPL and the other Registrants and reports to PPL’s Executive Vice President and Chief Technology and Innovation Officer. The CSO has over 25 years of experience leading technology and security organizations, has a degree in computer science, and holds professional certifications in information security, IT auditing, and privacy. He is also a member of nationally and internationally recognized industry and security organizations, including the Information Systems Audit and Control Association, International Association of Privacy Professionals, and the Domestic Security Alliance Council. The teams managed by the CSO are comprised of seasoned experts in cyber and IT security and possess appropriate experience to safeguard the company’s data, networks and systems, mitigate cyber risks and help prevent and combat cyber threats. The Registrants manage cybersecurity risks through monitoring, defense and response tools, including independent third-party assessments, internal audit assessments of the program’s effectiveness, intelligence reports, cybersecurity threat trends, implementation of governance models, industry collaboration and employee training and awareness. The Registrants are actively engaged in cybersecurity related industry forums, public-private partnerships with law enforcement, cross-industry peer groups, and other efforts to help improve the protection of the U.S. electric grid. The Registrants utilize monitoring tools, including but not limited to, cybersecurity incident and event management, penetration testing, intrusion detection and prevention, vulnerability assessments and anti-virus systems to detect anomalous or suspicious system or network activity. The Registrants may also become aware of a potential cybersecurity event or incident through employee reports, notification by a third-party service provider or business partner with potential impact to the Registrants or their systems, customers or notification by a government agency. The Registrants’ subject matter specialists from across the enterprise provide input and expertise into risk governance processes, including cybersecurity, information technology, legal, compliance, operations, and enterprise risk management. In developing their cybersecurity programs, the Registrants are guided by various frameworks including the NIST Cybersecurity Framework, a voluntary framework that consists of standards, guidelines and best practices for managing cybersecurity risk, that is widely used by critical infrastructure industries to help determine and address the highest priority cybersecurity risks. The Registrants conduct regular internal cybersecurity audits and vulnerability assessments and regularly engage with third-party cybersecurity experts for external assessments of their cybersecurity controls, including technical, physical and social aspects, to better comprehend the scope and magnitude of active threats to the industry and nation and their potential impact on our systems. The CSO chairs the Corporate Security Council, which holds regular meetings consisting of senior executive management and reviews and oversees cybersecurity risks. PPL and the other Registrants also maintain a process to review the cyber risks that arise from the use of third-party service providers as well as programs and procedures to mitigate such risks internally and to assess the extent to which such providers effectively manage their own cyber risks. PPL has established an Executive Crisis Team comprised of PPL’s executive leadership, including the Chief Executive Officer, Chief Technology and Innovation Officer, Chief Financial Officer, Chief Human Resources Officer, Chief Legal Officer, Chief Operating Officer, VP – Public Affairs and Sustainability, VP – Corporate Communications, Chief Security Officer and additional officers as circumstances may warrant, to allow the company to respond quickly to a crisis, including a cyber event. This team governs and manages corporate crisis preparedness across the business lines, operations, and functions. Material or potentially material risks are escalated to the Executive Crisis Team and other appropriate leadership for review and action. Also, the Registrants’ workforce undertakes mandatory role-based annual training on identifying, reporting, and escalating cyber and physical security concerns to further assist in the identification of risks as well as the acceptable use of corporate electronic resources. Additionally, all employees and contractors are required to participate in the Registrants’ ethical cyber phishing campaign program. In addition to these enterprise-wide initiatives, PPL's Kentucky, Pennsylvania and Rhode Island operations are subject to extensive and rigorous mandatory cybersecurity requirements that are developed and enforced by NERC and approved by the FERC to protect grid security and reliability. LG&E is also subject to certain security directives related to cybersecurity issued by the Department of Homeland Security’s Transportation Security Administration in 2021. See Note 12 to the Financial Statements for additional information on these directives. The Registrants have been subject to attempted cybersecurity threats and will likely continue to be subject to such attempts in the future. While PPL has not determined any cybersecurity incidents have materially affected the Registrants, including their business strategy, results of operations or financial condition, there can be no guarantee that the Registrants will not be the subject of future attacks, threats or incidents, the consequences of which may be material. See “Risks Related to All Segments – Our business operations are continually subject to cyber-based security and data integrity risks from vulnerabilities related to our IT systems, operational technology infrastructure and supply chain relationships” in “Item 1A. Risk Factors” for a discussion of cybersecurity risks affecting the Registrants.
Cybersecurity Risk Management Processes Integrated [Flag]	true
Cybersecurity Risk Management Processes Integrated [Text Block]	The Registrants’ subject matter specialists from across the enterprise provide input and expertise into risk governance processes, including cybersecurity, information technology, legal, compliance, operations, and enterprise risk management.
Cybersecurity Risk Management Third Party Engaged [Flag]	true
Cybersecurity Risk Third Party Oversight and Identification Processes [Flag]	true
Cybersecurity Risk Materially Affected or Reasonably Likely to Materially Affect Registrant [Flag]	false
Cybersecurity Risk Board of Directors Oversight [Text Block]	Oversight of Cybersecurity Risks by the Board of Directors and Management PPL’s Board of Directors oversees the Registrants’ management of cybersecurity risk through various processes identified below. The Board has direct oversight of the Registrants’ cybersecurity programs through periodic reports from the CSO, at least twice a year, regarding cybersecurity matters and risks as well as the adequacy and effectiveness of our cybersecurity risk management program. Through these reports, the Board monitors the Registrants’ programs, processes and procedures related to cybersecurity. The Board has directed the CEO and CSO to promptly inform the Board in the event of a material or potentially material cybersecurity event. Each member of the Board has access to management, including the CEO and CSO, to ask questions and engage on the company’s approach to prevent, detect, assess, and mitigate cybersecurity risk. PPL’s Board has several Board members with experience in cybersecurity, including one with a certificate in Cyber-Risk Oversight from the National Association of Corporate Directors. A primary function of the Audit Committee is to assist the Board in the oversight of the identification, assessment and management of risk. Cybersecurity risks are included in PPL’s enterprise risk management process and are reported to the Audit Committee of the Board on a quarterly basis or more frequently, as needed.
Cybersecurity Risk Board Committee or Subcommittee Responsible for Oversight [Text Block]	A primary function of the Audit Committee is to assist the Board in the oversight of the identification, assessment and management of risk.
Cybersecurity Risk Process for Informing Board Committee or Subcommittee Responsible for Oversight [Text Block]	The Board has direct oversight of the Registrants’ cybersecurity programs through periodic reports from the CSO, at least twice a year, regarding cybersecurity matters and risks as well as the adequacy and effectiveness of our cybersecurity risk management program. Through these reports, the Board monitors the Registrants’ programs, processes and procedures related to cybersecurity. The Board has directed the CEO and CSO to promptly inform the Board in the event of a material or potentially material cybersecurity event. Each member of the Board has access to management, including the CEO and CSO, to ask questions and engage on the company’s approach to prevent, detect, assess, and mitigate cybersecurity risk.
Cybersecurity Risk Role of Management [Text Block]	PPL’s Chief Security Officer (CSO) is responsible for establishing, implementing and executing PPL’s cyber-risk management strategy for PPL and the other Registrants and reports to PPL’s Executive Vice President and Chief Technology and Innovation Officer. The CSO has over 25 years of experience leading technology and security organizations, has a degree in computer science, and holds professional certifications in information security, IT auditing, and privacy. He is also a member of nationally and internationally recognized industry and security organizations, including the Information Systems Audit and Control Association, International Association of Privacy Professionals, and the Domestic Security Alliance Council. The teams managed by the CSO are comprised of seasoned experts in cyber and IT security and possess appropriate experience to safeguard the company’s data, networks and systems, mitigate cyber risks and help prevent and combat cyber threats. The CSO chairs the Corporate Security Council, which holds regular meetings consisting of senior executive management and reviews and oversees cybersecurity risks. PPL and the other Registrants also maintain a process to review the cyber risks that arise from the use of third-party service providers as well as programs and procedures to mitigate such risks internally and to assess the extent to which such providers effectively manage their own cyber risks. PPL has established an Executive
Cybersecurity Risk Management Positions or Committees Responsible [Flag]	true
Cybersecurity Risk Management Positions or Committees Responsible [Text Block]	PPL’s Chief Security Officer (CSO) is responsible for establishing, implementing and executing PPL’s cyber-risk management strategy for PPL and the other Registrants and reports to PPL’s Executive Vice President and Chief Technology and Innovation Officer.
Cybersecurity Risk Management Expertise of Management Responsible [Text Block]	The CSO has over 25 years of experience leading technology and security organizations, has a degree in computer science, and holds professional certifications in information security, IT auditing, and privacy. He is also a member of nationally and internationally recognized industry and security organizations, including the Information Systems Audit and Control Association, International Association of Privacy Professionals, and the Domestic Security Alliance Council. The teams managed by the CSO are comprised of seasoned experts in cyber and IT security and possess appropriate experience to safeguard the company’s data, networks and systems, mitigate cyber risks and help prevent and combat cyber threats.
Cybersecurity Risk Process for Informing Management or Committees Responsible [Text Block]	PPL has established an Executive
Cybersecurity Risk Management Positions or Committees Responsible Report to Board [Flag]	true

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2024
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 2022. PPL has elected to separately report the cash flows of continuing and discontinued operations on the Statements of Cash Flows for 2022. 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 11 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. 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. See Notes 15 and 16 for additional information on derivatives. (PPL and PPL Electric) To meet their obligations as last resort providers of electricity supply 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.
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 price 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 applicable tariff price. 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.
Accounts Receivable	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.
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, LG&E and KU) 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 15 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 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. AFUDC is capitalized at LG&E and KU for certain projects as part of the construction cost of approved projects. LG&E and KU are generally provided a return on construction work in progress for other projects. 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. Depreciation 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 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, renew or extend terms of an intangible asset are capitalized. 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) 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, 2024, PPL, for its reporting units, and individually, LG&E and KU, elected to perform the qualitative step zero evaluation of goodwill. These evaluations considered the excess of fair value over the carrying value of each reporting unit that was calculated during step one of the quantitative impairment tests performed in the fourth quarter of 2022, and the relevant events and circumstances that occurred since those tests were performed including: • current year financial performance versus the prior year, • changes in planned capital expenditures, • the consistency of forecasted free cash flows, • earnings quality and sustainability, • changes in market participant discount rates, • changes in long-term growth rates, • changes in PPL's market capitalization, and • the overall economic and regulatory environments in which these regulated entities operate.
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 18 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 and its subsidiaries, excluding RIE, use 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. RIE uses the standard amortization method under GAAP for recognition of gains and losses for its defined benefit pension plan. See Note 7 for a discussion of the regulatory treatment of defined benefit costs and Note 10 for a discussion of defined benefits. Stock-Based Compensation (PPL)
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 uncertain 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 amount of 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, 2024, 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. With respect to acquired renewable tax credits, pursuant to the IRA, any benefit is recognized in the period the credits can be utilized. 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)
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: 2024 PPL PPL Electric LG&E KU Fuel $ 153 $ — $ 64 $ 89 Natural gas stored underground 49 — 29 — Materials and supplies 309 104 64 84 Total $ 511 $ 104 $ 157 $ 173 2023 PPL PPL Electric LG&E KU Fuel $ 144 $ — $ 50 $ 94 Natural gas stored underground 58 — 34 — Materials and supplies 303 99 59 91 Total $ 505 $ 99 $ 143 $ 185
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 12 for further discussion of guarantees.
Treasury Stock	New Accounting Guidance Adopted (All Registrants) Improvements to Reportable Segment Disclosures Effective December 31, 2024, the Registrants retrospectively adopted accounting guidance to improve segment disclosures. The guidance requires enhanced disclosures about significant segment expenses. The standard also requires public entities to disclose the title and position of the Chief Operating Decision Maker (CODM) and explain how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources. Certain segment-related disclosures that previously were required only on an annual basis will be required to be disclosed in interim periods. In addition, public entities that have a single reportable segment are now required to provide segment disclosures. The adoption of this guidance resulted in the Registrants including the required additional disclosures within the notes to the financial statements. See Note 2 for additional information.
Emission Credits or Allowances, Policy	Renewable Energy Standard Obligation Purchased Renewable Energy Certificates (RECs) are stated at cost and are used to measure compliance with state renewable energy standards. RECs support new renewable generation standards and are held primarily to be utilized in fulfillment of RIE’s and PPL Electric's compliance obligations.
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 of electricity supply 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.
Compensation and Benefits	Stock-Based Compensation (PPL)
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 18 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 18 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, 2024
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, 2024
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. 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. See Notes 15 and 16 for additional information on derivatives. (PPL and PPL Electric) To meet their obligations as last resort providers of electricity supply 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.
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, 2024
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: 2024 2023 2022 PPL $ 20 $ 12 $ 7 PPL Electric 9 7 5 LG&E 3 1 — KU 4 1 —
Weighted-average Rates of Depreciation	Following are the weighted-average annual rates of depreciation, for regulated utility plant, for the years ended December 31: 2024 2023 2022 PPL 3.20 % 3.26 % 3.21 % PPL Electric 2.52 % 2.62 % 2.75 % LG&E 4.02 % 4.00 % 4.16 % KU 3.86 % 3.95 % 4.01 %
Schedule of Utility Inventory	"Fuel, materials and supplies" on the Balance Sheets consisted of the following at December 31: 2024 PPL PPL Electric LG&E KU Fuel $ 153 $ — $ 64 $ 89 Natural gas stored underground 49 — 29 — Materials and supplies 309 104 64 84 Total $ 511 $ 104 $ 157 $ 173 2023 PPL PPL Electric LG&E KU Fuel $ 144 $ — $ 50 $ 94 Natural gas stored underground 58 — 34 — Materials and supplies 303 99 59 91 Total $ 505 $ 99 $ 143 $ 185
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 (a) Balance at PPL 2024 $ 130 $ 109 $ 85 $ 154 (c) 2023 95 87 52 130 (c) 2022 69 78 52 95 (c) PPL Electric 2024 $ 50 $ 56 $ 65 $ 41 (b) 2023 33 52 35 50 (b) 2022 35 27 29 33 (b) LG&E 2024 $ 6 $ 4 $ 7 $ 3 2023 4 4 2 6 2022 3 6 5 4 Additions Balance at Charged to Income Deductions (a) Balance at KU 2024 $ 2 $ 4 $ 4 $ 2 2023 3 3 4 2 2022 3 6 6 3 (a) Primarily related to uncollectible accounts written off. (b) Includes $2 million, $3 million and $3 million related to other accounts receivable at December 31, 2024, 2023 and 2022. (c)
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: 2024 2023 2022 PPL $ 20 $ 12 $ 7 PPL Electric 9 7 5 LG&E 3 1 — KU 4 1 —
Intercompany tax receivables (payables)	At December 31, the following intercompany tax receivables (payables) were recorded: 2024 2023 PPL Electric $ (2) $ (21) LG&E (2) (5) KU (5) (3)
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: 2024 2023 PPL Electric $ (2) $ (21) LG&E (2) (5) KU (5) (3)
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: 2024 2023 PPL Electric $ (2) $ (21) LG&E (2) (5) KU (5) (3)

Segment and Related Informati_2

Segment and Related Information (Tables)	12 Months Ended
	Dec. 31, 2024
Segment Reporting [Abstract]
Segment and Related Information	The tables below provide information about PPL’s segments and include the reconciliation to consolidated net income for the year ended December 31, 2024: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Operating Revenues from external customers (a) $ 3,562 $ 2,876 $ 2,024 $ 8,462 Reconciliation of revenue Corporate and other revenues — Total consolidated revenues $ 8,462 Less: Fuel 783 — — 783 Energy Purchases 176 721 782 1,679 Operation and maintenance 803 705 731 2,239 Depreciation 710 401 165 1,276 Taxes, other than income 99 131 144 374 Other (income) expense - net (29) (78) (24) (131) Interest expense 240 246 95 581 Income taxes 160 176 22 358 Segment net income $ 620 $ 574 $ 109 $ 1,303 Reconciliation of segment profit or loss to consolidated net income Corporate and other net loss (415) Net Income $ 888 (a) See Note 1 and Note 3 for additional information on Operating Revenues. Other information for the segments and reconciliation to PPL's Consolidated results for the year ended December 31, 2024 are as follows: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Segments Corporate and Other Consolidated Total Other Segment Disclosures Amortization (a) $ 24 $ 45 $ 1 $ 70 $ 8 $ 78 Deferred income taxes and investment tax credits (b) 2 129 38 169 27 196 Expenditures for long lived assets 1,088 1,229 495 2,812 (7) 2,805 (a) 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. (b) Represents a non-cash expense item that is also included in "Income Taxes." The tables below provide information about PPL’s segments and include the reconciliation to consolidated net income for the year ended December 31, 2023: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Operating Revenues from external customers (a) $ 3,452 $ 3,008 $ 1,851 $ 8,311 Reconciliation of revenue Corporate and other revenues 1 Total consolidated revenues $ 8,312 Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Less: Fuel 733 — — 733 Energy Purchases 192 992 658 1,842 Operation and maintenance 826 605 705 2,136 Depreciation 696 397 156 1,249 Taxes, other than income 93 143 156 392 Other (income) expense - net (12) (39) (19) (70) Interest expense 235 223 83 541 Income taxes 137 168 16 321 Segment net income $ 552 $ 519 $ 96 $ 1,167 Reconciliation of segment profit or loss to consolidated net income Corporate and other net loss (427) Net Income $ 740 (a) See Note 1 and Note 3 for additional information on Operating Revenues. Other information for the segments and reconciliation to PPL's Consolidated results for the year ended December 31, 2023 are as follows: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Segments Corporate and Other Consolidated Total Other Segment Disclosures Amortization (a) $ 33 $ 41 $ 1 $ 75 $ 6 $ 81 Deferred income taxes and investment tax credits (b) (17) 46 48 77 245 322 Expenditures for long lived assets 950 956 454 2,360 30 2,390 (a) 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. (b) Represents a non-cash expense item that is also included in "Income Taxes." The tables below provide information about PPL’s segments and include the reconciliation to consolidated net income for the year ended December 31, 2022: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Operating Revenues from external customers (a) $ 3,811 $ 3,030 $ 1,038 $ 7,879 Reconciliation of revenue Corporate and other revenues 23 Total consolidated revenues $ 7,902 Less: Fuel 931 — — 931 Energy Purchases 273 1,048 365 1,686 Operation and maintenance 959 605 531 2,095 Depreciation 685 393 92 1,170 Taxes, other than income 92 149 92 333 Other (income) expense - net (12) (35) (23) (70) Interest expense 205 171 39 415 Income taxes 129 174 (14) 289 Segment net income $ 549 $ 525 $ (44) $ 1,030 Reconciliation of segment profit or loss to consolidated net income Corporate and other net loss (316) Income from discontinued operations (Note 9) 42 Net Income $ 756 (a) See Note 1 and Note 3 for additional information on Operating Revenues. Other information for the segments and reconciliation to PPL's Consolidated results for the year ended December 31, 2022 are as follows: Kentucky Regulated Pennsylvania Regulated Rhode Island Regulated Total Segments Corporate and Other Consolidated Total Other Segment Disclosures Amortization (a) $ 23 $ 22 $ 2 $ 47 $ 5 $ 52 Deferred income taxes and investment tax credits (b) 6 91 39 136 43 179 Expenditures for long lived assets 917 889 268 2,074 84 2,158 (a) 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. (b) Represents a non-cash expense item that is also included in "Income Taxes." The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated results as of: As of December 31, 2024 2023 Total Assets Kentucky Regulated $ 17,626 $ 17,029 Pennsylvania Regulated 15,475 14,294 Rhode Island Regulated 7,055 6,515 Corporate and Other (a) 913 1,398 Total $ 41,069 $ 39,236 (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, 2024
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: 2024 PPL PPL Electric LG&E KU Operating Revenues (a)(b) $ 8,462 $ 2,876 $ 1,648 $ 1,964 Revenues derived from: Alternative revenue programs (c) 5 (19) 13 16 Other (d) (23) (15) (4) (4) Revenues from Contracts with Customers $ 8,444 $ 2,842 $ 1,657 $ 1,976 2023 PPL PPL Electric LG&E KU Operating Revenues (a)(b) $ 8,312 $ 3,008 $ 1,613 $ 1,884 Revenues derived from: Alternative revenue programs (c) 1 5 (1) (5) Other (d) (23) (15) (4) (4) Revenues from Contracts with Customers $ 8,290 $ 2,998 $ 1,608 $ 1,875 2022 PPL PPL Electric LG&E KU Operating Revenues (a)(b) $ 7,902 $ 3,030 $ 1,798 $ 2,074 Revenues derived from: Alternative revenue programs (c) (92) (56) 9 5 Other (d) (24) (14) (6) (4) Revenues from Contracts with Customers $ 7,786 $ 2,960 $ 1,801 $ 2,075 (a) PPL includes $2,024 million, $1,851 million and $1,038 million for the twelve months ended December 31, 2024, 2023, and 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) PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL conformed the presentation of RIE's and the Rhode Island Regulated segment’s net metering charges with the presentation of the other segments, resulting in an increase in Operating Revenues and a corresponding increase in Energy purchases beginning on January 1, 2024. For the year ended December 31, 2024, net metering of $175 million was included in Energy purchases on PPL's Statement of Income. For the years ended December 31, 2023 and 2022, $146 million and $79 million of net metering was presented as a reduction of Operating Revenues on PPL's Statement of Income. (c) 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. (d) 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 2024 PA Regulated $ 1,502 $ 418 $ 47 $ 57 $ — $ — $ 818 $ 2,842 RI Regulated (c) 1,150 593 91 10 — — 176 2,020 KY Regulated 1,510 1,028 635 323 23 63 — 3,582 Total PPL $ 4,162 $ 2,039 $ 773 $ 390 $ 23 $ 63 $ 994 $ 8,444 Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers 2023 PA Regulated $ 1,649 $ 444 $ 55 $ 54 $ — $ — $ 796 $ 2,998 RI Regulated 640 228 20 793 — — 170 1,851 KY Regulated 1,458 1,001 637 272 22 50 — 3,440 Corp and Other — — — 1 — — — 1 Total PPL $ 3,747 $ 1,673 $ 712 $ 1,120 $ 22 $ 50 $ 966 $ 8,290 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 PPL Electric 2024 $ 1,502 $ 418 $ 47 $ 57 $ — $ — $ 818 $ 2,842 2023 $ 1,649 $ 444 $ 55 $ 54 $ — $ — $ 796 $ 2,998 2022 $ 1,647 $ 491 $ 85 $ 54 $ — $ — $ 683 $ 2,960 LG&E 2024 $ 754 $ 518 $ 188 $ 147 $ — $ 50 $ — $ 1,657 2023 $ 751 $ 517 $ 189 $ 104 $ — $ 47 $ — $ 1,608 2022 $ 835 $ 551 $ 199 $ 141 $ — $ 75 $ — $ 1,801 KU 2024 $ 756 $ 510 $ 447 $ 176 $ 23 $ 64 $ — $ 1,976 2023 $ 707 $ 484 $ 448 $ 168 $ 22 $ 46 $ — $ 1,875 2022 $ 802 $ 517 $ 463 $ 182 $ 28 $ 83 $ — $ 2,075 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. For the years ended December 31, 2023 and 2022, the Rhode Island Regulated segment primarily includes open access tariff revenues, which are calculated on combined customer classes. (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. (c) PPL's transition services agreement associated with the RIE acquisition ended in the third quarter of 2024. In conjunction with the completion of the agreement, PPL disaggregated the 2024 revenues of the Rhode Island Regulated segment in a manner consistent with that of its other segments. This resulted in certain customer revenues for the Rhode Island Regulated segment, which were previously presented in the "Other" category, being presented in the "Residential", "Commercial" or "Industrial" customer classes beginning on January 1, 2024. Applying the previous methodology to 2024 revenues would result in $469 million of Residential, $372 million of Commercial and $88 million of Industrial for the Rhode Island Regulated segment being presented as "Other" for the year ended December 31, 2024.
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: 2024 2023 2022 PPL(a) $ 103 $ 79 $ 70 PPL Electric 52 47 21 LG&E 4 4 6 KU 4 2 6
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, 2024 $ 39 $ 28 $ 5 $ 6 Contract liabilities as of December 31, 2023 43 29 6 7 Revenue recognized during the year ended December 31, 2024 that was included in the contract liability balance at December 31, 2023 26 12 6 7 Contract liabilities as of December 31, 2023 $ 43 $ 29 $ 6 $ 7 Contract liabilities as of December 31, 2022 34 23 5 6 Revenue recognized during the year ended December 31, 2023 that was included in the contract liability balance at December 31, 2022 21 10 5 6 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

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2024
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: 2024 2023 2022 Income (Numerator) Income from continuing operations after income taxes $ 888 $ 740 $ 714 Less amounts allocated to participating securities 2 1 1 Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted $ 886 $ 739 $ 713 Income from discontinued operations (net of income taxes) available to PPL common shareowners - Basic and Diluted $ — $ — $ 42 Net income attributable to PPL $ 888 $ 740 756 Less amounts allocated to participating securities 2 1 1 Net income available to PPL common shareowners - Basic and Diluted $ 886 $ 739 $ 755 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,756 737,036 736,027 Add: Dilutive share-based payment awards (a) 2,097 1,130 875 Weighted-average shares - Diluted EPS 739,853 738,166 736,902 Basic EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 1.20 $ 1.00 $ 0.97 Income from discontinued operations (net of income taxes) — — 0.06 Net Income available to PPL common shareowners $ 1.20 $ 1.00 $ 1.03 Diluted EPS Available to PPL common shareowners: Income from continuing operations after income taxes $ 1.20 $ 1.00 $ 0.96 Income from discontinued operations (net of income taxes) — — 0.06 Net Income available to PPL common shareowners $ 1.20 $ 1.00 $ 1.02 (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): 2024 2023 DRIP 202 —
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: 2024 2023 2022 Stock-based compensation awards — 243 93

Income and Other Taxes (Tables)

Income and Other Taxes (Tables)	12 Months Ended
	Dec. 31, 2024
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: 2024 2023 Deferred Tax Assets Deferred investment tax credits 28 28 Regulatory liabilities 133 123 Income taxes due to customers 418 436 Accrued pension and postretirement costs 112 101 State loss carryforwards 224 253 Federal and state tax credit carryforwards 24 67 Internal Revenue Code Section 197 intangibles 72 78 Contributions in aid of construction 163 149 Bad debt 37 28 Other 114 111 Valuation allowances (224) (245) Total deferred tax assets 1,101 1,129 Deferred Tax Liabilities Plant - net 3,898 3,749 Regulatory assets 432 376 Prepayments 39 47 Goodwill 38 22 Other 38 30 Total deferred tax liabilities 4,445 4,224 Net deferred tax liability $ 3,344 $ 3,095
Summary of Operating Loss Carryforwards and Tax Credit Carryforwards	At December 31, 2024, 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 $ 5,011 $ 224 $ (221) 2025-2044 State charitable contributions 10 1 (1) 2025-2029 Foreign capital loss 8 2 (2) Indefinite Gross Deferred Tax Asset Valuation Allowance Expiration Credit carryforwards Federal - other 14 — 2044 State recycling credit 8 — 2028 State - other 2 — 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 2024 $ 245 $ 3 $ 1 $ 25 (a) $ 224 2023 213 54 (b) — 22 (c) 245 2022 462 10 — 259 (d) 213 (a) In 2024, PPL recorded a $23 million decrease in a valuation allowance on a 2004 state net operating loss carryforward that expired in 2024. (b) PPL has a Pennsylvania net operating loss fully offset by a valuation allowance. In 2023, PPL adjusted the net operating loss and related valuation allowance to be recorded at the current estimate of the applicable rate at which each portion of the net operating loss that will expire and be written off as the rate is reduced annually by one half a percentage point until the rate reaches to 4.99% in 2031. (c) In 2023, PPL recorded a $22 million decrease in a valuation allowance on a 2003 state net operating loss carryforward that expired in 2023. (d)
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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal (a) $ 23 $ (175) $ (2) Current - State 9 37 24 Total Current Expense (Benefit) 32 (138) 22 Deferred - Federal (a) 137 286 122 Deferred - State 64 48 68 Total Deferred Expense (Benefit), excluding operating loss carryforwards 201 334 190 Amortization of investment tax credit (3) (3) (3) Tax expense (benefit) of operating loss carryforwards Deferred - Federal 1 3 2 Deferred - State (3) (12) (10) Total Tax Expense (Benefit) of Operating Loss Carryforwards (2) (9) (8) Total income tax expense (benefit) $ 228 $ 184 $ 201 Total income tax expense (benefit) - Federal $ 158 $ 111 $ 119 Total income tax expense (benefit) - State 70 73 82 Total income tax expense (benefit) $ 228 $ 184 $ 201 (a) In 2023, PPL purchased approximately $300 million of renewable tax credits and recorded a current tax benefit and a deferred tax expense for utilization of approximately $250 million of the credits in 2023 and prior years, per the three-year carry-back rule. In the table above, the following income tax expense (benefit) are excluded from income taxes: 2024 2023 2022 Discontinued operations $ — $ — $ (42) Other comprehensive income (8) (14) 11 Valuation allowance recorded to other comprehensive income — (1) — Total $ (8) $ (15) $ (31)
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: 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 234 $ 194 $ 192 State income taxes, net of federal income tax benefit 65 58 68 Valuation allowance adjustments (a) 2 12 9 Income tax credits (b) (8) (22) (3) Utility rate-making tax adjustments (c) (21) (10) (8) Amortization of excess deferred federal and state income taxes (45) (48) (54) Other 1 — (3) Total increase (decrease) (6) (10) 9 Total income tax expense (benefit) $ 228 $ 184 $ 201 Effective income tax rate 20.4% 19.9% 22.0% (a) In 2024, 2023, and 2022, PPL recorded deferred income tax expense of $3 million, $11 million and $5 million for valuation allowances primarily related to increased Pennsylvania net operating loss carryforwards expected to be unutilized. (b) In 2023, PPL purchased approximately $300 million of renewable tax credits and recorded a current tax benefit and a deferred tax expense for utilization of approximately $250 million of the credits in 2023 and prior years, per the three-year carry-back rule. (c) Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL utilities and flow through tax impacts. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.
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: 2024 2023 2022 Taxes, other than income State gross earnings and state gross receipts $ 167 $ 195 $ 175 Property and other 207 197 157 Total $ 374 $ 392 $ 332
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: 2024 2023 Deferred Tax Assets Accrued pension and postretirement costs $ 36 $ 30 Contributions in aid of construction 120 105 Regulatory liabilities 40 43 Income taxes due to customers 184 191 Other 22 27 Total deferred tax assets 402 396 Deferred Tax Liabilities Electric utility plant - net 1,934 1,810 Regulatory assets 160 119 Prepayments 30 36 Other 4 4 Total deferred tax liabilities 2,128 1,969 Net deferred tax liability $ 1,726 $ 1,573
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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal $ 44 $ 91 $ 63 Current - State 4 31 20 Total Current Expense (Benefit) 48 122 83 Deferred - Federal 86 28 60 Deferred - State 42 18 31 Total Deferred Expense (Benefit), excluding operating loss carryforwards 128 46 91 Total income tax expense (benefit) $ 176 $ 168 $ 174 Total income tax expense (benefit) - Federal $ 130 $ 119 $ 123 Total income tax expense (benefit) - State 46 49 51 Total income tax expense (benefit) $ 176 $ 168 $ 174
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: 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 158 $ 144 $ 147 Increase (decrease) due to: State income taxes, net of federal income tax benefit 47 49 54 Utility rate-making tax adjustments (a) (16) (9) (7) Amortization of excess deferred federal income taxes (b) (10) (11) (12) State income tax rate change (c) — — (9) Other (3) (5) 1 Total increase (decrease) 18 24 27 Total income tax expense (benefit) $ 176 $ 168 $ 174 Effective income tax rate 23.5% 24.5% 24.9% (a) Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL utilities and flow through tax impacts. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. (b) In 2024, 2023, and 2022, 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. (c) 2022 includes a deferred tax benefit of $9 million due to the corporate net income tax rate reduction.
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: 2024 2023 2022 Taxes, other than income State gross receipts $ 122 $ 136 $ 142 Property and other 9 7 7 Total $ 131 $ 143 $ 149
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: 2024 2023 Deferred Tax Assets Contributions in aid of construction $ 18 $ 18 Regulatory liabilities 18 19 Accrued pension and postretirement costs 4 3 Deferred investment tax credits 7 8 Income taxes due to customers 110 115 State tax credit carryforwards 6 8 Lease liabilities 4 4 Valuation allowances (6) (8) Other 6 8 Total deferred tax assets 167 175 Deferred Tax Liabilities Plant - net 875 877 Regulatory assets 88 67 Lease right-of-use assets 4 3 Other 3 4 Total deferred tax liabilities 970 951 Net deferred tax liability $ 803 $ 776
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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal $ 60 $ 70 $ 60 Current - State 11 13 9 Total Current Expense (Benefit) 71 83 69 Deferred - Federal 1 (15) (10) Deferred - State 6 2 5 Total Deferred Expense (Benefit) 7 (13) (5) Amortization of investment tax credit - Federal (1) (1) (1) Total income tax expense (benefit) $ 77 $ 69 $ 63 Total income tax expense (benefit) - Federal $ 60 $ 54 $ 49 Total income tax expense (benefit) - State 17 15 14 Total income tax expense (benefit) $ 77 $ 69 $ 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: 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 79 $ 70 $ 70 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 13 13 Amortization of excess deferred federal and state income taxes (13) (13) (18) Other (3) (1) (2) Total increase (decrease) (2) (1) (7) Total income tax expense (benefit) $ 77 $ 69 $ 63 Effective income tax rate 20.6% 20.6% 18.8%
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: 2024 2023 2022 Taxes, other than income Property and other $ 49 $ 48 $ 48 Total $ 49 $ 48 $ 48
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: 2024 2023 Deferred Tax Assets Contributions in aid of construction $ 12 $ 10 Regulatory liabilities 29 23 Deferred investment tax credits 20 21 Income taxes due to customers 124 131 State tax credit carryforwards 4 4 Lease liabilities 6 5 Valuation allowances (2) (2) Other 4 5 Total deferred tax assets 197 197 Deferred Tax Liabilities Plant - net 1,053 1,045 Regulatory assets 55 50 Pension and postretirement costs 6 7 Lease right-of-use assets 6 5 Other 1 2 Total deferred tax liabilities 1,121 1,109 Net deferred tax liability $ 924 $ 912
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: 2024 2023 2022 Income Tax Expense (Benefit) Current - Federal $ 87 $ 73 $ 63 Current - State 17 13 11 Total Current Expense (Benefit) 104 86 74 Deferred - Federal (15) (11) (3) Deferred - State 2 4 7 Total Deferred Expense (Benefit) (13) (7) 4 Amortization of investment tax credit - Federal (2) (2) (2) Total income tax expense (benefit) $ 89 $ 77 $ 76 Total income tax expense (benefit) - Federal $ 70 $ 60 $ 58 Total income tax expense (benefit) - State 19 17 18 Total income tax expense (benefit) $ 89 $ 77 $ 76
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: 2024 2023 2022 Reconciliation of Income Tax Expense (Benefit) Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 93 $ 82 $ 84 Increase (decrease) due to: State income taxes, net of federal income tax benefit 16 15 16 Amortization of investment tax credit (2) (2) (2) Amortization of excess deferred federal and state income taxes (17) (17) (21) Other (1) (1) (1) Total decrease (4) (5) (8) Total income tax expense (benefit) $ 89 $ 77 $ 76 Effective income tax rate 20.0% 19.8% 19.1%
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: 2024 2023 2022 Taxes, other than income Property and other $ 49 $ 45 $ 45 Total $ 49 $ 45 $ 45

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	12 Months Ended
	Dec. 31, 2024
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 LG&E KU 2024 2023 2024 2023 2024 2023 2024 2023 Current Regulatory Assets: Rate adjustment mechanism $ 95 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 14 14 — — — — — — Derivative instruments 3 51 — — — — — — Smart meter rider 7 6 7 6 — — — — Storm damage expense rider 68 12 68 12 — — — — Transmission service charge 44 43 27 31 — — — — Transmission formula rate 14 5 2 — — — — — ISR deferral 22 11 — — — — — — Gas line tracker 4 — — — 4 — — — TCJA customer refund and recovery 21 — 21 — — — — — DSIC 8 7 8 7 — — — — Other 20 26 — 1 4 7 1 3 Total current regulatory assets $ 320 $ 293 $ 133 $ 57 $ 8 $ 7 $ 1 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 967 $ 887 $ 473 $ 417 $ 226 $ 217 $ 149 $ 136 Plant outage cost 30 38 — — 7 10 23 28 Net metering 147 112 — — — — — — Environmental cost recovery 96 99 — — — — — — Storm costs 113 97 22 — 20 15 29 14 Unamortized loss on debt 20 22 3 3 9 10 6 7 Interest rate swaps 4 7 — — 4 7 — — Terminated interest rate swaps 53 58 — — 31 34 22 24 Accumulated cost of removal of utility plant 173 178 173 178 — — — — AROs 280 289 — — 75 76 205 213 Retired asset recovery 83 — — — 83 — — — Derivative instruments 1 8 — — — — — — Gas line inspections 24 21 — — 22 19 2 2 Advanced metering infrastructure 28 15 — — 14 7 14 8 Other 41 43 2 — — — 8 7 Total noncurrent regulatory assets $ 2,060 $ 1,874 $ 673 $ 598 $ 491 $ 395 $ 458 $ 439 PPL PPL Electric LG&E KU 2024 2023 2024 2023 2024 2023 2024 2023 Current Regulatory Liabilities: Generation supply charge $ 52 $ 51 $ 52 $ 51 $ — $ — $ — $ — TCJA customer refund and recovery — 5 — 5 — — — — Act 129 compliance rider 2 15 2 15 — — — — Transmission formula rate 1 21 — 18 — — — — Rate adjustment mechanism 71 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — DSM 17 1 — — 7 — 10 1 Environmental cost recovery 12 — — — 6 — 6 — Other 43 22 3 2 1 1 6 — Total current regulatory liabilities $ 223 $ 225 $ 57 $ 91 $ 14 $ 16 $ 22 $ 1 PPL PPL Electric LG&E KU 2024 2023 2024 2023 2024 2023 2024 2023 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,022 $ 996 $ — $ — $ 314 $ 306 $ 408 $ 399 Power purchase agreement - OVEC 10 19 — — 7 13 3 6 Net deferred taxes 1,899 1,977 739 763 439 459 498 523 Defined benefit plans 294 252 100 73 24 20 65 59 Terminated interest rate swaps 54 57 — — 27 29 27 28 Energy efficiency 16 5 — — — — — — Other 40 34 — — 4 — 8 3 Total noncurrent regulatory liabilities $ 3,335 $ 3,340 $ 839 $ 836 $ 815 $ 827 $ 1,009 $ 1,018 `

Financing Activities (Tables)

Financing Activities (Tables)	12 Months Ended
	Dec. 31, 2024
Debt Disclosure [Line Items]
Credit Facilities in Place at Period End	The following credit facilities were in place at: December 31, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of PPL PPL Capital Funding Syndicated Credit Facility (a) (b) (c) Dec 2028 $ 1,250 $ — $ 138 $ 1,112 $ — $ 390 Bilateral Credit Facility (a) (b) Feb 2025 100 — — 100 — — Bilateral Credit Facility (a) (b) Feb 2025 100 — 15 85 — 13 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 153 $ 1,297 $ — $ 403 PPL Electric Syndicated Credit Facility (a) (b) Dec 2028 650 — 1 649 — 511 Total PPL Electric Credit Facilities $ 650 $ — $ 1 $ 649 $ — $ 511 December 31, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Capacity Borrowed Letters of LG&E Syndicated Credit Facility (a) (b) Dec 2028 500 — 25 475 — — Total LG&E Credit Facilities $ 500 $ — $ 25 $ 475 $ — $ — KU Syndicated Credit Facility (a) (b) Dec 2028 400 — 140 260 — 93 Total KU Credit Facilities $ 400 $ — $ 140 $ 260 $ — $ 93 (a) Each company pays customary fees under its respective facility and borrowings generally bear interest at applicable secured overnight financing rates or base 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, RIE, 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 February 2025 be increased by up to $30 million and that the capacity of its syndicated credit facility be increased by up to $400 million. PPL Electric, LG&E and KU may each request up to a $250 million increase in its syndicated credit facility's capacity, subject to regulatory approval of the increased capacity. Participation in any such increase is at the sole discretion of each lender. (c) Includes a $250 million borrowing sublimit for RIE and a $1 billion sublimit for PPL Capital Funding at December 31, 2024 and 2023. At December 31, 2024, PPL Capital Funding had $138 million of commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million of commercial paper outstanding and RIE had $25 million of commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL. (d)
Commercial paper	The following commercial paper programs were in place at: December 31, 2024 December 31, 2023 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) 4.76% $ 1,350 $ 138 $ 1,212 5.66% $ 365 RIE (b) 250 — 250 5.72% 25 PPL Electric 650 — 650 5.67% 510 LG&E 4.72% 500 25 475 — KU 4.71% 400 140 260 5.64% 93 Total $ 3,150 $ 303 $ 2,847 $ 993 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility, which, at December 31, 2024, had a total capacity of $1.25 billion and under which they are both borrowers. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. The PPL Capital Funding syndicated credit facility includes a borrowing sublimit for RIE, which at December 31, 2024 was set at $250 million with the remaining $1 billion allocated to PPL Capital Funding. RIE's obligations under the facility are not guaranteed by PPL. The sublimits of each borrower may be decreased or increased at the borrowers’ option up to a prescribed amount such that all borrowings under the syndicated credit facility cannot exceed the size of the credit facility of $1.25 billion. (c) 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) 2024 2023 PPL Senior Unsecured Notes 4.34 % 2026 - 2047 $ 4,316 $ 3,066 Senior Secured Notes/First Mortgage Bonds (a) (b) (c) 4.38 % 2025 - 2053 10,878 10,229 Exchangeable Senior Unsecured Notes 2.88 % 2028 1,000 1,000 Junior Subordinated Notes 7.25 % 2067 480 480 Total Long-term Debt before adjustments 16,674 14,775 Unamortized premium and (discount), net (57) (55) Unamortized debt issuance costs (114) (108) Total Long-term Debt 16,503 14,612 Less current portion of Long-term Debt 551 1 Total Long-term Debt, noncurrent $ 15,952 $ 14,611 PPL Electric Senior Secured Notes/First Mortgage Bonds (a) (b) 4.64 % 2027 - 2053 $ 5,299 $ 4,649 Total Long-term Debt Before Adjustments 5,299 4,649 Unamortized discount (42) (42) Unamortized debt issuance costs (43) (40) Total Long-term Debt 5,214 4,567 Less current portion of Long-term Debt — — Total Long-term Debt, noncurrent $ 5,214 $ 4,567 December 31, Weighted-Average Maturities (d) 2024 2023 LG&E Senior Secured Notes/First Mortgage Bonds (a) (c) 4.01 % 2025 - 2049 $ 2,489 $ 2,489 Total Long-term Debt Before Adjustments 2,489 2,489 Unamortized discount (4) (4) Unamortized debt issuance costs (14) (16) Total Long-term Debt 2,471 2,469 Less current portion of Long-term Debt 300 — Total Long-term Debt, noncurrent $ 2,171 $ 2,469 KU Senior Secured Notes/First Mortgage Bonds (a) (c) 4.22 % 2025 - 2050 $ 3,089 $ 3,089 Total Long-term Debt Before Adjustments 3,089 3,089 Unamortized premium 4 5 Unamortized discount (8) (9) Unamortized debt issuance costs (19) (21) Total Long-term Debt 3,066 3,064 Less current portion of Long-term Debt 250 — Total Long-term Debt, noncurrent $ 2,816 $ 3,064 (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 $13.3 billion and $12.4 billion at December 31, 2024 and 2023. 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 $6.0 billion and $5.9 billion at December 31, 2024 and 2023. 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 $7.5 billion and $7.3 billion at December 31, 2024 and 2023. (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 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. (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 SOFR index rate. At December 31, 2024, the aggregate tax-exempt revenue bonds issued on behalf of LG&E and KU that were in a term rate mode totaled $894 million for PPL, comprised of $538 million and $356 million for LG&E and KU. At December 31, 2024, 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, 2024.
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 2025 through 2029 and thereafter are as follows: PPL PPL LG&E KU 2025 $ 551 $ — $ 300 $ 250 2026 904 — 90 164 2027 428 108 260 60 2028 1,350 — — — 2029 116 116 — — Thereafter 13,325 5,075 1,839 2,615 Total $ 16,674 $ 5,299 $ 2,489 $ 3,089

Acquisitions, Development and_2

Acquisitions, Development and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Acquisitions, Development and Divestitures [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The table below shows the 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. Final Purchase Price Allocation 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 Noncurrent Assets Property, Plant and Equipment, net 3,992 Regulatory Assets 393 Goodwill 1,585 Other Noncurrent Assets 164 Total Noncurrent Assets 6,134 Total Assets $ 6,776 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 142 Noncurrent Liabilities 2,281 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 Operating Revenues and Net Income (Loss) attributable to PPL, including RIE, as if the Acquisition had occurred prior to January 1, 2022 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 (a) Net Income (Loss) includes expenses of $98 million (pre-tax) related to commitments made as a condition of the Acquisition.
Narragansett Electric
Acquisitions, Development and Divestitures [Line Items]
Schedule of Fair Value Consideration Paid for Business Acquisition	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

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2024
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' leases for the years ended December 31: 2024 2023 2022 PPL Lease cost: Finance lease cost: Amortization of right-of-use assets $ — 1 $ — Interest on lease liabilities — — — Operating lease cost — 26 20 Short-term lease cost — 6 6 Total lease cost $ — $ 33 $ 26 LG&E Lease cost: Operating lease cost $ 5 $ 6 Short-term lease cost 1 1 Total lease cost $ — $ 6 $ 7 KU Lease cost: Operating lease cost $ 10 $ 9 Short-term lease cost 1 2 Total lease cost $ — $ 11 $ 11 The following table provides other key information related to the Registrants' leases at December 31: 2024 2023 2022 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from finance leases $ — — $ — Operating cash flows from operating leases — 25 26 Financing cash flows from finance leases — 1 — Right-of-use asset obtained in exchange for new finance lease liabilities — 7 — Right-of-use asset obtained in exchange for new operating lease liabilities — 47 15 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 8 Right-of-use asset obtained in exchange for new operating lease liabilities 6 4 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9 $ 12 Right-of-use asset obtained in exchange for new operating lease liabilities 10 5
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2024. PPL LG&E KU Operating leases Finance leases Operating leases Operating leases 2024 $ — $ — 2025 — — 2026 — — 2027 — — 2028 — — Thereafter — — Total $ — $ — $ — $ — Weighted-average discount rate Weighted-average remaining lease term (in years) Current lease liabilities (a) $ — $ — Non-current lease liabilities (a) — — Right-of-use assets (b) — — (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Operating lease right-of-use assets are included in "Other noncurrent assets" and finance lease right-of-use assets are included in "Property, Plant and Equipment" on the Balance Sheets.
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: 2024 2023 2022 PPL $ — 4 6 LG&E — — 2 KU — — —
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' leases for the years ended December 31: 2024 2023 2022 PPL Lease cost: Finance lease cost: Amortization of right-of-use assets $ — 1 $ — Interest on lease liabilities — — — Operating lease cost — 26 20 Short-term lease cost — 6 6 Total lease cost $ — $ 33 $ 26 LG&E Lease cost: Operating lease cost $ 5 $ 6 Short-term lease cost 1 1 Total lease cost $ — $ 6 $ 7 KU Lease cost: Operating lease cost $ 10 $ 9 Short-term lease cost 1 2 Total lease cost $ — $ 11 $ 11 The following table provides other key information related to the Registrants' leases at December 31: 2024 2023 2022 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from finance leases $ — — $ — Operating cash flows from operating leases — 25 26 Financing cash flows from finance leases — 1 — Right-of-use asset obtained in exchange for new finance lease liabilities — 7 — Right-of-use asset obtained in exchange for new operating lease liabilities — 47 15 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 8 Right-of-use asset obtained in exchange for new operating lease liabilities 6 4 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9 $ 12 Right-of-use asset obtained in exchange for new operating lease liabilities 10 5
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2024. PPL LG&E KU Operating leases Finance leases Operating leases Operating leases 2024 $ — $ — 2025 — — 2026 — — 2027 — — 2028 — — Thereafter — — Total $ — $ — $ — $ — Weighted-average discount rate Weighted-average remaining lease term (in years) Current lease liabilities (a) $ — $ — Non-current lease liabilities (a) — — Right-of-use assets (b) — — (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Operating lease right-of-use assets are included in "Other noncurrent assets" and finance lease right-of-use assets are included in "Property, Plant and Equipment" on the Balance Sheets.
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: 2024 2023 2022 PPL $ — 4 6 LG&E — — 2 KU — — —
Kentucky Utilities Co [Member]
Leases [Line Items]
Lease, Cost [Table Text Block]	The following table provides the components of lease cost for the Registrants' leases for the years ended December 31: 2024 2023 2022 PPL Lease cost: Finance lease cost: Amortization of right-of-use assets $ — 1 $ — Interest on lease liabilities — — — Operating lease cost — 26 20 Short-term lease cost — 6 6 Total lease cost $ — $ 33 $ 26 LG&E Lease cost: Operating lease cost $ 5 $ 6 Short-term lease cost 1 1 Total lease cost $ — $ 6 $ 7 KU Lease cost: Operating lease cost $ 10 $ 9 Short-term lease cost 1 2 Total lease cost $ — $ 11 $ 11 The following table provides other key information related to the Registrants' leases at December 31: 2024 2023 2022 PPL Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from finance leases $ — — $ — Operating cash flows from operating leases — 25 26 Financing cash flows from finance leases — 1 — Right-of-use asset obtained in exchange for new finance lease liabilities — 7 — Right-of-use asset obtained in exchange for new operating lease liabilities — 47 15 LG&E Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 6 $ 8 Right-of-use asset obtained in exchange for new operating lease liabilities 6 4 KU Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 9 $ 12 Right-of-use asset obtained in exchange for new operating lease liabilities 10 5
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table provides the total future minimum rental payments for leases, as well as a reconciliation of these undiscounted cash flows to the lease liabilities recognized on the Balance Sheets as of December 31, 2024. PPL LG&E KU Operating leases Finance leases Operating leases Operating leases 2024 $ — $ — 2025 — — 2026 — — 2027 — — 2028 — — Thereafter — — Total $ — $ — $ — $ — Weighted-average discount rate Weighted-average remaining lease term (in years) Current lease liabilities (a) $ — $ — Non-current lease liabilities (a) — — Right-of-use assets (b) — — (a) Current lease liabilities are included in "Other Current Liabilities" on the Balance Sheets. Non-current lease liabilities are included in "Other deferred credits and noncurrent liabilities" on the Balance Sheets. The difference between the total future minimum lease payments and the recorded lease liabilities is due to the impact of discounting. (b) Operating lease right-of-use assets are included in "Other noncurrent assets" and finance lease right-of-use assets are included in "Property, Plant and Equipment" on the Balance Sheets.
Lessor, Operating Lease, Payments to be Received, Maturity [Table Text Block]	for the years ended December 31: 2024 2023 2022 PPL $ — 4 6 LG&E — — 2 KU — — —

Retirement and Postemployment_2

Retirement and Postemployment Benefits (Tables)	12 Months Ended
	Dec. 31, 2024
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 2024 2023 2022 2024 2023 2022 Net periodic defined benefit costs (credits): Service cost $ 35 $ 34 $ 51 $ 6 $ 6 $ 7 Interest cost 183 188 144 29 30 20 Expected return on plan assets (299) (309) (276) (30) (30) (28) Amortization of: Prior service cost (credit) 3 6 8 1 1 1 Actuarial (gain) loss 10 2 51 (5) (5) (5) Net periodic defined benefit costs (credits) prior to settlements and termination benefits (68) (79) (22) 1 2 (5) Settlements (a) — — 23 — — — Net periodic defined benefit costs (credits) $ (68) $ (79) $ 1 $ 1 $ 2 $ (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) — — — Net (gain) loss 134 193 242 1 (6) — Prior service cost (credit) (13) 2 — — — — Amortization of: Prior service (cost) credit (3) (6) (8) (1) (1) (1) Actuarial gain (loss) (10) (2) (51) 5 5 5 Total recognized in OCI and regulatory assets/liabilities 108 187 193 5 (2) (45) Total recognized in net periodic defined benefit costs, OCI and regulatory assets/liabilities $ 40 $ 108 $ 194 $ 6 $ — $ (50) (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 2024 2023 2022 2024 2023 2022 OCI $ 25 $ 52 $ 142 $ 2 $ — $ 13 Regulatory assets/liabilities 83 135 51 3 (2) (58) Total recognized in OCI and $ 108 $ 187 $ 193 $ 5 $ (2) $ (45)
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 2024 2023 2024 2023 PPL Discount rate 5.93 % 5.52 % 5.91 % 5.54 % Rate of compensation increase 3.43 % 3.43 % 3.44 % 3.43 % 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 2024 2023 2022 2024 2023 2022 PPL Discount rate 5.52 % 5.52 % 3.35 % 5.54 % 5.54 % 3.54 % Rate of compensation increase 3.43 % 3.43 % 3.74 % 3.43 % 3.43 % 2.84 % Expected return on plan assets 8.25 % 8.25 % 7.25 % 7.28 % 7.38 % 6.52 % (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: 2024 2023 2022 PPL Health care cost trend rate assumed for next year – obligations 7.00 % 6.25 % 6.50 % – cost 6.25 % 6.50 % 6.25 % 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 2033 2029 2029 – cost 2029 2029 2027
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 2024 2023 2024 2023 Change in Benefit Obligation Benefit Obligation, beginning of period $ 3,454 $ 3,333 $ 538 $ 534 Service cost 35 34 6 6 Interest cost 183 188 29 30 Participant contributions — — 8 9 Plan amendments (13) 3 — — Actuarial (gain) loss (131) 179 (4) 18 Settlements — (3) — — Gross benefits paid (284) (280) (56) (59) Federal subsidy — — 2 — Benefit Obligation, end of period 3,244 3,454 523 538 Change in Plan Assets Plan assets at fair value, beginning of period 3,176 3,149 438 417 Actual return on plan assets 34 297 25 54 Employer contributions 10 13 14 16 Participant contributions — — 7 7 Transfer out (a) — — (13) — Settlements — (3) — — Gross benefits paid (284) (280) (54) (56) Plan assets at fair value, end of period 2,936 3,176 417 438 Funded Status, end of period $ (308) $ (278) $ (106) $ (100) Amounts recognized in the Balance Sheets consist of: Noncurrent asset $ 19 $ 7 $ 8 $ 10 Current liability (10) (10) (13) (14) Noncurrent liability (317) (275) (101) (96) Net amount recognized, end of period $ (308) $ (278) $ (106) $ (100) Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax) consist of: Prior service cost (credit) $ (6) $ 11 $ 9 $ 10 Net actuarial (gain) loss 1,164 1,017 (90) (96) Total $ 1,158 $ 1,028 $ (81) $ (86) Total accumulated benefit obligation for defined benefit pension plans $ 3,116 $ 3,312 (a) Transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to be used to pay medical claims of active bargaining unit employees. 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 2024 2023 2024 2023 AOCI $ 283 $ 235 $ 16 $ 14 Regulatory assets/liabilities 875 793 (97) (100) Total $ 1,158 $ 1,028 $ (81) $ (86)
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 2024 2023 Projected benefit obligation $ 2,719 $ 2,891 Fair value of plan assets 2,392 2,606 ABO in excess of plan assets 2024 2023 Accumulated benefit obligation $ 2,618 $ 1,773 Fair value of plan assets 2,392 1,594
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 2024 2024 2023 Target Asset Growth Portfolio 55 % 54 % 55 % Equity securities 30 % 31 % Debt securities (a) 13 % 12 % Alternative investments 12 % 11 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 35 % 36 % Derivatives (b) 8 % 7 % Liquidity Portfolio 2 % 3 % 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.
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, 2024 December 31, 2023 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 $ 212 $ 212 $ — $ — $ 226 $ 226 $ — $ — Equity securities: U.S. Equity 63 63 — — 36 36 — — U.S. Equity fund measured at NAV (a) 461 — — — 542 — — — International equity fund at NAV (a) 376 — — — 431 — — — Commingled debt measured at NAV (a) 461 — — — 528 — — — Debt securities: U.S. Treasury and U.S. government sponsored 150 149 1 — 159 159 — — Corporate 867 — 848 19 915 — 906 9 Other 13 — 13 — 14 — 13 1 Alternative investments: Real estate measured at NAV (a) 72 — — — 61 — — — Private equity measured at NAV (a) 114 — — — 105 — — — Private credit partnerships measured at NAV (a) 16 — — — 13 — — — Hedge funds measured at NAV (a) 181 — — — 192 — — — Derivatives (38) — (38) — 93 — 93 — PPL Services Corporation Master Trust assets, at 2,948 $ 424 $ 824 $ 19 3,315 $ 421 $ 1,012 $ 10 Receivables and payables, net (b) 102 (16) 401(h) accounts restricted for other (114) (124) Total PPL Services Corporation Master Trust $ 2,936 $ 3,175 (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, 2024 is as follows: Corporate Balance at beginning of period $ 10 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 7 Purchases, sales and settlements 4 Balance at end of period $ 19 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2023 is as follows: Corporate Balance at beginning of period $ 16 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 4 Purchases, sales and settlements (8) Balance at end of period $ 10
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 2024 2023 2024 Asset Class Equity securities 45 % 46 % 45 % Debt securities (a) 49 % 48 % 49 % Cash and cash equivalents (b) 6 % 6 % 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, 2024 December 31, 2023 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 $ — $ — $ 20 $ 20 $ — $ — Equity securities: Large-cap equity fund measure at NAV (a) 71 — — — 76 — — — Commingled debt fund measured at NAV (a) 78 — — — 84 — — — Global equity exchange-traded fund 70 70 — — 72 72 — — Long-term bond exchange-traded fund 74 74 — — 74 74 — — Total VEBA trust assets, at fair value 312 $ 163 $ — $ — 326 $ 166 $ — $ — Receivables and payables, net (b) (9) (12) 401(h) account assets 114 124 Total other postretirement benefit plan assets $ 417 $ 438 (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 2025 $ 304 $ 50 $ — 2026 297 49 — 2027 288 49 — 2028 282 48 — 2029 276 47 — 2030-2034 1,298 218 —
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: 2024 2023 2022 PPL $ 53 $ 48 $ 36 PPL Electric 9 8 6 LG&E 8 8 7 KU 6 6 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 2024 2024 2023 Target Asset Growth Portfolio 55 % 54 % 55 % Equity securities 30 % 31 % Debt securities (a) 13 % 12 % Alternative investments 12 % 11 % Immunizing Portfolio 43 % 43 % 43 % Debt securities (a) 35 % 36 % Derivatives (b) 8 % 7 % Liquidity Portfolio 2 % 3 % 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.
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, 2024 December 31, 2023 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 $ 212 $ 212 $ — $ — $ 226 $ 226 $ — $ — Equity securities: U.S. Equity 63 63 — — 36 36 — — U.S. Equity fund measured at NAV (a) 461 — — — 542 — — — International equity fund at NAV (a) 376 — — — 431 — — — Commingled debt measured at NAV (a) 461 — — — 528 — — — Debt securities: U.S. Treasury and U.S. government sponsored 150 149 1 — 159 159 — — Corporate 867 — 848 19 915 — 906 9 Other 13 — 13 — 14 — 13 1 Alternative investments: Real estate measured at NAV (a) 72 — — — 61 — — — Private equity measured at NAV (a) 114 — — — 105 — — — Private credit partnerships measured at NAV (a) 16 — — — 13 — — — Hedge funds measured at NAV (a) 181 — — — 192 — — — Derivatives (38) — (38) — 93 — 93 — PPL Services Corporation Master Trust assets, at 2,948 $ 424 $ 824 $ 19 3,315 $ 421 $ 1,012 $ 10 Receivables and payables, net (b) 102 (16) 401(h) accounts restricted for other (114) (124) Total PPL Services Corporation Master Trust $ 2,936 $ 3,175 (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, 2024 is as follows: Corporate Balance at beginning of period $ 10 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 7 Purchases, sales and settlements 4 Balance at end of period $ 19 A reconciliation of the Master Trust assets classified as Level 3 at December 31, 2023 is as follows: Corporate Balance at beginning of period $ 16 Actual return on plan assets: Relating to assets still held at the reporting date (2) Relating to assets sold during the period 4 Purchases, sales and settlements (8) Balance at end of period $ 10
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: 2024 2023 Pension $ (83) $ (65) Other postretirement benefits (60) (55)
Louisville Gas And Electric Co [Member]
Defined Benefit Plan Disclosure [Line Items]
Schedule of Funded Status of Defined Benefit Plans	Allocations to LG&E resulted in assets/(liabilities) at December 31 as follows: 2024 2023 Pension $ 29 $ 34 Other postretirement benefits (44) (44)
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. 2024 2023 Pension $ 46 $ 51 Other postretirement benefits (8) (9)

Jointly Owned Utility Facilitie

Jointly Owned Utility Facilities (Tables)	12 Months Ended
	Dec. 31, 2024
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2024 and 2023, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2024 Trimble County Unit 1 75.00 % $ 462 $ 124 $ 1 Trimble County Unit 2 75.00 % 1,549 323 10 December 31, 2023 Trimble County Unit 1 75.00 % $ 464 $ 110 $ — Trimble County Unit 2 75.00 % 1,490 300 49 LG&E December 31, 2024 E.W. Brown Units 6-7 38.00 % $ 53 $ 29 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 30 — Trimble County Unit 1 75.00 % 462 124 1 Trimble County Unit 2 14.25 % 472 79 5 Trimble County Units 5-6 29.00 % 37 19 — Trimble County Units 7-10 37.00 % 82 41 1 Cane Run Unit 7 22.00 % 137 27 — E.W. Brown Solar Unit 39.00 % 10 4 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 10 — 1 Mill Creek 5 31.00 % — — 74 Brown Wind 36.00 % — — — December 31, 2023 E.W. Brown Units 6-7 38.00 % $ 53 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 29 — Trimble County Unit 1 75.00 % 464 110 — Trimble County Unit 2 14.25 % 447 74 25 Trimble County Units 5-6 29.00 % 37 17 — Trimble County Units 7-10 37.00 % 82 39 — Cane Run Unit 7 22.00 % 127 25 3 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 7 — — Mill Creek 5 31.00 % — — 2 Brown Wind 36.00 % — — — Ownership Electric Plant Accumulated Construction KU December 31, 2024 E.W. Brown Units 6-7 62.00 % $ 87 $ 48 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 26 — Trimble County Unit 2 60.75 % 1,077 224 5 Trimble County Units 5-6 71.00 % 87 44 — Trimble County Units 7-10 63.00 % 136 69 1 Cane Run Unit 7 78.00 % 485 95 1 E.W. Brown Solar Unit 61.00 % 16 6 — Solar Share 56.00 % 4 1 — Mercer Solar 63.00 % 16 — 2 Mill Creek 5 69.00 % — — 164 Brown Wind 64.00 % 1 — — December 31, 2023 E.W. Brown Units 6-7 62.00 % $ 87 $ 45 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 25 — Trimble County Unit 2 60.75 % 1,043 227 24 Trimble County Units 5-6 71.00 % 86 41 — Trimble County Units 7-10 63.00 % 135 65 — Cane Run Unit 7 78.00 % 449 90 10 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — Mercer Solar 63.00 % 12 — 1 Mill Creek 5 69.00 % — — 3 Brown Wind 64.00 % 1 — —
Louisville Gas And Electric Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2024 and 2023, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2024 Trimble County Unit 1 75.00 % $ 462 $ 124 $ 1 Trimble County Unit 2 75.00 % 1,549 323 10 December 31, 2023 Trimble County Unit 1 75.00 % $ 464 $ 110 $ — Trimble County Unit 2 75.00 % 1,490 300 49 LG&E December 31, 2024 E.W. Brown Units 6-7 38.00 % $ 53 $ 29 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 30 — Trimble County Unit 1 75.00 % 462 124 1 Trimble County Unit 2 14.25 % 472 79 5 Trimble County Units 5-6 29.00 % 37 19 — Trimble County Units 7-10 37.00 % 82 41 1 Cane Run Unit 7 22.00 % 137 27 — E.W. Brown Solar Unit 39.00 % 10 4 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 10 — 1 Mill Creek 5 31.00 % — — 74 Brown Wind 36.00 % — — — December 31, 2023 E.W. Brown Units 6-7 38.00 % $ 53 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 29 — Trimble County Unit 1 75.00 % 464 110 — Trimble County Unit 2 14.25 % 447 74 25 Trimble County Units 5-6 29.00 % 37 17 — Trimble County Units 7-10 37.00 % 82 39 — Cane Run Unit 7 22.00 % 127 25 3 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 7 — — Mill Creek 5 31.00 % — — 2 Brown Wind 36.00 % — — — Ownership Electric Plant Accumulated Construction KU December 31, 2024 E.W. Brown Units 6-7 62.00 % $ 87 $ 48 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 26 — Trimble County Unit 2 60.75 % 1,077 224 5 Trimble County Units 5-6 71.00 % 87 44 — Trimble County Units 7-10 63.00 % 136 69 1 Cane Run Unit 7 78.00 % 485 95 1 E.W. Brown Solar Unit 61.00 % 16 6 — Solar Share 56.00 % 4 1 — Mercer Solar 63.00 % 16 — 2 Mill Creek 5 69.00 % — — 164 Brown Wind 64.00 % 1 — — December 31, 2023 E.W. Brown Units 6-7 62.00 % $ 87 $ 45 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 25 — Trimble County Unit 2 60.75 % 1,043 227 24 Trimble County Units 5-6 71.00 % 86 41 — Trimble County Units 7-10 63.00 % 135 65 — Cane Run Unit 7 78.00 % 449 90 10 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — Mercer Solar 63.00 % 12 — 1 Mill Creek 5 69.00 % — — 3 Brown Wind 64.00 % 1 — —
Kentucky Utilities Co [Member]
Jointly Owned Facilities [Line Items]
Jointly Owned Utility Facilities	At December 31, 2024 and 2023, the Balance Sheets reflect the owned interests in the generating plants listed below. Ownership Electric Plant Accumulated Construction PPL December 31, 2024 Trimble County Unit 1 75.00 % $ 462 $ 124 $ 1 Trimble County Unit 2 75.00 % 1,549 323 10 December 31, 2023 Trimble County Unit 1 75.00 % $ 464 $ 110 $ — Trimble County Unit 2 75.00 % 1,490 300 49 LG&E December 31, 2024 E.W. Brown Units 6-7 38.00 % $ 53 $ 29 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 30 — Trimble County Unit 1 75.00 % 462 124 1 Trimble County Unit 2 14.25 % 472 79 5 Trimble County Units 5-6 29.00 % 37 19 — Trimble County Units 7-10 37.00 % 82 41 1 Cane Run Unit 7 22.00 % 137 27 — E.W. Brown Solar Unit 39.00 % 10 4 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 10 — 1 Mill Creek 5 31.00 % — — 74 Brown Wind 36.00 % — — — December 31, 2023 E.W. Brown Units 6-7 38.00 % $ 53 $ 27 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 53.00 % 52 29 — Trimble County Unit 1 75.00 % 464 110 — Trimble County Unit 2 14.25 % 447 74 25 Trimble County Units 5-6 29.00 % 37 17 — Trimble County Units 7-10 37.00 % 82 39 — Cane Run Unit 7 22.00 % 127 25 3 E.W. Brown Solar Unit 39.00 % 10 3 — Solar Share 44.00 % 3 — — Mercer Solar 37.00 % 7 — — Mill Creek 5 31.00 % — — 2 Brown Wind 36.00 % — — — Ownership Electric Plant Accumulated Construction KU December 31, 2024 E.W. Brown Units 6-7 62.00 % $ 87 $ 48 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 26 — Trimble County Unit 2 60.75 % 1,077 224 5 Trimble County Units 5-6 71.00 % 87 44 — Trimble County Units 7-10 63.00 % 136 69 1 Cane Run Unit 7 78.00 % 485 95 1 E.W. Brown Solar Unit 61.00 % 16 6 — Solar Share 56.00 % 4 1 — Mercer Solar 63.00 % 16 — 2 Mill Creek 5 69.00 % — — 164 Brown Wind 64.00 % 1 — — December 31, 2023 E.W. Brown Units 6-7 62.00 % $ 87 $ 45 $ — Paddy's Run Unit 13 & E.W. Brown Unit 5 47.00 % 46 25 — Trimble County Unit 2 60.75 % 1,043 227 24 Trimble County Units 5-6 71.00 % 86 41 — Trimble County Units 7-10 63.00 % 135 65 — Cane Run Unit 7 78.00 % 449 90 10 E.W. Brown Solar Unit 61.00 % 16 5 — Solar Share 56.00 % 4 — — Mercer Solar 63.00 % 12 — 1 Mill Creek 5 69.00 % — — 3 Brown Wind 64.00 % 1 — —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2024
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 2026 Natural Gas Retail Supply 2025 Coal 2030 Coal Transportation and Fleeting Services 2033 Natural Gas Transportation 2055 LG&E KU Total 2025 $ 25 $ 11 $ 36 2026 27 12 39 2027 27 12 39 2028 25 11 36 2029 25 11 36 Thereafter 177 79 256 Total $ 306 $ 136 $ 442 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2024 2023 2022 LG&E $ 21 $ 20 $ 21 KU 9 9 9 Total $ 30 $ 29 $ 30
Guarantees	The table below details guarantees provided as of December 31, 2024. Exposure at December 31, 2024 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 $ 100 (b) 2028 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 (c) Various LG&E and KU LG&E and KU obligation of shortfall related to OVEC (d) (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. (c) 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. PPL's support obligations related to the PPAs were replaced by Aspen Power and terminated on January 8, 2024. (d) 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 $81 million at December 31, 2024, consisting of LG&E's share of $56 million and KU's share of $25 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.
Rhode Island Energy
Commitments And Contingencies [Line Items]
Schedule of Electric and Gas Purchase Contracts	These contracts include the following commitments: Contract Type Maximum Maturity Date Electric power 2027 Gas-related Beyond 2030 RIE’s commitments under these long-term contracts subsequent to December 31, 2024 are summarized in the table below. Total 2025 2026-2027 2028-2029 Thereafter Energy Purchase Obligations $ 936 $ 274 $ 240 $ 122 $ 300
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 2026 Natural Gas Retail Supply 2025 Coal 2030 Coal Transportation and Fleeting Services 2033 Natural Gas Transportation 2055 LG&E KU Total 2025 $ 25 $ 11 $ 36 2026 27 12 39 2027 27 12 39 2028 25 11 36 2029 25 11 36 Thereafter 177 79 256 Total $ 306 $ 136 $ 442 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2024 2023 2022 LG&E $ 21 $ 20 $ 21 KU 9 9 9 Total $ 30 $ 29 $ 30
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 2026 Natural Gas Retail Supply 2025 Coal 2030 Coal Transportation and Fleeting Services 2033 Natural Gas Transportation 2055 LG&E KU Total 2025 $ 25 $ 11 $ 36 2026 27 12 39 2027 27 12 39 2028 25 11 36 2029 25 11 36 Thereafter 177 79 256 Total $ 306 $ 136 $ 442 LG&E and KU had total energy purchases under the OVEC PPA for the years ended December 31 as follows: 2024 2023 2022 LG&E $ 21 $ 20 $ 21 KU 9 9 9 Total $ 30 $ 29 $ 30

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2024
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL 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. 2024 2023 2022 PPL Electric from PPL Services $ 227 $ 222 $ 241 LG&E from LKS 105 115 153 LG&E from PPL Services 66 42 13 KU from LKS 130 150 171 KU from PPL Services 65 48 14
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL 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. 2024 2023 2022 PPL Electric from PPL Services $ 227 $ 222 $ 241 LG&E from LKS 105 115 153 LG&E from PPL Services 66 42 13 KU from LKS 130 150 171 KU from PPL Services 65 48 14
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL 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. 2024 2023 2022 PPL Electric from PPL Services $ 227 $ 222 $ 241 LG&E from LKS 105 115 153 LG&E from PPL Services 66 42 13 KU from LKS 130 150 171 KU from PPL Services 65 48 14

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	12 Months Ended
	Dec. 31, 2024
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 42 $ 40 $ 47 Interest income 33 32 4 AFUDC - equity component 47 30 22 Charitable contributions (5) (5) (14) Talen litigation (a) (2) (124) 1 Miscellaneous (1) (13) (6) Other Income (Expense) - net $ 114 $ (40) $ 54 (a) PPL incurred legal expenses related to litigation associated with its former affiliate, Talen Montana, LLC, and certain affiliated entities (collectively, Talen), which was settled in December 2023.
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 17 $ 20 $ 15 Interest income 8 8 3 AFUDC - equity component 23 16 16 Charitable contributions (4) (3) (3) Miscellaneous 1 (2) (1) Other Income (Expense) - net $ 45 $ 39 $ 30
LOUISVILLE GAS And ELECTRIC CO [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 3 $ — $ 3 AFUDC - equity component 8 3 1 Charitable contributions (1) (1) (1) Miscellaneous 2 1 1 Other Income (Expense) - net $ 12 $ 3 $ 4
Kentucky Utilities Co [Member]
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	The components of "Other Income (Expense) - net" for the years ended December 31, were: 2024 2023 2022 Defined benefit plans - non-service credits (Note 10) $ 8 $ 6 $ 9 AFUDC - equity component 9 3 1 Charitable contributions (1) (1) — Miscellaneous (1) — (2) Other Income (Expense) - net $ 15 $ 8 $ 8

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2024
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, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 306 $ 306 $ — $ — $ 331 $ 331 $ — $ — Restricted cash and cash equivalents (a) 33 33 — — 51 51 — — Total Cash, Cash Equivalents and Restricted Cash (b) 339 339 — — 382 382 — — Special use funds (a): Money market fund 1 1 — — 1 1 — — Commingled debt fund measured at NAV (c) 10 — — — 9 — — — Commingled equity fund measured at NAV (c) 8 — — — 8 — — — Total special use funds 19 1 — — 18 1 — — December 31, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Price risk management assets (d): Gas contracts 9 — 4 5 1 — 1 — Total assets $ 367 $ 340 $ 4 $ 5 $ 401 $ 383 $ 1 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Gas contracts 13 — 10 3 60 — 41 19 Total price risk management liabilities $ 16 $ — $ 13 $ 3 $ 67 $ — $ 48 $ 19 PPL Electric Assets Cash and cash equivalents $ 24 $ 24 $ — $ — $ 51 $ 51 $ — $ — Total assets $ 24 $ 24 $ — $ — $ 51 $ 51 $ — $ — LG&E Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 18 $ 18 $ — $ — Restricted cash and cash equivalents (a) 16 16 — — 26 26 — — Total Cash, Cash Equivalents and Restricted Cash (b) 24 24 — — 44 44 — — Total assets $ 24 $ 24 $ — $ — $ 44 $ 44 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 13 $ 13 $ — $ — $ 14 $ 14 $ — $ — Restricted cash and cash equivalents (a) 16 16 — — 24 24 — — Total Cash, Cash Equivalents and Restricted Cash (b) 29 29 — — 38 38 — — Total assets $ 29 $ 29 $ — $ — $ 38 $ 38 $ — $ — (a) Current portion is included in "Other current assets" and noncurrent 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 assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" "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, 2024 December 31, 2023 Carrying Fair Value Carrying Fair Value PPL $ 16,503 $ 15,562 $ 14,612 $ 14,031 PPL Electric 5,214 4,862 4,567 4,475 LG&E 2,471 2,295 2,469 2,369 KU 3,066 2,750 3,064 2,861 (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 classified as Level 3 for the year ended December 31 is as follows: Gas Contracts 2024 Balance at beginning of period $ (19) Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities 2 Settlements 19 Balance at end of period $ 2

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2024
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, 2024 December 31, 2023 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 Gas contracts — — 7 10 — — 1 51 Total current — — 7 10 — — 1 52 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps (b) — — — 3 — — — 6 Gas contracts — — 2 3 — — — 9 Total noncurrent — — 2 6 — — — 15 Total derivatives $ — $ — $ 9 $ 16 $ — $ — $ 1 $ 67 (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 2024 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) 2023 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) 2022 Cash Flow Hedges: Interest rate swaps $ — Interest Expense $ (3) Total $ — $ (3) Derivatives Not Designated as Location of Gain (Loss) Recognized in 2024 2023 2022 Interest rate swaps Interest Expense — — (2) Gas contracts Energy Purchases (40) (19) 41 Other income (expense) - net — $ (1) $ — Total $ (40) $ (20) $ 39 Derivatives Not Designated as Location of Gain (Loss) Recognized as 2024 2023 2022 Gas contracts Regulatory assets - current $ 48 $ 9 $ 39 Regulatory assets - noncurrent 7 (8) — Interest rate swaps Regulatory assets - noncurrent 4 — 11 Total $ 59 $ 1 $ 50 The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2024: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 738 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) The following table presents the effect of cash flow hedge activity on the Statement of Income for the year ended December 31, 2023: Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 666 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) 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 Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 513 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)
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, 2024 Derivatives PPL $ 9 $ 5 $ — $ 4 $ 16 $ 5 $ — $ 11 LG&E — — — — 3 — — 3 December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7
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, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ — $ — $ 1 Total current — — — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 3 — 6 Total noncurrent — 3 — 6 Total derivatives $ — $ 3 $ — $ 7
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) 2024 2023 2022 Interest rate swaps Interest Expense $ — $ — $ (2) Derivative Instruments Location of Gain (Loss) 2024 2023 2022 Interest rate swaps Regulatory assets - noncurrent $ 4 $ — $ 11
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, 2024 Derivatives PPL $ 9 $ 5 $ — $ 4 $ 16 $ 5 $ — $ 11 LG&E — — — — 3 — — 3 December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7

Goodwill and Other Intangible_2

Goodwill and Other Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2024
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 2024 2023 2024 2023 2024 2023 2024 2023 Balance at beginning of period (a) $ 662 $ 662 $ 725 $ 725 $ 860 $ 861 $ 2,247 $ 2,248 Goodwill recognized during the period (b) — — — — — (1) — (1) Total $ 662 $ 662 $ 725 $ 725 $ 860 $ 860 $ 2,247 $ 2,247 (a) There were no accumulated impairment losses related to goodwill. (b) Recognized as a result of purchase price allocation adjustments related to the acquisition of RIE. See Note 9 for additional information.
Other Intangible Assets	The gross carrying amount and the accumulated amortization of other intangible assets were: December 31, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Contracts (a) $ 125 $ 116 $ 125 $ 107 Renewable Energy Credits 20 — 15 — Land rights and easements 432 147 411 143 Licenses and other 2 — 2 — Total subject to amortization 579 263 553 250 Not subject to amortization due to indefinite life: Land rights and easements 18 — 18 — Total not subject to amortization due to indefinite life 18 — 18 — Total $ 597 $ 263 $ 571 $ 250 (a) Gross carrying amount in 2024 and 2023 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: 2024 2023 2022 Intangible assets with no regulatory offset $ 5 $ 5 $ 5 Intangible assets with regulatory offset 8 9 9 Total $ 13 $ 14 $ 14
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 Intangible assets with no regulatory offset $ 4 $ 4 $ 4 $ 4 $ 4 Intangible assets with regulatory offset 8 2 — — — Total $ 12 $ 6 $ 4 $ 4 $ 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, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 396 $ 141 $ 389 $ 138 Licenses and other 2 1 2 1 Total subject to amortization 398 142 391 139 Not subject to amortization due to indefinite life: Land rights and easements 18 — 17 — Total $ 416 $ 142 $ 408 $ 139
Amortization Expense, Excluding Consumption of Emission Allowances / Renewable Energy Credits	Amortization expense was as follows: 2024 2023 2022 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: 2025 2026 2027 2028 2029 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, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 7 $ 2 $ 7 $ 2 OVEC power purchase agreement (a) 86 79 86 73 Total subject to amortization $ 93 $ 81 $ 93 $ 75 (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: 2024 2023 2022 Intangible assets with regulatory offset $ 6 $ 6 $ 6
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 Intangible assets with regulatory offset $ 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, 2024 December 31, 2023 Gross Accumulated Gross Accumulated Subject to amortization: Land rights and easements $ 29 $ 4 $ 17 $ 4 OVEC power purchase agreement (a) 39 36 39 33 Total subject to amortization $ 68 $ 40 $ 56 $ 37 (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: 2024 2023 2022 Intangible assets with regulatory offset 2 3 3
Future Amortization Expense	Amortization expense for each of the next five years is estimated to be: 2025 2026 2027 2028 2029 Intangible assets with regulatory offset $ 2 $ 1 $ — $ — $ —

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2024
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 2024 2023 2024 2023 2024 2023 ARO at beginning of period $ 158 $ 177 $ 85 $ 86 $ 66 $ 82 Accretion 8 9 4 4 4 5 Obligations incurred 9 2 3 1 6 1 Changes in estimated timing or cost 4 15 3 11 1 6 Obligations settled (24) (39) (11) (11) (13) (28) Other 2 (6) — (6) — ARO at end of period $ 157 $ 158 $ 84 $ 85 $ 64 $ 66
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 2024 2023 2024 2023 2024 2023 ARO at beginning of period $ 158 $ 177 $ 85 $ 86 $ 66 $ 82 Accretion 8 9 4 4 4 5 Obligations incurred 9 2 3 1 6 1 Changes in estimated timing or cost 4 15 3 11 1 6 Obligations settled (24) (39) (11) (11) (13) (28) Other 2 (6) — (6) — ARO at end of period $ 157 $ 158 $ 84 $ 85 $ 64 $ 66
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 2024 2023 2024 2023 2024 2023 ARO at beginning of period $ 158 $ 177 $ 85 $ 86 $ 66 $ 82 Accretion 8 9 4 4 4 5 Obligations incurred 9 2 3 1 6 1 Changes in estimated timing or cost 4 15 3 11 1 6 Obligations settled (24) (39) (11) (11) (13) (28) Other 2 (6) — (6) — ARO at end of period $ 157 $ 158 $ 84 $ 85 $ 64 $ 66

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	12 Months Ended
	Dec. 31, 2024
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, 2021 $ — $ 1 $ — $ (6) $ (152) $ (157) 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) Amounts arising during the year — — 1 — (41) (40) Reclassifications from AOCI — 3 — 1 (3) 1 Net OCI during the year — 3 1 1 (44) (39) December 31, 2023 $ — $ 6 $ 3 $ (4) $ (168) $ (163) Amounts arising during the year — — 1 — (22) (21) Reclassifications from AOCI — 3 — 1 (4) — Net OCI during the year — 3 1 1 (26) (21) December 31, 2024 $ — $ 9 $ 4 $ (3) $ (194) $ (184)
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, 2024, 2023 and 2022. 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 10 for additional information. PPL Details about AOCI 2024 2023 2022 Affected Line Item on the Qualifying derivatives Interest rate swaps $ (3) $ (3) $ (3) Interest Expense Total Pre-tax (3) (3) (3) Income Taxes — — 1 Total After-tax (3) (3) (2) Defined benefit plans Prior service costs (1) (2) (3) Net actuarial loss 4 3 (24) Total Pre-tax 3 1 (27) Income Taxes — 1 8 Total After-tax 3 2 (19) Total reclassifications during the year $ — $ (1) $ (21)

Summary of Significant Accoun_4

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Other	$ 76	$ 271
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	154	130	$ 95	$ 69
Additions charged to income	109	87	78
Deductions	85	52	52
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount			95
Other	39	41	36
PPL Electric Utilities Corp [Member]
SEC Schedule, 12-09, Valuation and Qualifying Accounts Disclosure [Line Items]
Other	8	8
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	41	50	33	$ 35
Additions charged to income	56	52	27
Deductions	65	35	29
SEC Schedule, 12-09, Valuation Allowances and Reserves, Adjusted for CECL, Amount			33
Other	$ 2	$ 3	$ 3

Accounting Policies (Details)

Accounting Policies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022	Dec. 31, 2021
Utility Revenue (Details) [Abstract]
Operating Revenues	$ 8,462	$ 8,312	$ 7,902
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	306	331
Total Cash, Cash Equivalents and Restricted Cash	339	382	357	$ 3,572
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 20	12	$ 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	$ 511	505
Balance Sheet Classification of Deferred Taxes [Abstract]
Goodwill	2,247	2,247
Fuel [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	153	144
Natural Gas Stored Underground [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	49	58
Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 309	$ 303
Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	3.20%	3.26%	3.21%
Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 130	$ 95	$ 69
Additions charged to income	109	87	78
Deductions	85	52	52
Balance at end of period	154	130	95
PPL Electric Utilities Corp [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	2,876	3,008	3,030
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	24	51
Total Cash, Cash Equivalents and Restricted Cash	24	51	25	21
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	9	7	$ 5
Income Taxes [Abstract]
Intercompany tax receivables (payables)	(2)	(21)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	104	99
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	$ 104	$ 99
PPL Electric Utilities Corp [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	2.52%	2.62%	2.75%
PPL Electric Utilities Corp [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 50	$ 33	$ 35
Additions charged to income	56	52	27
Deductions	65	35	29
Balance at end of period	41	50	33
Louisville Gas And Electric Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,648	1,613	1,798
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	8	18
Total Cash, Cash Equivalents and Restricted Cash	24	44	$ 93	9
Income Taxes [Abstract]
Intercompany tax receivables (payables)	(2)	(5)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	157	143
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	64	50
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	29	34
Louisville Gas And Electric Co [Member] | Material And Supplies [Member]
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	$ 64	$ 59
Louisville Gas And Electric Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	4.02%	4%	4.16%
Louisville Gas And Electric Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 6	$ 4	$ 3
Additions charged to income	4	4	6
Deductions	7	2	5
Balance at end of period	3	6	4
Kentucky Utilities Co [Member]
Utility Revenue (Details) [Abstract]
Operating Revenues	1,964	1,884	2,074
Restricted Cash and Cash Equivalents [Abstract]
Cash and cash equivalents	13	14
Total Cash, Cash Equivalents and Restricted Cash	29	38	$ 21	$ 13
Income Taxes [Abstract]
Intercompany tax receivables (payables)	(5)	(3)
Fuel, Materials and Supplies (Details) [Abstract]
Fuel, materials and supplies on the Balance Sheet	173	185
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	89	94
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	$ 84	$ 91
Kentucky Utilities Co [Member] | Regulated Operations [Member] | Utility Plant [Member]
Depreciation (Details) [Abstract]
Weighted-average rates	3.86%	3.95%	4.01%
Kentucky Utilities Co [Member] | Allowance For Doubtful Accounts [Member]
Allowance for Doubtful Accounts (Details) [Roll Forward]
Balance at beginning of period	$ 2	$ 3	$ 3
Additions charged to income	4	3	6
Deductions	4	4	6
Balance at end of period	2	2	3
Louisville Gas and Electric [Member]
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	3	1	0
Kentucky Utilities [Member]
Property, Plant and Equipment (Numeric) [Abstract]
Interest costs, capitalized during the period	$ 4	$ 1	$ 0

New Accounting Guidance Adopted

New Accounting Guidance Adopted (Details) $ in Millions	Dec. 31, 2024 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 0
Lease Liability - Current	0
Lease Liability - Noncurrent	0
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset
Lease Liability - Current
Lease Liability - Noncurrent
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset
Lease Liability - Current
Lease Liability - Noncurrent

Segment and Related Informati_3

Segment and Related Information (Income Statement and Balance Sheet Data) (Details) $ in Millions		12 Months Ended
		Dec. 31, 2024 USD ($) Integer	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Income Statement Data
Operating Revenues from external customers		$ 8,462	$ 8,312	$ 7,902
Fuel		783	733	931
Energy purchases		1,679	1,841	1,686
Depreciation		1,279	1,254	1,181
Taxes, other than income		374	392	332
Other Income (Expense) - net		(114)	40	(54)
Amortization		78	81	52
Interest Expense, Operating and Nonoperating		738	666	513
Income Before Income Taxes		1,116	924	915
Income Taxes		228	184	201
Deferred income taxes and investment tax credits		196	322	179
Net income (loss)		888	740	756
Cash Flow Data
Expenditures for long-lived assets		2,805	2,390	2,158
Balance Sheet Data
Total Assets		$ 41,069	39,236
Segment Information (Numeric) [Abstract]
Number of reportable segments | Integer		3
PPL Electric Utilities Corp [Member]
Income Statement Data
Operating Revenues from external customers		$ 2,876	3,008	3,030
Energy purchases		721	992	1,048
Depreciation		401	397	393
Taxes, other than income		131	143	149
Other Income (Expense) - net		(45)	(39)	(30)
Amortization		45	41	22
Interest Expense, Operating and Nonoperating		246	223	171
Income Before Income Taxes		750	687	699
Income Taxes		176	168	174
Deferred income taxes and investment tax credits		129	46	91
Net income (loss)	[1]	574	519	525
Balance Sheet Data
Total Assets		$ 15,475	14,294
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		2
Number of reportable segments | Integer		1
LOUISVILLE GAS And ELECTRIC CO [Member]
Income Statement Data
Operating Revenues from external customers		$ 1,648	1,613	1,798
Fuel		308	286	346
Energy purchases		151	168	245
Depreciation		305	302	298
Taxes, other than income		49	48	48
Other Income (Expense) - net		(12)	(3)	(4)
Amortization		16	14	5
Interest Expense, Operating and Nonoperating		105	102	89
Income Before Income Taxes		374	335	335
Income Taxes		77	69	63
Deferred income taxes and investment tax credits		6	(14)	(6)
Net income (loss)	[2]	297	266	272
Balance Sheet Data
Total Assets		$ 7,992	7,753
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		1
Number of reportable segments | Integer		1
Kentucky Utilities Co [Member]
Income Statement Data
Operating Revenues from external customers		$ 1,964	1,884	2,074
Fuel		476	447	585
Energy purchases		25	24	28
Depreciation		403	392	386
Taxes, other than income		49	45	45
Other Income (Expense) - net		(15)	(8)	(8)
Amortization		21	20	18
Income Before Income Taxes		445	389	398
Income Taxes		89	77	76
Deferred income taxes and investment tax credits		(15)	(10)	2
Net income (loss)	[3]	356	312	322
Balance Sheet Data
Total Assets		$ 10,073	9,714
Segment Information (Numeric) [Abstract]
Number of operating segments | Integer		1
Number of reportable segments | Integer		1
Total Segments
Income Statement Data
Operating Revenues from external customers		$ 8,462	8,311	7,879
Fuel		783	733	931
Energy purchases		1,679	1,842	1,686
Operation and maintenance		2,239	2,136	2,095
Depreciation		1,276	1,249	1,170
Taxes, other than income		374	392	333
Other Income (Expense) - net		(131)	(70)	(70)
Amortization		70	75	47
Interest Expense, Operating and Nonoperating		(581)	(541)	(415)
Income Taxes		(358)	(321)	(289)
Deferred income taxes and investment tax credits		169	77	136
Net income (loss)		(1,303)	(1,167)	(1,030)
Cash Flow Data
Expenditures for long-lived assets		2,812	2,360	2,074
Rhode Island Regulated
Income Statement Data
Operating Revenues from external customers		2,024	1,851	1,038
Fuel		0	0	0
Energy purchases		782	658	365
Operation and maintenance		731	705	531
Depreciation		165	156	92
Taxes, other than income		144	156	92
Other Income (Expense) - net		(24)	(19)	(23)
Amortization		1	1	2
Interest Expense, Operating and Nonoperating		(95)	(83)	(39)
Income Taxes		(22)	(16)	14
Deferred income taxes and investment tax credits		38	48	39
Net income (loss)		(109)	(96)	44
Cash Flow Data
Expenditures for long-lived assets		495	454	268
Balance Sheet Data
Total Assets		7,055	6,515
Kentucky Regulated [Member]
Income Statement Data
Operating Revenues from external customers		3,562	3,452	3,811
Fuel		783	733	931
Energy purchases		176	192	273
Operation and maintenance		803	826	959
Depreciation		710	696	685
Taxes, other than income		99	93	92
Other Income (Expense) - net		(29)	(12)	(12)
Amortization		24	33	23
Interest Expense, Operating and Nonoperating		(240)	(235)	(205)
Income Taxes		(160)	(137)	(129)
Deferred income taxes and investment tax credits		2	(17)	6
Net income (loss)		(620)	(552)	(549)
Cash Flow Data
Expenditures for long-lived assets		1,088	950	917
Balance Sheet Data
Total Assets		17,626	17,029
Pennsylvania Regulated [Member]
Income Statement Data
Operating Revenues from external customers		2,876	3,008	3,030
Fuel		0	0	0
Energy purchases		721	992	1,048
Operation and maintenance		705	605	605
Depreciation		401	397	393
Taxes, other than income		131	143	149
Other Income (Expense) - net		(78)	(39)	(35)
Amortization		45	41	22
Interest Expense, Operating and Nonoperating		(246)	(223)	(171)
Income Taxes		(176)	(168)	(174)
Deferred income taxes and investment tax credits		129	46	91
Net income (loss)		(574)	(519)	(525)
Cash Flow Data
Expenditures for long-lived assets		1,229	956	889
Balance Sheet Data
Total Assets		15,475	14,294
Corporate And Other [Member]
Income Statement Data
Operating Revenues from external customers		0	1	23
Amortization		8	6	5
Deferred income taxes and investment tax credits		27	245	43
Net income (loss)		415	427	316
Cash Flow Data
Expenditures for long-lived assets		(7)	30	$ 84
Balance Sheet Data
Total Assets		$ 913	$ 1,398
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) $ in Millions	7 Months Ended	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2024 USD ($) Days	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 8,462	$ 8,312	$ 7,902
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		5	1	(92)
Other Revenue		(23)	(23)	(24)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		8,444	8,290	7,786
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		103	79	70
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	$ 34	39	43	34	$ 42
Contract with Customer, Liability, Revenue Recognized		$ 26	21	25
PPL Electric [Member]
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days		21
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	23
Rhode Island Regulated
Revenue from contracts with customers [Line Items]
Number Of Days Due From Invoice Date | Days		21
Rhode Island Regulated | Net Metering
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			(146)	(79)
Contract with Customer, Asset and Liability [Abstract]
Utilities Operating Expense, Purchased Power		$ 175
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		4,162	3,747	3,583
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,039	1,673	1,660
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		773	712	756
Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		390	1,120	878
Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		23	22	28
Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		63	50	97
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		994	966	784
Pennsylvania Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		2,876	3,008	3,030
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,842	2,998	2,960
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,502	1,649	1,647
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		418	444	491
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		47	55	85
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		57	54	54
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		818	796	683
Kentucky Regulated [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		3,562	3,452	3,811
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		3,582	3,440	3,815
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,510	1,458	1,637
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,028	1,001	1,068
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		635	637	662
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		323	272	323
Kentucky Regulated [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		23	22	28
Kentucky Regulated [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		63	50	97
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		0	1	23
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			1	23
Corporate And Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			0	0
Corporate And Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			0	0
Corporate And Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			0	0
Corporate And Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			1	23
Corporate And Other [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			0	0
Corporate And Other [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			0	0
Corporate And Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers			0	0
Rhode Island Regulated
Revenue from contracts with customers [Line Items]
Operating Revenues		2,024	1,851	1,038
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,020	1,851	988
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,150	640	299
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		593	228	101
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		91	20	9
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		10	793	478
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		176	170	101
PPL Electric Utilities Corp [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 2,876	3,008	3,030
Number Of Days Due From Invoice Date | Days		21
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		$ (19)	5	(56)
Other Revenue		(15)	(15)	(14)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		2,842	2,998	2,960
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		52	47	21
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	23	28	29	23	25
Contract with Customer, Liability, Revenue Recognized		12	10	12
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,502	1,649	1,647
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		418	444	491
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		47	55	85
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		57	54	54
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		818	796	683
Louisville Gas And Electric Co [Member]
Revenue from contracts with customers [Line Items]
Operating Revenues		$ 1,648	1,613	1,798
Number Of Days Due From Invoice Date | Days		22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		$ 13	(1)	9
Other Revenue		(4)	(4)	(6)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,657	1,608	1,801
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		4	4	6
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	5	5	6	5	6
Contract with Customer, Liability, Revenue Recognized		6	5	6
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		754	751	835
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		518	517	551
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		188	189	199
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		147	104	141
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		50	47	75
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		$ 1,964	1,884	2,074
Number Of Days Due From Invoice Date | Days		22
Reconciliation of Revenue from Contracts with Customers [Abstract]
Alternative Revenue Programs		$ 16	(5)	5
Other Revenue		(4)	(4)	(4)
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		1,976	1,875	2,075
Credit loss from contract with customer [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)		4	2	6
Contract with Customer, Asset and Liability [Abstract]
Contract with Customer, Liability	$ 6	6	7	6	$ 6
Contract with Customer, Liability, Revenue Recognized		7	6	6
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		756	707	802
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		510	484	517
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		447	448	463
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		176	168	182
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		23	22	28
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Abstract]
Revenue from Contracts with Customers		64	46	83
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	$ 8,444	$ 8,290	$ 7,786
Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,842	2,998	2,960
Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	3,582	3,440	3,815
Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		1	23
Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,020	1,851	988
Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	4,162	3,747	3,583
Residential [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,502	1,649	1,647
Residential [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,510	1,458	1,637
Residential [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		0	0
Residential [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,150	640	299
Residential [Member] | Rhode Island Regulated | Reclassification, Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	469
Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,039	1,673	1,660
Commercial [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	418	444	491
Commercial [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,028	1,001	1,068
Commercial [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		0	0
Commercial [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	593	228	101
Commercial [Member] | Rhode Island Regulated | Reclassification, Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	372
Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	773	712	756
Industrial [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	47	55	85
Industrial [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	635	637	662
Industrial [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		0	0
Industrial [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	91	20	9
Industrial [Member] | Rhode Island Regulated | Reclassification, Other
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	88
Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	390	1,120	878
Other [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	57	54	54
Other [Member] | Kentucky Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	323	272	323
Other [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		1	23
Other [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	10	793	478
Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	23	22	28
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	23	22	28
Wholesale Municipal [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		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	63	50	97
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	63	50	97
Wholesale Other [Member] | Corporate And Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers		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	994	966	784
Transmission [Member] | Pennsylvania Regulated [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	818	796	683
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
Transmission [Member] | Rhode Island Regulated
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	176	170	101
PPL Electric Utilities Corp [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	2,842	2,998	2,960
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,502	1,649	1,647
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	418	444	491
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	47	55	85
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	57	54	54
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	818	796	683
Kentucky Utilities Co [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	1,976	1,875	2,075
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	756	707	802
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	510	484	517
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	447	448	463
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	176	168	182
Kentucky Utilities Co [Member] | Wholesale Municipal [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	23	22	28
Kentucky Utilities Co [Member] | Wholesale Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	64	46	83
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	1,657	1,608	1,801
LOUISVILLE GAS And ELECTRIC CO [Member] | Residential [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	754	751	835
LOUISVILLE GAS And ELECTRIC CO [Member] | Commercial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	518	517	551
LOUISVILLE GAS And ELECTRIC CO [Member] | Industrial [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	188	189	199
LOUISVILLE GAS And ELECTRIC CO [Member] | Other [Member]
Disaggregation of Revenue [Line Items]
Revenue from Contracts with Customers	147	104	141
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	50	47	75
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, 2024	Dec. 31, 2023	Dec. 31, 2022
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
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Income (Numerator)
Net income (loss)	$ 888	$ 740	$ 756
Less amounts allocated to participating securities	2	1	1
Net Income (Loss) Available to Common Stockholders, Basic	886	739	755
Net Income (Loss) from Continuing Operations Available to Common Shareholders, Diluted	886	739	713
Net income available to PPL common shareowners - Basic	886	739	713
Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Diluted	0	0	42
Net Income (Loss) from Discontinued Operations Available to Common Shareholders, Basic	0	0	42
Net income available to PPL common shareowners - Diluted	$ 886	$ 739	$ 755
Shares of Common Stock (Denominator)
Weighted-average shares - Basic EPS (in shares)	737,756	737,036	736,027
Add incremental non-participating securities:
Share-based payment awards (in shares)	2,097	1,130	875
Weighted-average shares - Diluted EPS (in shares)	739,853	738,166	736,902
Income from Continuing Operations After Income Taxes, Per Basic Share	$ 1.20	$ 1	$ 0.97
Basic EPS - Available to PPL common shareowners:
Net Income (Loss)	1.20	1	1.03
Income from Continuing Operations After Income Taxes, Per Diluted Share	1.20	1	0.96
Income (Loss) from Discontinued Operations (net of income taxes), Per Diluted Shares	0	0	0.06
Diluted EPS - Available to PPL common shareowners:
Net Income (in dollars per share)	$ 1.20	$ 1	$ 1.02
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Common stock issued under DRIP (in shares)	202	0
Shares Issued (Numeric) [Abstract]
Income (Loss) from Continuing Operations After Income Taxes	$ 888	$ 740	$ 714
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	0	243	93

Income and Other Taxes (Tax Ref

Income and Other Taxes (Tax Reform) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Tax Reform [Line Items]
Income Tax Expense (Benefit)	$ 228	$ 184	$ 201
Net Increase in Regulatory Liability	68	37	119
Deferred Tax Liabilities, Net	3,344	3,095
PPL Electric Utilities Corp [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	176	168	174
Net Increase in Regulatory Liability	101	38	59
Deferred Tax Liabilities, Net	1,726	1,573
Louisville Gas And Electric Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	77	69	63
Net Increase in Regulatory Liability	3	(25)	(17)
Deferred Tax Liabilities, Net	803	776
Kentucky Utilities Co [Member]
Tax Reform [Line Items]
Income Tax Expense (Benefit)	89	77	76
Net Increase in Regulatory Liability	(23)	(25)	$ 19
Deferred Tax Liabilities, Net	$ 924	$ 912

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, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	$ 1,116	$ 924	$ 915
Deferred Tax Assets
Deferred investment tax credits	28	28
Regulatory liabilities	133	123
Income taxes due to customer	418	436
Accrued pension and postretirement costs	112	101
State loss carryforwards	224	253
Contributions in aid of construction	163	149
Leases	114	111
Valuation allowances	(224)	(245)
Total deferred tax assets	1,101	1,129
Deferred Tax Liabilities
Domestic plant - net	3,898	3,749
Regulatory assets	432	376
Prepayments	39	47
Goodwill	38	22
Domestic - other	38	30
Total deferred tax liabilities	4,445	4,224
Net deferred tax liability	3,344	3,095
Loss carryforwards
State loss carryforwards	224	253
Deferred tax asset tax credit carryforwards	24	67
Deferred Tax Assets, Goodwill and Intangible Assets	72	78
Renewable Tax Credits Purchased		300
Deferred Tax Assets, Bad Debt	37	28
Federal [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset tax credit carryforwards	14
State [Member]
Deferred Tax Assets
State loss carryforwards	224
Loss carryforwards
Net operating losses	5,011
Charitable contributions	10
State loss carryforwards	224
Charitable contribution carryforwards	1
Loss carryforward valuation allowance on net operating losses	(221)
Charitable Contributions Loss Carryforwards valuation allowance	(1)
State [Member] | General Business Tax Credit Carryforward [Member]
Loss carryforwards
Deferred tax asset tax credit carryforwards	2
Foreign Tax Jurisdiction [Member]
Deferred Tax Assets
Foreign capital loss carryforwards	2
Loss carryforwards
Capital losses	8
Foreign capital loss carryforwards	2
Loss carryforward valuation allowance on capital losses	(2)
Other Noncurrent Assets [Member]
Deferred Tax Liabilities
Deferred Tax Assets, State Taxes	12	9
PPL Electric Utilities Corp [Member]
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	750	687	699
Deferred Tax Assets
Regulatory liabilities	40	43
Income taxes due to customer	184	191
Accrued pension and postretirement costs	36	30
Contributions in aid of construction	120	105
Leases	22	27
Total deferred tax assets	402	396
Deferred Tax Liabilities
Domestic plant - net	1,934	1,810
Regulatory assets	160	119
Prepayments	30	36
Domestic - other	4	4
Total deferred tax liabilities	2,128	1,969
Net deferred tax liability	1,726	1,573
Louisville Gas And Electric Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	374	335	335
Deferred Tax Assets
Deferred investment tax credits	7	8
Regulatory liabilities	18	19
Income taxes due to customer	110	115
Deferred Tax Assets, Lease Liabilities	4	4
Accrued pension and postretirement costs	4	3
State tax credit carryforwards	6	8
Contributions in aid of construction	18	18
Leases	6	8
Valuation allowances	(6)	(8)
Total deferred tax assets	167	175
Deferred Tax Liabilities
Domestic plant - net	875	877
Regulatory assets	88	67
Lease right-of-use assets	4	3
Domestic - other	3	4
Total deferred tax liabilities	970	951
Net deferred tax liability	803	776
Louisville Gas And Electric Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	6
Valuation allowances	(6)
Kentucky Utilities Co [Member]
Income Before Income Taxes (Details) [Abstract]
Income from Continuing Operations Before Income Taxes	445	389	$ 398
Deferred Tax Assets
Deferred investment tax credits	20	21
Regulatory liabilities	29	23
Income taxes due to customer	124	131
Deferred Tax Assets, Lease Liabilities	6	5
State tax credit carryforwards	4	4
Contributions in aid of construction	12	10
Leases	4	5
Valuation allowances	(2)	(2)
Total deferred tax assets	197	197
Deferred Tax Liabilities
Domestic plant - net	1,053	1,045
Regulatory assets	55	50
Accrued pension and postretirement costs	6	7
Lease right-of-use assets	6	5
Domestic - other	1	2
Total deferred tax liabilities	1,121	1,109
Net deferred tax liability	924	$ 912
Kentucky Utilities Co [Member] | Federal [Member] | General Business Tax Credit Carryforward [Member]
Deferred Tax Assets
State tax credit carryforwards	4
Valuation allowances	$ (2)

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, 2024	Dec. 31, 2023	Dec. 31, 2022
Credit carryforwards
Deferred tax asset tax credit carryforwards	$ 24	$ 67
Deferred Tax Assets, Valuation Allowances	224	245
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	224	245
SEC Schedule 12-09, Valuation Allowance, Deduction, Tax Rate Change			$ 213
SEC Schedule 12-09, Valuation Allowance, Deduction, Expiration of NOL Carryforward	23	22	36
Recycling Tax Credit [Member] | State [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	8
Credit Carryforward Valuation Allowance Other	0
Other [Member] | Federal [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	14
Credit Carryforward Valuation Allowance Other	0
Other [Member] | State [Member]
Credit carryforwards
Deferred tax asset tax credit carryforwards	2
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	245	213	462
Additions charged to income	3	54	10
Additions charged to other accounts	1	0	0
Deductions	25	22	259
Balance at end of period	224	245	$ 213
Louisville Gas And Electric Co [Member]
Credit carryforwards
State tax credit carryforwards	6	8
Deferred Tax Assets, Valuation Allowances	6	8
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	6	8
Louisville Gas And Electric Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	6
Deferred Tax Assets, Valuation Allowances	6
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	6
Kentucky Utilities Co [Member]
Credit carryforwards
State tax credit carryforwards	4	4
Deferred Tax Assets, Valuation Allowances	2	2
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	2	$ 2
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member]
Credit carryforwards
State tax credit carryforwards	4
Deferred Tax Assets, Valuation Allowances	2
Valuation Allowances and Reserves (Details) [Roll Forward]
Deferred Tax Assets, Valuation Allowances	2
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Year 2028 [Member]
Credit carryforwards
State tax credit carryforwards	2
Kentucky Utilities Co [Member] | Other [Member] | Federal [Member] | Tax Credit Carryforward Expiration Indefinite [Member]
Credit carryforwards
State tax credit carryforwards	$ 2

Income and Other Taxes (Income

Income and Other Taxes (Income Tax Expense and Reconciliation of Income Tax Expense) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Income Tax Expense (Benefit)
Current - Federal	$ 23	$ (175)	$ (2)
Current - State	9	37	24
Total Current Expense	32	(138)	22
Deferred - Federal	137	286	122
Deferred - State	64	48	68
Total Deferred Expense (Benefit), excluding operating loss carry forwards	201	334	190
Amortization of investment tax credit	(3)	(3)	(3)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Deferred - Federal	1	3	2
Deferred - State	(3)	(12)	(10)
Total Tax Expense (Benefit) of Operating Loss Carryforwards	(2)	(9)	(8)
Total income tax from continuing operations	228	184	201
Income tax expense [Abstract]
Total income tax expense - Federal	158	111	119
Total income tax expense - State	70	73	82
Total income tax from continuing operations	228	184	201
Income Tax Expense (Benefit) Excluded From Income Taxes [Abstract]
Income tax related to other comprehensive income	(8)	(14)	11
Valuation allowance on state deferred taxes recorded to other comprehensive income	0	(1)	0
Total income tax expense (benefits) excluded from income taxes from continuing operations	(8)	(15)	(31)
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	234	194	192
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	65	58	68
Valuation allowance adjustments	2	12	9
Income tax credits	(8)	(22)	(3)
Depreciation and other items not normalized	(21)	(10)	(8)
Amortization of excess deferred federal and state income taxes	(45)	(48)	(54)
Other	1	0	(3)
Total increase (decrease)	(6)	(10)	9
Total income tax from continuing operations	$ 228	$ 184	$ 201
Effective income tax rate	20.40%	19.90%	22%
Expense related to increased Pennsylvania net operating loss carryforwards expected to be unutilized	$ 3	$ 11	$ 5
Taxes, other than income
State gross receipts	167	195	175
Domestic property and other	207	197	157
Total	374	392	332
Deferred Tax Assets, Valuation Allowances	224	245
Renewable Tax Credits Utilized		250
Renewable Tax Credits Purchased		300
WPD [Member]
Taxes, other than income
Income tax related to Discontinued Operations	0	0	(42)
PPL Electric Utilities Corp [Member]
Income Tax Expense (Benefit)
Current - Federal	44	91	63
Current - State	4	31	20
Total Current Expense	48	122	83
Deferred - Federal	86	28	60
Deferred - State	42	18	31
Total Deferred Expense (Benefit), excluding operating loss carry forwards	128	46	91
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	176	168	174
Income tax expense [Abstract]
Total income tax expense - Federal	130	119	123
Total income tax expense - State	46	49	51
Total income tax from continuing operations	176	168	174
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	158	144	147
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	47	49	54
Depreciation and other items not normalized	(16)	(9)	(7)
Amortization of excess deferred federal and state income taxes	(10)	(11)	(12)
Other	(3)	(5)	1
Total increase (decrease)	18	24	27
Total income tax from continuing operations	$ 176	$ 168	$ 174
Effective income tax rate	23.50%	24.50%	24.90%
Taxes, other than income
State gross receipts	$ 122	$ 136	$ 142
Domestic property and other	9	7	7
Total	131	143	149
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	0	0	(9)
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
Louisville Gas And Electric Co [Member]
Income Tax Expense (Benefit)
Current - Federal	60	70	60
Current - State	11	13	9
Total Current Expense	71	83	69
Deferred - Federal	1	(15)	(10)
Deferred - State	6	2	5
Total Deferred Expense (Benefit), excluding operating loss carry forwards	7	(13)	(5)
Amortization of investment tax credit	(1)	(1)	(1)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	77	69	63
Income tax expense [Abstract]
Total income tax expense - Federal	60	54	49
Total income tax expense - State	17	15	14
Total income tax from continuing operations	77	69	63
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	79	70	70
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	14	13	13
Amortization of excess deferred federal and state income taxes	(13)	(13)	(18)
Other	(3)	(1)	(2)
Total increase (decrease)	(2)	(1)	(7)
Total income tax from continuing operations	$ 77	$ 69	$ 63
Effective income tax rate	20.60%	20.60%	18.80%
Taxes, other than income
Domestic property and other	$ 49	$ 48	$ 48
Total	49	48	48
Deferred Tax Assets, Valuation Allowances	6	8
Kentucky Utilities Co [Member]
Income Tax Expense (Benefit)
Current - Federal	87	73	63
Current - State	17	13	11
Total Current Expense	104	86	74
Deferred - Federal	(15)	(11)	(3)
Deferred - State	2	4	7
Total Deferred Expense (Benefit), excluding operating loss carry forwards	(13)	(7)	4
Amortization of investment tax credit	(2)	(2)	(2)
Tax expense (benefit) of operating loss carryforwards [Abstract]
Total income tax from continuing operations	89	77	76
Income tax expense [Abstract]
Total income tax expense - Federal	70	60	58
Total income tax expense - State	19	17	18
Total income tax from continuing operations	89	77	76
Reconciliation of Income Tax Expense
Federal income tax on Income Before Income Taxes at statutory tax rate	93	82	84
Increase (decrease) due to:
State income taxes, net of federal income tax benefit	16	15	16
Amortization of investment tax credit	(2)	(2)	(2)
Amortization of excess deferred federal and state income taxes	(17)	(17)	(21)
Other	(1)	(1)	(1)
Total increase (decrease)	(4)	(5)	(8)
Total income tax from continuing operations	$ 89	$ 77	$ 76
Effective income tax rate	20%	19.80%	19.10%
Taxes, other than income
Domestic property and other	$ 49	$ 45	$ 45
Total	49	45	$ 45
Deferred Tax Assets, Valuation Allowances	$ 2	$ 2

Income and Other Taxes (Unrecog

Income and Other Taxes (Unrecognized to End) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2024 USD ($) Integer	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Income Tax Examination (Details) [Line Items]
Number of major tax jurisdictions tax returns are filed | Integer	4
Deferred Income Tax Expense (Benefit)	$ 201	$ 334	$ 190
Increase (Decrease) in Regulatory Assets and Liabilities	$ 68	37	119
US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2020 and prior
Pennsylvania - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2020 and prior
Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2019 and prior
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)	$ 128	46	91
Increase (Decrease) in Regulatory Assets and Liabilities	101	38	59
Effective Income Tax Rate Reconciliation, Change in Enacted State Tax Rate, Amount	$ 0	0	(9)
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
PPL Electric Utilities Corp [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2020 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	2020 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	2019 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)	$ 7	(13)	(5)
Increase (Decrease) in Regulatory Assets and Liabilities	$ 3	(25)	(17)
Louisville Gas And Electric Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2020 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	2019 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)	$ (13)	(7)	4
Increase (Decrease) in Regulatory Assets and Liabilities	$ (23)	$ (25)	$ 19
Kentucky Utilities Co [Member] | US - Federal [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2020 and prior
Kentucky Utilities Co [Member] | Kentucky - State [Member]
Income Tax Examination (Details) [Line Items]
Income tax examination, year(s) no longer under examination	2019 and prior

Utility Rate Regulation (Regula

Utility Rate Regulation (Regulatory Assets) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 2,060	$ 1,874
Current Regulatory Assets	320	293
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	$ 79	86
Regulatory Asset Amortization Period	15 years
LGE [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Regulatory Asset Amortization Period	12 months
KU [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Regulatory Asset Amortization Period	12 months
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 30	38
Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	7	6
Storm Damage Expense rider
Regulatory Assets [Line Items]
Current Regulatory Assets	68	12
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	14	5
Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	0
Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	113	97
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	44	43
Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	41	43
Current Regulatory Assets	20	26
Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	967	887
Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	20	22
Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	4	7
Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	53	58
Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	173	178
AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	280	289
Net Metering
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	147	112
Environmental Cost Recovery Mechanism
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	96	99
Derivative Instruments
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	1	8
Current Regulatory Assets	3	51
Rate adjustment mechanism
Regulatory Assets [Line Items]
Current Regulatory Assets	95	118
Renewable Energy Program
Regulatory Assets [Line Items]
Current Regulatory Assets	14	14
Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current Regulatory Assets	8	7
Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	24	21
Advanced metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	28	15
Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	83	0
TCJA (over/under collection)
Regulatory Assets [Line Items]
Current Regulatory Assets	21	0
ISR deferral
Regulatory Assets [Line Items]
Current Regulatory Assets	22	11
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	673	598
Current Regulatory Assets	133	57
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	7	6
PPL Electric Utilities Corp [Member] | Storm Damage Expense rider
Regulatory Assets [Line Items]
Current Regulatory Assets	68	12
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	2	0
PPL Electric Utilities Corp [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	27	31
PPL Electric Utilities Corp [Member] | Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	2	0
Current Regulatory Assets	0	1
PPL Electric Utilities Corp [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	473	417
PPL Electric Utilities Corp [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	3	3
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	173	178
PPL Electric Utilities Corp [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent 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] | Derivative Instruments
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Renewable Energy Program
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current Regulatory Assets	8	7
PPL Electric Utilities Corp [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Advanced metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
PPL Electric Utilities Corp [Member] | TCJA (over/under collection)
Regulatory Assets [Line Items]
Current Regulatory Assets	21	0
PPL Electric Utilities Corp [Member] | ISR deferral
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	491	395
Current Regulatory Assets	8	7
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	$ 44	46
Regulatory Asset Amortization Period	15 years
Louisville Gas And Electric Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Regulatory Asset Amortization Period	12 months
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 7	10
Louisville Gas And Electric Co [Member] | Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Storm Damage Expense rider
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Gas Line Tracker [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	4	0
Louisville Gas And Electric Co [Member] | Storm costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	20	15
Louisville Gas And Electric Co [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Current Regulatory Assets	4	7
Louisville Gas And Electric Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	226	217
Louisville Gas And Electric Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	9	10
Louisville Gas And Electric Co [Member] | Interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	4	7
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	31	34
Louisville Gas And Electric Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	75	76
Louisville Gas And Electric Co [Member] | Net Metering
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery Mechanism
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Derivative Instruments
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Renewable Energy Program
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	22	19
Louisville Gas And Electric Co [Member] | Advanced metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	14	7
Louisville Gas And Electric Co [Member] | Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	83	0
Louisville Gas And Electric Co [Member] | TCJA (over/under collection)
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Louisville Gas And Electric Co [Member] | ISR deferral
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	458	439
Current Regulatory Assets	1	3
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	$ 35	40
Regulatory Asset Amortization Period	15 years
Kentucky Utilities Co [Member] | Fuel Adjustment Clause [Member]
Regulatory Assets [Line Items]
Regulatory Asset Amortization Period	12 months
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	$ 23	28
Kentucky Utilities Co [Member] | Smart meter rider [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Storm Damage Expense rider
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Transmission Formula Rate [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	29	14
Kentucky Utilities Co [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Other [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	8	7
Current Regulatory Assets	1	3
Kentucky Utilities Co [Member] | Defined benefit plans [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	149	136
Kentucky Utilities Co [Member] | Unamortized loss on debt [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	6	7
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	22	24
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | AROs [Member]
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	205	213
Kentucky Utilities Co [Member] | Net Metering
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Environmental Cost Recovery Mechanism
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Derivative Instruments
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Renewable Energy Program
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	2	2
Kentucky Utilities Co [Member] | Advanced metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	14	8
Kentucky Utilities Co [Member] | Retired asset recovery
Regulatory Assets [Line Items]
Noncurrent Regulatory Assets	0	0
Kentucky Utilities Co [Member] | TCJA (over/under collection)
Regulatory Assets [Line Items]
Current Regulatory Assets	0	0
Kentucky Utilities Co [Member] | ISR deferral
Regulatory Assets [Line Items]
Current Regulatory Assets	$ 0	$ 0

Utility Rate Regulation (Regu_2

Utility Rate Regulation (Regulatory Liabilities) (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 223	$ 225
Noncurrent regulatory liabilities	3,335	3,340
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	52	51
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	12	0
Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	15
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	21
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	5
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	15
Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,022	996
Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	10	19
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,899	1,977
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	294	252
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	54	57
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	43	22
Noncurrent regulatory liabilities	40	34
Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	71	72
Energy efficiency
Regulatory Liabilities [Line Items]
Current regulatory liabilities	25	23
Noncurrent regulatory liabilities	16	5
Demand Side Management
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	1
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	57	91
Noncurrent regulatory liabilities	839	836
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	52	51
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	18
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	5
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	15
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	739	763
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	100	73
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	3	2
Noncurrent regulatory liabilities	0	0
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
PPL Electric Utilities Corp [Member] | Demand Side Management
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	16
Noncurrent regulatory liabilities	815	827
Louisville Gas And Electric Co [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
Louisville Gas And Electric Co [Member] | Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	15
Louisville Gas And Electric Co [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	314	306
Louisville Gas And Electric Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	7	13
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	439	459
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	24	20
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	29
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	1
Noncurrent regulatory liabilities	4	0
Louisville Gas And Electric Co [Member] | Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Energy efficiency
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Demand Side Management
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	22	1
Noncurrent regulatory liabilities	1,009	1,018
Kentucky Utilities Co [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
Kentucky Utilities Co [Member] | Gas Supply Clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Accumulated cost of removal of utility plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	408	399
Kentucky Utilities Co [Member] | Power Purchase Agreement Ohio Valley Electric Corporation [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	3	6
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	498	523
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	65	59
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	28
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	0
Noncurrent regulatory liabilities	8	3
Kentucky Utilities Co [Member] | Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Energy efficiency
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Demand Side Management
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 10	$ 1

Utility Rate Regulation (Regu_3

Utility Rate Regulation (Regulatory Assets and Liabilities) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Regulatory Assets and Liabilities (Numeric) [Line Items]
Increase (Decrease) in Regulatory Assets and Liabilities	$ 68	$ 37	$ 119
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	$ 79	86
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	$ 101	38	59
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	$ 3	(25)	(17)
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	$ 44	46
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	$ (23)	(25)	$ 19
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	$ 35	$ 40
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

1 Months Ended

3 Months Ended

12 Months Ended

Mar. 26, 2024 USD ($)

Nov. 06, 2023

Sep. 27, 2023 USD ($)

Oct. 16, 2018

Dec. 31, 2024 USD ($)

Dec. 31, 2023 USD ($)

Dec. 31, 2022 MW

Mar. 31, 2015

Dec. 31, 2024 USD ($)

Dec. 31, 2023 USD ($)

Jan. 31, 2025 USD ($)

Oct. 04, 2024 USD ($)

Apr. 26, 2024

Apr. 25, 2024 USD ($)

Nov. 21, 2023 USD ($)

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 2,060

$ 1,874

$ 2,060

$ 1,874

Storm Costs [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

113

97

113

97

Other [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 41

43

$ 41

43

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

Billing Issues, Expenses Incurred

$ 18

34

Distribution System Improvement Charge Cap

5%

5%

PPL Electric [Member] | Pennsylvania Public Utility Commission [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

PPL Electric Billing Issue, Donation to be Paid

$ 1

PPL Electric Billing Issue, Civil Penalty to be Paid

$ 1

Requested Distribution System Improvement Charge Cap

9%

LGE [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

CPCN NGCC Combustion Turbine Facilities, Power | MW

640

LGE [Member] | Mill Creek Unit 2

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Public Utilities, Property, Plant and Equipment, Generation or Processing

$ 221

$ 221

Public Utilities, Property, Plant and Equipment, Generation, Expected Remaining Book Value at Retirement

161

$ 161

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] | Mill Creek Unit 1 Retirement

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Amount of Regulatory Costs Not yet Approved

$ 125

LGE [Member] | Kentucky Public Service Commission [Member] | Storm Costs [Member] | September 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

2

$ 2

LGE [Member] | Kentucky Public Service Commission [Member] | Storm Costs [Member] | May 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 4

$ 4

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

12 months

LGE [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Amount of Regulatory Costs Not yet Approved

$ 2

KU [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

CPCN NGCC Combustion Turbine Facilities, Power | MW

640

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] | Storm Costs [Member] | September 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 11

$ 11

KU [Member] | Kentucky Public Service Commission [Member] | Storm Costs [Member] | May 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 5

$ 5

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

12 months

KU [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Amount of Regulatory Costs Not yet Approved

8

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 | Maximum ROE authorized

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

FERC Granted ROE

11.74%

Rhode Island Energy | Rhode Island Public Uitilty Commsion

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Recovery Cap on Capital Investment Related to AMF Program

$ 153

Capital Investment Spend on FY 2025 Gas ISR Plan

185

Contingency Plan Spend on FY 2025 Gas ISR Plan

11

Capital Investment Spend on FY 2025 Electric ISR Plan

141

Total Approved Spend on FY 2025 Gas ISR Plan

$ 180

Approved Contingency Plan Spend on FY 2025 Gas ISR Plan

11

Capital Investment Spend on FY 2026 Gas ISR Plan

$ 187

Capital Investment Spend on FY 2026 Electric ISR Plan

160

Contingency Plan Spend on FY 2026 Gas ISR Plan

15

Total Capital Investment Spend on FY 2026 Electric ISR Plan

248

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Paving Costs

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Capital Investment Spend on FY 2026 Gas ISR Plan

$ 22

Rhode Island Energy | Rhode Island Public Uitilty Commsion | AMF Capital Investment

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

88

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Vegetation Management

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Capital Investment Spend on FY 2026 Electric ISR Plan

14

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Other O&M

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Capital Investment Spend on FY 2026 Electric ISR Plan

1

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Paving Costs

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Total Approved Spend on FY 2025 Gas ISR Plan

12

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Capital Investment

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Total Approved Spend on FY 2025 Gas ISR Plan

168

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Vegetation Management

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Capital Investment Spend on FY 2025 Electric ISR Plan

13

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

13

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Other O&M

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Capital Investment Spend on FY 2025 Electric ISR Plan

1

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

1

Rhode Island Energy | Rhode Island Public Uitilty Commsion | Capital Investment

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

$ 132

PPL Electric Utilities Corp [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Act 129 Recovery Period Under Phase IV Plan

5 years

Regulatory assets

$ 673

598

$ 673

598

Billing Issues, Expenses Incurred

$ 18

34

Distribution System Improvement Charge Cap

5%

5%

PPL Electric Utilities Corp [Member] | Storm Costs [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 22

0

$ 22

0

PPL Electric Utilities Corp [Member] | Other [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

2

0

2

0

PPL Electric Utilities Corp [Member] | Pennsylvania Public Utility Commission [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

PPL Electric Billing Issue, Donation to be Paid

$ 1

PPL Electric Billing Issue, Civil Penalty to be Paid

$ 1

Requested Distribution System Improvement Charge Cap

9%

Louisville Gas And Electric Co [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

CPCN NGCC Combustion Turbine Facilities, Power | MW

640

New NGCC LG&E Planned Ownership Percentage

0.31

Regulatory assets

491

395

491

395

Louisville Gas And Electric Co [Member] | Mill Creek Unit 2

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Public Utilities, Property, Plant and Equipment, Generation or Processing

221

221

Public Utilities, Property, Plant and Equipment, Generation, Expected Remaining Book Value at Retirement

161

161

Louisville Gas And Electric Co [Member] | Storm Costs [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

20

15

20

15

Louisville Gas And Electric Co [Member] | Other [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

0

0

$ 0

0

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] | Mill Creek Unit 1 Retirement

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Amount of Regulatory Costs Not yet Approved

$ 125

Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Storm Costs [Member] | September 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

2

$ 2

Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Storm Costs [Member] | May 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 4

$ 4

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

12 months

Louisville Gas And Electric Co [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Amount of Regulatory Costs Not yet Approved

2

Kentucky Utilities Co [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

CPCN NGCC Combustion Turbine Facilities, Power | MW

640

New NGCC KU Planned Ownership Percentage

0.69

Regulatory assets

$ 458

439

$ 458

439

Kentucky Utilities Co [Member] | Storm Costs [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

29

14

29

14

Kentucky Utilities Co [Member] | Other [Member]

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

8

$ 7

$ 8

$ 7

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] | Storm Costs [Member] | September 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

11

$ 11

Kentucky Utilities Co [Member] | Kentucky Public Service Commission [Member] | Storm Costs [Member] | May 2024 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Regulatory assets

$ 5

$ 5

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

12 months

Kentucky Utilities Co [Member] | Subsequent Event [Member] | Kentucky Public Service Commission [Member] | January 2025 KY Storm

Regulatory Matters Federal Matters Federal Energy Regulatory Commission Wholesale Formula Rates Numeric [Abstract]

Amount of Regulatory Costs Not yet Approved

$ 8

Utility Rate Regulation (Other)

Utility Rate Regulation (Other) (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.5	$ 1.5	$ 1.3
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Purchases of accounts receivable	$ 1.5	$ 1.5	$ 1.3

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Jan. 01, 2025	Dec. 31, 2024	Dec. 31, 2023
Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		$ 303	$ 993
PPL Capital Funding [Member]
Financing Activities [Line Items]
Capacity		1,450
Borrowed		0	0
Letters of credit and commercial paper issued		153	403
Unused capacity		1,297
PPL Capital Funding [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		138	365
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		138	390
Unused capacity		$ 1,112
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 400
Line of Credit Facility, Borrowing Capacity Sublimit		1,000	1,000
PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		138	365
PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	$ 1,500
PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Financing Activities [Line Items]
Capacity		100
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
Borrowed		0	0
Letters of credit and commercial paper issued		15	13
Unused capacity		$ 85
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
PPL Electric [Member]
Financing Activities [Line Items]
Capacity		$ 650
Borrowed		0	0
Letters of credit and commercial paper issued		1	511
Unused capacity		649
PPL Electric [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		0	510
PPL Electric [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		650
Borrowed		0	0
Letters of credit and commercial paper issued		1	511
Unused capacity		$ 649
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 250
PPL Electric [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	750
PPL Electric [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
LGE [Member]
Financing Activities [Line Items]
Capacity		$ 500
Borrowed		0	0
Letters of credit and commercial paper issued		25	0
Unused capacity		475
LGE [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		25	0
LGE [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		500
Borrowed		0	0
Letters of credit and commercial paper issued		25	0
Unused capacity		$ 475
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 250
LGE [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	600
LGE [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
KU [Member]
Financing Activities [Line Items]
Capacity		$ 400
Borrowed		0	0
Letters of credit and commercial paper issued		140	93
Unused capacity		260
KU [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		140	93
KU [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0	0
Letters of credit and commercial paper issued		140	93
Unused capacity		$ 260
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 250
KU [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	600
KU [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Rhode Island Energy | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		$ 0	25
Rhode Island Energy | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Line of Credit Facility, Borrowing Capacity Sublimit		250	250
Rhode Island Energy | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		0	25
PPL Electric Utilities Corp [Member]
Financing Activities [Line Items]
Capacity		650
Borrowed		0	0
Letters of credit and commercial paper issued		1	511
Unused capacity		649
PPL Electric Utilities Corp [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		0	510
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		1	511
Unused capacity		$ 649
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 250
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	750
PPL Electric Utilities Corp [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Louisville Gas And Electric Co [Member]
Financing Activities [Line Items]
Capacity		$ 500
Borrowed		0	0
Letters of credit and commercial paper issued		25	0
Unused capacity		475
Louisville Gas And Electric Co [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		25	0
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		25	0
Unused capacity		$ 475
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 250
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	600
Louisville Gas And Electric Co [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Kentucky Utilities Co [Member]
Financing Activities [Line Items]
Capacity		$ 400
Borrowed		0	0
Letters of credit and commercial paper issued		140	93
Unused capacity		260
Kentucky Utilities Co [Member] | Commercial Paper [Member]
Financing Activities [Line Items]
Commercial paper issuances		140	93
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Financing Activities [Line Items]
Capacity		400
Borrowed		0	0
Letters of credit and commercial paper issued		140	$ 93
Unused capacity		$ 260
Maximum percentage of debt to total capitalization allowed under the credit facility		70%
Potential capacity increase		$ 250
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member] | Subsequent Event [Member]
Financing Activities [Line Items]
Capacity	$ 600
Kentucky Utilities Co [Member] | Term Loan Credit Facility [Member]
Financing Activities [Line Items]
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, 2024	Dec. 31, 2023
Short-term Debt [Line Items]
Capacity	$ 3,150
Commercial paper issuances	303	$ 993
Unused capacity	$ 2,847
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.76%	5.66%
Capacity	$ 1,350
Commercial paper issuances	138	$ 365
Unused capacity	1,212
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted-average interest rate		5.67%
Capacity	650
Commercial paper issuances	0	$ 510
Unused capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.72%
Capacity	$ 500
Commercial paper issuances	25	$ 0
Unused capacity	$ 475
KU [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.71%	5.64%
Capacity	$ 400
Commercial paper issuances	140	$ 93
Unused capacity	260
Rhode Island Energy
Short-term Debt [Line Items]
Weighted-average interest rate		5.72%
Capacity	250
Commercial paper issuances	0	$ 25
Unused capacity	250
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted-average interest rate		5.67%
Capacity	650
Commercial paper issuances	0	$ 510
Unused capacity	$ 650
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.72%
Capacity	$ 500
Commercial paper issuances	25	$ 0
Unused capacity	$ 475
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted-average interest rate	4.71%	5.64%
Capacity	$ 400
Commercial paper issuances	140	$ 93
Unused capacity	$ 260

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Aug. 31, 2024	Mar. 31, 2024	Jan. 31, 2024	Dec. 31, 2024	Aug. 01, 2024	Mar. 01, 2024	Jan. 01, 2024	Dec. 31, 2023
Debt Instrument [Line Items]
Principal outstanding				$ 16,674				$ 14,775
Unamortized premium and (discount), net				(57)				(55)
Unamortized debt issuance costs				(114)				(108)
Total Long-term Debt				16,503				14,612
Less current portion of Long-term debt				551				1
Long-term Debt				15,952				14,611
Aggregate maturities of long-term debt (Details) [Abstract]
2022				551
2023				904
2024				428
2025				1,350
2026				116
Thereafter				$ 13,325
Senior Unsecured Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate				4.34%
Principal outstanding				$ 4,316				3,066
Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate				4.38%
Principal outstanding				$ 10,878				10,229
Junior Subordinated Notes [Member]
Debt Instrument [Line Items]
Weighted-Average Rate				7.25%
Principal outstanding				$ 480				480
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				$ 894
Exchangeable Senior Unsecured Notes
Debt Instrument [Line Items]
Weighted-Average Rate				2.88%
Principal outstanding				$ 1,000				1,000
PPL Capital Funding [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity				1,450
PPL Capital Funding [Member] | Senior Notes [Member] | Senior Notes due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount					$ 750
Stated interest rate					5.25%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Senior Long-Term Debt	$ 741
PPL Electric [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity				650
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				13,300				12,400
PPL Electric [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount							$ 650
Stated interest rate							4.85%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of First Mortgage Bond			$ 644
LGE [Member]
Aggregate maturities of long-term debt (Details) [Abstract]
Capacity				500
LGE [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien				$ 6,000				5,900
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				400
KU [Member] | First Mortgage Bonds [Member] | 2010 Mortgage Indenture [Member]
Long-term Debt (Numeric) [Abstract]
Aggregate carrying value of property subject to lien				$ 7,500				7,300
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
Rhode Island Energy | Senior Notes [Member] | Senior Notes due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount						$ 500
Stated interest rate						5.35%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of Senior Long-Term Debt		$ 496
PPL Electric Utilities Corp [Member]
Debt Instrument [Line Items]
Principal outstanding				5,299				4,649
Unamortized discount				(42)				(42)
Unamortized debt issuance costs				(43)				(40)
Total Long-term Debt				5,214				4,567
Less current portion of Long-term debt				0				0
Long-term Debt				5,214				4,567
Aggregate maturities of long-term debt (Details) [Abstract]
2022				0
2023				0
2024				108
2025				0
2026				116
Thereafter				5,075
Capacity				$ 650
PPL Electric Utilities Corp [Member] | Senior Secured Notes - First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate				4.64%
Principal outstanding				$ 5,299				4,649
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				13,300				12,400
PPL Electric Utilities Corp [Member] | First Mortgage Bonds [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount							$ 650
Stated interest rate							4.85%
Aggregate maturities of long-term debt (Details) [Abstract]
Proceeds from Issuance of First Mortgage Bond			$ 644
Louisville Gas And Electric Co [Member]
Debt Instrument [Line Items]
Principal outstanding				2,489				2,489
Unamortized discount				(4)				(4)
Unamortized debt issuance costs				(14)				(16)
Total Long-term Debt				2,471				2,469
Less current portion of Long-term debt				300				0
Long-term Debt				2,171				2,469
Aggregate maturities of long-term debt (Details) [Abstract]
2022				300
2023				90
2024				260
2025				0
2026				0
Thereafter				1,839
Capacity				$ 500
Louisville Gas And Electric Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate				4.01%
Principal outstanding				$ 2,489				2,489
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				$ 6,000				5,900
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				$ 538
Aggregate amount of tax-exempt revenue bonds in a variable rate mode				66
Kentucky Utilities Co [Member]
Debt Instrument [Line Items]
Principal outstanding				3,089				3,089
Debt Instrument, Unamortized Premium				4				5
Unamortized discount				(8)				(9)
Unamortized debt issuance costs				(19)				(21)
Total Long-term Debt				3,066				3,064
Less current portion of Long-term debt				250				0
Long-term Debt				2,816				3,064
Aggregate maturities of long-term debt (Details) [Abstract]
2022				250
2023				164
2024				60
2025				0
2026				0
Thereafter				2,615
Capacity				$ 400
Kentucky Utilities Co [Member] | First Mortgage Bonds [Member]
Debt Instrument [Line Items]
Weighted-Average Rate				4.22%
Principal outstanding				$ 3,089				3,089
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				$ 7,500				$ 7,300
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				$ 356
Aggregate amount of tax-exempt revenue bonds in a variable rate mode				$ 33

Financing Activities Financing

Financing Activities Financing Activities- Equity Securities (Details) - shares shares in Thousands		12 Months Ended
		Dec. 31, 2024	Dec. 31, 2022
Common Stock [Member]
Equity Programs [Line Items]
Common stock shares issued	[1]	202	123
[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		3 Months Ended	12 Months Ended
	Feb. 28, 2025	Nov. 30, 2023	Dec. 31, 2024	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)			$ 0.2575	$ 1.03	$ 0.960	$ 0.875
Annualized current quarterly common stock dividend (in dollars per share)		$ 1.03
Deferred Interest Payment				$ 0
Subsequent Event [Member]
Distributions [Line Items]
Current quarterly common stock dividend (in dollars per share)	$ 0.2725
Louisville Gas And Electric Co [Member]
Distributions [Line Items]
Restricted net assets at end of period			$ 1,500	1,500
Unrestricted assets at the end of period			1,800	$ 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			2,000	$ 2,000
Unrestricted assets at the end of period			$ 2,300	$ 2,300
Minimum adjusted equity to total capitalization in order to pay dividends				30%

Acquisitions, Development and_3

Acquisitions, Development and Divestitures - Acquisitions (Details) $ in Millions		1 Months Ended		3 Months Ended	4 Months Ended	6 Months Ended	7 Months Ended	12 Months Ended
	May 25, 2022 USD ($)	Dec. 31, 2022 USD ($) MW	Jun. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Sep. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)
Disclosure [Line Items]
Goodwill, Acquired During Period, After Remeasurement									$ 1,585
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-Term Debt			$ 1,500	$ 1,500		$ 1,500
Operating Revenues								$ 8,462	8,312	$ 7,902
Net income (loss)								888	740	756
Business Acquisition, Pro Forma Revenue								8,667
Business Acquisition, Pro Forma Net Income (Loss)								790
Business Combination, Integration Related Costs									223
Transition Service Agreement Expense								137	228	123
Goodwill								2,247	2,247
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)								0	0	42
Payments to Acquire Businesses, Gross						5,300
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, AR Reserve	60
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Current Assets, Receivables, Gross	255
Business Combination, Transaction Costs Expense									18
Business Combination, Integration Related Costs									223
Transition Service Agreement Expense								137	228	123
Corporate And Other [Member]
Disclosure [Line Items]
Goodwill, Acquired During Period, After Remeasurement									860
Operating Revenues								0	1	23
Net income (loss)								415	427	316
Goodwill, Measurement Period Adjustment								1
Goodwill		$ 861					$ 861	860	860	861
Rhode Island Regulated
Disclosure [Line Items]
Operating Revenues								2,024	1,851	1,038
Net income (loss)								(109)	(96)	44
Goodwill		$ 725					725	725	725	725
LGE [Member]
Disposal Group [Line Items]
Expected Capital Cost Of Expansion Project								1,000
CPCN NGCC Combustion Turbine Facilities, Power | MW		640
KU [Member]
Disposal Group [Line Items]
Expected Capital Cost Of Expansion Project								1,000
CPCN NGCC Combustion Turbine Facilities, Power | MW		640
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	3,992
Public Utilities, Customer Bill Credit Agreement, Total	50
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Regulatory Assets	393
Goodwill, Business Combination	1,585
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Other Noncurrent Assets	164
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Assets	6,134
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Assets	6,776
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	142
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities	2,281
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	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
Disposal Group [Line Items]
Accounts Receivable Forgiven, AR Reserve									23	23
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
Rhode Island Energy | Rhode Island Energy TSA
Disclosure [Line Items]
Other Nonrecurring (Income) Expense								307	262	181
Disposal Group [Line Items]
Other Nonrecurring (Income) Expense								307	262	181
Rhode Island Energy | Accrual for TSA Markup
Disclosure [Line Items]
Other Nonrecurring (Income) Expense								10	7	3
Disposal Group [Line Items]
Other Nonrecurring (Income) Expense								10	7	3
Rhode Island Energy | Accrual for RIAG Evaluation Fund
Disclosure [Line Items]
Other Nonrecurring (Income) Expense				2.5
Disposal Group [Line Items]
Other Nonrecurring (Income) Expense				$ 2.5
WPD [Member]
Disposal Group [Line Items]
Income tax related to Discontinued Operations								0	0	(42)
Transaction Costs | Additional Costs Related to Purchase, Agreed not to seek recovery
Disclosure [Line Items]
Business Combination, Separately Recognized Transactions, Expenses and Losses Recognized								$ 28
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, Not Discontinued Operations | Safari Holdings LLC, Consolidated
Disposal Group [Line Items]
Gain (loss) on disposition of business, net of tax									5	46
Loss on Sale									$ 6	60
Discontinued Operations, Held-for-sale | WPD [Member]
Disposal Group [Line Items]
Income tax related to Discontinued Operations										$ 42
Narragansett Electric
Disclosure [Line Items]
Business Combination, Consideration Transferred						$ 3,800

Acquisitions, Development and_4

Acquisitions, Development and Divestitures - Divestitures(Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
LGE [Member]
Disposal Group [Line Items]
Expected Capital Cost Of Expansion Project	$ 1,000
KU [Member]
Disposal Group [Line Items]
Expected Capital Cost Of Expansion Project	1,000
WPD [Member]
Disposal Group [Line Items]
Income tax related to Discontinued Operations	$ 0	$ 0	$ (42)
Discontinued Operations, Held-for-sale | WPD [Member]
Disposal Group [Line Items]
Income tax related to Discontinued Operations			$ 42

Leases - Lessee (Details)

Leases - Lessee (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Lease, Cost [Abstract]
Operating lease cost	$ 0	$ 26	$ 20
Short-term lease cost	0	6	6
Total lease cost	0	33	26
Operating cash flows from operating leases	0	25	26
Right-of-use asset obtained in exchange for new operating lease liabilities	0	47	15
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022	0
2023	0
2024	0
2025	0
2026	0
Thereafter	0
Total	$ 0
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate
Weighted-average remaining lease term (in years)
Current lease liabilities	$ 0
Non-current lease liabilities	0
Right-of-use assets	$ 0
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
Finance Lease, Right-of-Use Asset, Amortization	$ 0	1	0
Finance Lease, Interest Expense	0	0	0
Finance Lease, Interest Payment on Liability	0	0	0
Finance Lease, Principal Payments	0	1	0
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	0	7	0
Finance Lease, Liability, to be Paid, Year One	0
Finance Lease, Liability, to be Paid, Year Two	0
Finance Lease, Liability, to be Paid, Year Three	0
Finance Lease, Liability, to be Paid, Year Four	0
Finance Lease, Liability, to be Paid, Year Five	0
Finance Lease, Liability, to be Paid, after Year Five	0
Finance Lease, Liability, to be Paid	$ 0
Finance Lease, Weighted Average Discount Rate, Percent
Finance Lease, Weighted Average Remaining Lease Term
Finance Lease, Liability, Current	$ 0
Finance Lease, Liability, Noncurrent	0
Finance Lease, Right-of-Use Asset, before Accumulated Amortization	$ 0
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Regulated utility plant
Finance Lease, Liability, Current, Statement of Financial Position [Extensible Enumeration]	Other current liabilities
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible Enumeration]	Other deferred credits and noncurrent liabilities
Louisville Gas And Electric Co [Member]
Lease, Cost [Abstract]
Operating lease cost		5	6
Short-term lease cost		1	1
Total lease cost	0	6	7
Operating cash flows from operating leases		6	8
Right-of-use asset obtained in exchange for new operating lease liabilities		6	4
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022
2023
2024
2025
2026
Thereafter
Total	$ 0
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate
Weighted-average remaining lease term (in years)
Current lease liabilities
Non-current lease liabilities
Right-of-use assets
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		10	9
Short-term lease cost		1	2
Total lease cost	0	11	11
Operating cash flows from operating leases		9	12
Right-of-use asset obtained in exchange for new operating lease liabilities		$ 10	$ 5
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2022
2023
2024
2025
2026
Thereafter
Total	$ 0
Assets and Liabilities, Lessee [Abstract]
Weighted-average discount rate
Weighted-average remaining lease term (in years)
Current lease liabilities
Non-current lease liabilities
Right-of-use assets
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Lessor, Lease, Description [Line Items]
Lease income recognized	$ 0	$ 4	$ 6
Louisville Gas And Electric Co [Member]
Lessor, Lease, Description [Line Items]
Lease income recognized	0	0	2
Kentucky Utilities Co [Member]
Lessor, Lease, Description [Line Items]
Lease income recognized	$ 0	$ 0	$ 0

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, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan [Member]
Net Periodic Defined Benefit Costs (Credits): [ Abstract]
Service cost	$ 35	$ 34	$ 51
Interest cost	183	188	144
Expected return on plan assets	(299)	(309)	(276)
Amortization of:
Prior service cost (credit)	3	6	8
Actuarial (gain) loss	10	2	51
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	(68)	(79)	(22)
Settlements	0	0	23
Net Periodic Defined Benefit Costs (Credits)	(68)	(79)	1
Net (loss)/gain allocated at acquisition	0	0	33
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	(23)
Net (gain) loss	134	193	242
Prior service costs (credit)	(13)	2	0
Amortization of: [Abstract]
Prior service (cost) credit	(3)	(6)	(8)
Actuarial gain (loss)	(10)	(2)	(51)
Total recognized in OCI and regulatory assets/liabilities	108	187	193
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	40	108	194
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	25	52	142
Regulatory assets/liabilities	83	135	51
Total recognized in OCI and regulatory assets/liabilities	108	187	193
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	6	6	7
Interest cost	29	30	20
Expected return on plan assets	(30)	(30)	(28)
Amortization of:
Prior service cost (credit)	1	1	1
Actuarial (gain) loss	(5)	(5)	(5)
Net periodic defined benefit costs (credits) prior to settlements and termination benefits	1	2	(5)
Settlements	0	0	0
Net Periodic Defined Benefit Costs (Credits)	1	2	(5)
Net (loss)/gain allocated at acquisition	0	0	(49)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross: [Abstract]
Settlement	0	0	0
Net (gain) loss	1	(6)	0
Prior service costs (credit)	0	0	0
Amortization of: [Abstract]
Prior service (cost) credit	(1)	(1)	(1)
Actuarial gain (loss)	5	5	5
Total recognized in OCI and regulatory assets/liabilities	5	(2)	(45)
Total recognized in net periodic benefit costs, OCI and regulatory assets/liabilities	6	0	(50)
Other Changes in Plan Assets and Benefit Obligations Recognized in OCI and Regulatory Assets/Liabilities - Gross (Details) [Abstract]
OCI	2	0	13
Regulatory assets/liabilities	3	(2)	(58)
Total recognized in OCI and regulatory assets/liabilities	5	(2)	(45)
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Pension Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	5.93%	5.52%
Benefit obligations valuation rate of compensation increase	3.43%	3.43%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	5.52%	5.52%	3.35%
Net periodic benefit costs rate of compensation increase	3.43%	3.43%	3.74%
Net periodic benefit costs expected return on plan assets	8.25%	8.25%	7.25%
Assumed Health Care Cost Trend Rates (Details) [Abstract]
Health care cost trend rate assumed for next year, obligations	7%	6.25%	6.50%
Health care cost trend rate assumed for next year, cost	6.25%	6.50%	6.25%
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	2033	2029	2029
Year that the rate reaches the ultimate trend rate, cost	2029	2029	2027
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 3,454	$ 3,333
Service cost	35	34	$ 51
Interest cost	183	188	144
Participant contributions	0	0
Plan Amendments	(13)	3
Actuarial (gain) loss	(131)	179
Settlements	0	(3)
Gross benefits paid	(284)	(280)
Benefit Obligation, end of period	3,244	3,454	3,333
Change in Plan Assets [Roll Forward]
Balance at beginning of period	3,176	3,149
Actual return on plan assets	34	297
Employer contributions	10	13
Participant contributions	0	0
Settlements	0	(3)
Gross benefits paid	(284)	(280)
Balance at end of period	2,936	3,176	$ 3,149
Funded Status, end of period	(308)	(278)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	19	7
Current liability	(10)	(10)
Noncurrent liability	(317)	(275)
Net amount recognized, end of period	(308)	(278)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	(6)	11
Net actuarial (gain) loss	1,164	1,017
Total	1,158	1,028
Total accumulated benefit obligation for defined benefit pension plans	3,116	3,312
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	283	235
Regulatory assets/liabilities	875	793
Total	1,158	1,028
Pension Plans Where the Projected or Accumulated Benefit Obligation Exceed the Fair Value of Plan Assets (Details) [Abstract]
Projected benefit obligations	2,719	2,891
Fair value of plan assets where the projected benefit obligations exceed the value of plan assets	2,392	2,606
Accumulated benefit obligation	2,618	1,773
Fair value of plan assets where the accumulated benefit obligations exceed the value of plan assets	2,392	1,594
Pension Plan [Member] | U.S. [Member]
Change in Benefit Obligation [Roll Forward]
Federal subsidy	0	0
Change in Plan Assets [Roll Forward]
Transfer out	$ 0	$ 0
Other Postretirement Benefits Plan [Member]
Weighted Average Assumptions Used in the Valuation of the Benefit Obligations (Details) [Abstract]
Benefit obligations valuation discount rate	5.91%	5.54%
Benefit obligations valuation rate of compensation increase	3.44%	3.43%
Weighted Average Assumptions Used to Determine the Net Periodic Benefit Costs (Details) [Abstract]
Net periodic benefit costs discount rate	5.54%	5.54%	3.54%
Net periodic benefit costs rate of compensation increase	3.43%	3.43%	2.84%
Net periodic benefit costs expected return on plan assets	7.28%	7.38%	6.52%
Change in Benefit Obligation [Roll Forward]
Benefit Obligation, beginning of period	$ 538	$ 534
Service cost	6	6	$ 7
Interest cost	29	30	20
Participant contributions	8	9
Plan Amendments	0	0
Actuarial (gain) loss	(4)	18
Settlements	0	0
Gross benefits paid	(56)	(59)
Federal subsidy	2	0
Benefit Obligation, end of period	523	538	534
Change in Plan Assets [Roll Forward]
Balance at beginning of period	438	417
Actual return on plan assets	25	54
Employer contributions	14	16
Participant contributions	7	7
Transfer out	(13)	0
Settlements	0	0
Gross benefits paid	(54)	(56)
Balance at end of period	417	438	$ 417
Funded Status, end of period	(106)	(100)
Amounts recognized in the Balance Sheets consist of: [Abstract]
Noncurrent asset	8	10
Current liability	(13)	(14)
Noncurrent liability	(101)	(96)
Net amount recognized, end of period	(106)	(100)
Amounts recognized in AOCI and regulatory assets/liabilities (pre-tax): [Abstract]
Prior service cost (credit)	9	10
Net actuarial (gain) loss	(90)	(96)
Total	(81)	(86)
Changes in Plan Assets and Benefit Obligations Recognized in AOCI and Regulatory Assets/Liabilities by Type (Details) [Abstract]
AOCI	16	14
Regulatory assets/liabilities	(97)	(100)
Total	(81)	(86)
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	(83)	(65)
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)	(55)
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	29	34
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	(44)	(44)
Kentucky Utilities Co [Member] | Pension Plan [Member] | LKE Funded Status Allocation [Member]
Change in Plan Assets [Roll Forward]
Funded Status, end of period	46	51
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	$ (8)	$ (9)

Retirement and Postemployment_5

Retirement and Postemployment Benefits (Plan Assets and Expected Cash Flows) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Pension Plan [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	$ 2,936	$ 3,176
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,176	3,149
Balance at end of period	2,936	3,176
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	10	$ 13
Expected amount of benefit payments in the next period for non-qualified plans	10
Estimated Future Benefit Payments (Details) [Abstract]
2022	304
2023	297
2024	288
2025	282
2026	276
2027-2030	$ 1,298
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	$ 59
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	$ 2,936	$ 3,175
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,175
Balance at end of period	$ 2,936	$ 3,175
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	$ 59
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	$ 2,936	$ 3,175
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,175
Balance at end of period	2,936	3,175
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	424	421
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	421
Balance at end of period	424	421
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	424	421
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	421
Balance at end of period	424	421
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	824	1,012
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,012
Balance at end of period	824	1,012
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	824	1,012
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	1,012
Balance at end of period	824	1,012
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	19	10
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	10
Balance at end of period	19	10
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	19	10
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	10
Balance at end of period	19	10
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	212	226
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	212	226
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	212	226
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	212	226
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	461	542
Measured at fair value not using net asset value per share	63	36
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	461	542
Measured at fair value not using net asset value per share	63	36
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	63	36
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	63	36
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	376	431
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	376	431
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	461	528
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	461	528
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	150	159
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	150	159
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	149	159
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	149	159
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	1	0
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	1	0
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	867	915
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	867	915
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	848	906
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	848	906
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	19	9
Fair value at end of period	19	10
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	10	16
Purchases, sales and settlements	4	(8)
Balance at end of period	19	10
Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member] | U.S. [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		4
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	19	9
Fair value at end of period	19	10
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	10	16
Purchases, sales and settlements	4	(8)
Balance at end of period	19	10
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	7
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	13	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	13	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	13	13
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	13	13
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	1
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	1
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	72	61
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	72	61
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	2,948	3,315
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,315
Balance at end of period	2,948	3,315
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	2,948	3,315
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	3,315
Balance at end of period	2,948	3,315
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	114	105
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	114	105
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	181	192
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	181	192
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	(38)	93
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	(38)	93
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	(38)	93
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	(38)	93
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	102	(16)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(16)
Balance at end of period	102	(16)
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	102	(16)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(16)
Balance at end of period	102	(16)
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	(114)	(124)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(124)
Balance at end of period	(114)	(124)
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	(114)	(124)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(124)
Balance at end of period	(114)	(124)
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	16	13
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	$ 16	$ 13
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	55%	54%
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%	54%
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	30%	31%
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	30%	31%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	13%	12%
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%	12%
Pension Plan [Member] | Master Trust [Member] | Growth Portfolio [Member] | Alternative Investments [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	12%	11%
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	12%	11%
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	35%	36%
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	35%	36%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	8%	7%
Pension Plan [Member] | Master Trust [Member] | Immunizing Portfolio [Member] | Derivatives [Member] | LKE [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	8%	7%
Pension Plan [Member] | Master Trust [Member] | Liquidity Portfolio [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	2%	3%
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%	3%
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	$ 438
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	438	417
Balance at end of period	417	438
Defined Benefit Plan Estimated Future Employer Contributions (Numeric) [Abstract]
Employer contributions	14	16
Amount to be contributed to plan in the next fiscal year	13
Estimated Future Benefit Payments (Details) [Abstract]
2022	50
2023	49
2024	49
2025	48
2026	47
2027-2030	218
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	0
Other Postretirement Benefits Plan [Member] | Level 1 [Member]
Defined benefit plan fair value of plan assets (Details) [Abstract]
Fair value at end of period	163	166
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	166
Balance at end of period	163	166
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	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] | 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	6%	6%
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	$ 20
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	20
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%	46%
Target Allocations (Details ) [Abstract]
Target asset allocation	45%
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	$ 76
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	$ 78	$ 84
Other Postretirement Benefits Plan [Member] | Debt Securities [Member]
Actual Allocation by Plan Asset (Details) [Abstract]
Percentage of trust assets	49%	48%
Target Allocations (Details ) [Abstract]
Target asset allocation	49%
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	$ 312	$ 326
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	326
Balance at end of period	312	326
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	(9)	(12)
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	(12)
Balance at end of period	(9)	(12)
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	114	124
Change in Fair Value of Level 3 Plan Assets [Roll Forward]
Balance at beginning of period	124
Balance at end of period	114	124
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	70	72
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	70	72
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	74	74
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	74	74
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	$ 7
Louisville Gas And Electric Co [Member] | Pension Plan [Member] | Master Trust [Member] | Corporate Debt Securities [Member] | Level 3 [Member] | U.S. [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		$ 4

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, 2024	Dec. 31, 2023	Dec. 31, 2022
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 53	$ 48	$ 36
PPL Electric Utilities Corp [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	9	8	6
Louisville Gas And Electric Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	8	8	7
Kentucky Utilities Co [Member]
Defined Contribution Pension And Other Postretirement Plans [Line Items]
Employer contributions to deferred savings plans	$ 6	$ 6	$ 5

Jointly Owned Facilities (Detai

Jointly Owned Facilities (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Trimble County Unit 1 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75%	75%
Electric plant	$ 462	$ 464
Accumulated depreciation	124	110
Construction work in progress	$ 1	$ 0
Trimble County Unit 2 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	75%	75%
Electric plant	$ 1,549	$ 1,490
Accumulated depreciation	323	300
Construction work in progress	$ 10	$ 49
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	29	27
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	$ 52	$ 52
Accumulated depreciation	30	29
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	$ 462	$ 464
Accumulated depreciation	124	110
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	$ 472	$ 447
Accumulated depreciation	79	74
Construction work in progress	$ 5	$ 25
Louisville Gas And Electric Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	29%	29%
Electric plant	$ 37	$ 37
Accumulated depreciation	19	17
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	$ 82	$ 82
Accumulated depreciation	41	39
Construction work in progress	$ 1	$ 0
Louisville Gas And Electric Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	22%	22%
Electric plant	$ 137	$ 127
Accumulated depreciation	27	25
Construction work in progress	$ 0	$ 3
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	4	3
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	$ 3
Accumulated depreciation	0	0
Construction work in progress	$ 0	$ 0
Louisville Gas And Electric Co [Member] | Jointly Owned Mercer Solar
Jointly Owned Facilities [Line Items]
Ownership interest	37%	37%
Electric plant	$ 10	$ 7
Accumulated depreciation	0	0
Construction work in progress	$ 1	$ 0
Louisville Gas And Electric Co [Member] | Jointly Owned Mill Creek 5
Jointly Owned Facilities [Line Items]
Ownership interest	31%	31%
Electric plant	$ 0	$ 0
Accumulated depreciation	0	0
Construction work in progress	$ 74	$ 2
Louisville Gas And Electric Co [Member] | Jointly Owned Brown Wind
Jointly Owned Facilities [Line Items]
Ownership interest	36%	36%
Electric plant	$ 0	$ 0
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	$ 87
Accumulated depreciation	48	45
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	$ 46	$ 46
Accumulated depreciation	26	25
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	$ 1,077	$ 1,043
Accumulated depreciation	224	227
Construction work in progress	$ 5	$ 24
Kentucky Utilities Co [Member] | Trimble County Units 5 And 6 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	71%	71%
Electric plant	$ 87	$ 86
Accumulated depreciation	44	41
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	$ 136	$ 135
Accumulated depreciation	69	65
Construction work in progress	$ 1	$ 0
Kentucky Utilities Co [Member] | Cane Run Unit 7 [Member]
Jointly Owned Facilities [Line Items]
Ownership interest	78%	78%
Electric plant	$ 485	$ 449
Accumulated depreciation	95	90
Construction work in progress	$ 1	$ 10
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	6	5
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	$ 4
Accumulated depreciation	1	0
Construction work in progress	$ 0	$ 0
Kentucky Utilities Co [Member] | Jointly Owned Mercer Solar
Jointly Owned Facilities [Line Items]
Ownership interest	63%	63%
Electric plant	$ 16	$ 12
Accumulated depreciation	0	0
Construction work in progress	$ 2	$ 1
Kentucky Utilities Co [Member] | Jointly Owned Mill Creek 5
Jointly Owned Facilities [Line Items]
Ownership interest	69%	69%
Electric plant	$ 0	$ 0
Accumulated depreciation	0	0
Construction work in progress	$ 164	$ 3
Kentucky Utilities Co [Member] | Jointly Owned Brown Wind
Jointly Owned Facilities [Line Items]
Ownership interest	64%	64%
Electric plant	$ 1	$ 1
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
	Dec. 31, 2024 USD ($)	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Oct. 07, 2024 MW	Jul. 01, 2022 MW	Dec. 06, 2018 MW	Apr. 09, 2018 MW	Oct. 01, 2015 MW	Dec. 31, 2014 MW	May 01, 2012 MW	Jul. 01, 2011 MW	Jul. 01, 2010 MW	Jun. 30, 2010 MW
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							36.427
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
LTCS Renewable Energy Contract, Fourth Solicitation, Power | MW												32.1
Minimum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
ACES Renewable Energy Contracting Capacity Requirement | MW					200
RIE Solicitation of Renewable Contracting Capacity | MW				20
Maximum [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
RIE Solicitation of Renewable Contracting Capacity | MW				150
Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023	$ 36
2024	39
2025	39
2026	36
2027	36
Thereafter	256
Total	442
Purchases	30	$ 29	$ 30
Rhode Island Energy | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023	274
Thereafter	300
Total	936
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
2026-2027	240
2028-2029	122
Louisville Gas And Electric Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023	25
2024	27
2025	27
2026	25
2027	25
Thereafter	177
Total	306
Purchases	21	20	21
Kentucky Utilities Co [Member] | Power Purchase [Member]
Energy Purchase Commitments (Numeric) [Abstract]
2023	11
2024	12
2025	12
2026	11
2027	11
Thereafter	79
Total	136
Purchases	9	9	$ 9
PPL Electric Additional Sites [Member] | PPL Electric [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies	8	8
PPL Electric Additional Sites [Member] | PPL Electric Utilities Corp [Member]
Legal Matters - Cane Run Environmental Claims (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies	$ 8	$ 8

Commitments and Contingencies_3

Commitments and Contingencies (Environmental Matter and Other) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
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
Rhode Island Division Of Public Utilities And Carriers Amount To Be Refunded To The RIE Energy Efficiency Program	$ 11
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	98	$ 99
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	8	8
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Environmental Matters - Superfund And Other Remediation (Numeric) [Abstract]
Environmental site accrual	$ 8	$ 8

Commitments and Contingencies_4

Commitments and Contingencies (Guarantees and Other Assurances) (Details) - 12 months ended Dec. 31, 2024 £ 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	231
Indemnification Cap, Surrenders of Tax Losses | £		£ 50
Indemnification for Safari sale/leaseback	25
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	100
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	81
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	56
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	25
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	56
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	$ 25

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable from Affiliate	$ 222	$ 0
Financing Receivable, after Allowance for Credit Loss, Related Party, Name [Extensible Enumeration]	CEP Reserves, Inc.	CEP Reserves, Inc.
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 227	$ 222	$ 241
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	7	$ 0
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Accounts receivable from affiliates [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	4
PPL Electric Utilities Corp [Member] | PPL Services [Member] | Other Noncurrent Assets [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	3
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc.
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	$ 800
Louisville Gas And Electric Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable, Related Party [Extensible Enumeration]	Related Party	Affiliated Entity [Member]
Notes Payable with affiliates	$ 43	$ 0
Louisville Gas And Electric Co [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	66	42	13
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	682
Louisville Gas And Electric Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 105	$ 115	153
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable, Related Party [Extensible Enumeration]	Related Party	Affiliated Entity [Member]
Notes Payable with affiliates	$ 73	$ 0
Kentucky Utilities Co [Member] | PPL Services [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	65	48	14
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	437
Kentucky Utilities Co [Member] | LKS [Member]
Related Party Transactions [Line Items]
Related Party Transaction, Amounts of Transaction	$ 130	$ 150	$ 171

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Other Income [Line Items]
Defined benefit plans - non-service credits	$ 42	$ 40	$ 47
Interest Income (Expense), Nonoperating	33	32	4
Allowance for funds used during construction - equity component	47	30	22
Other Expense [Line Items]
Charitable contributions	(5)	(5)	(14)
Miscellaneous	(1)	(13)	(6)
Other Income (Expense) - net	114	(40)	54
Income (Expense) Related to Talen Litigation	(2)	(124)	1
PPL Electric Utilities Corp [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	17	20	15
Interest Income (Expense), Nonoperating	8	8	3
Allowance for funds used during construction - equity component	23	16	16
Other Expense [Line Items]
Charitable contributions	(4)	(3)	(3)
Miscellaneous	1	(2)	(1)
Other Income (Expense) - net	45	39	30
LOUISVILLE GAS And ELECTRIC CO [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	3	0	3
Allowance for funds used during construction - equity component	8	3	1
Other Expense [Line Items]
Charitable contributions	(1)	(1)	(1)
Miscellaneous	2	1	1
Other Income (Expense) - net	12	3	4
Kentucky Utilities Co [Member]
Other Income [Line Items]
Defined benefit plans - non-service credits	8	6	9
Allowance for funds used during construction - equity component	9	3	1
Other Expense [Line Items]
Charitable contributions	(1)	(1)	0
Miscellaneous	(1)	0	(2)
Other Income (Expense) - net	$ 15	$ 8	$ 8

Fair Value Measurements (Assets

Fair Value Measurements (Assets and Liabilities Measured on Recurring Basis Table) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Recurring [Member]
Price risk management liabilities:
Cash and cash equivalents	$ 306	$ 331
Restricted cash and cash equivalents	33	51
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	339	382
Money market fund	1	1
Commingled debt fund measured at NAV	10	9
Commingled equity fund measured at NAV	8	8
Total special use funds	19	18
Gas Purchase Contract, Fair Value Disclosure	9	1
Total Assets	367	401
Interest rate swaps	3	7
Gas contracts, Liability	13	60
Liability value	16	67
Recurring [Member] | PPL Electric Utilities Corp [Member]
Price risk management liabilities:
Cash and cash equivalents	24	51
Total Assets	24	51
Recurring [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Price risk management liabilities:
Cash and cash equivalents	8	18
Restricted cash and cash equivalents	16	26
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	24	44
Total Assets	24	44
Interest rate swaps	3	7
Liability value	3	7
Recurring [Member] | Kentucky Utilities Co [Member]
Price risk management liabilities:
Cash and cash equivalents	13	14
Restricted cash and cash equivalents	16	24
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	29	38
Total Assets	29	38
Recurring [Member] | Level 1 [Member]
Price risk management liabilities:
Cash and cash equivalents	306	331
Restricted cash and cash equivalents	33	51
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	339	382
Money market fund	1	1
Total special use funds	1	1
Gas Purchase Contract, Fair Value Disclosure	0	0
Total Assets	340	383
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	24	51
Total Assets	24	51
Recurring [Member] | Level 1 [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Price risk management liabilities:
Cash and cash equivalents	8	18
Restricted cash and cash equivalents	16	26
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	24	44
Total Assets	24	44
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	13	14
Restricted cash and cash equivalents	16	24
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	29	38
Total Assets	29	38
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	4	1
Total Assets	4	1
Interest rate swaps	3	7
Gas contracts, Liability	10	41
Liability value	13	48
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
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	0	0
Total Assets	0	0
Interest rate swaps	3	7
Liability value	3	7
Recurring [Member] | Level 2 [Member] | Kentucky Utilities Co [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
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	5	0
Total Assets	5	0
Interest rate swaps	0	0
Gas contracts, Liability	3	19
Liability value	3	19
Recurring [Member] | Level 3 [Member] | Gas Contracts
Price risk management liabilities:
Gas Contracts, Liability, Purchases	2
Gas Contracts, Liability, Settlements	19
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis with Unobservable Inputs	2	(19)
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
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	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
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash, Fair Value	0	0
Total Assets	0	0
Carrying Amount [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	16,503	14,612
Carrying Amount [Member] | PPL Electric Utilities Corp [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	5,214	4,567
Carrying Amount [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,471	2,469
Carrying Amount [Member] | Kentucky Utilities Co [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	3,066	3,064
Fair Value [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	15,562	14,031
Fair Value [Member] | PPL Electric Utilities Corp [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	4,862	4,475
Fair Value [Member] | LOUISVILLE GAS And ELECTRIC CO [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	2,295	2,369
Fair Value [Member] | Kentucky Utilities Co [Member]
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Long-term debt	$ 2,750	$ 2,861

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities (Intro) (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
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, 2024	Dec. 31, 2023	Dec. 31, 2022
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	49
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, 2024	Dec. 31, 2023
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	9	1
Liability value	16	67
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	7	1
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	7	1
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	2	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	2	0
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	10	52
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	1
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	10	51
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	6	15
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	3	6
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member] | Gas Contract
Fair Values by Balance Sheet Location [Abstract]
Liability value	3	9
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	3	7
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	0	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	0	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	3	6
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	$ 3	$ 6

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities (Gains and Losses) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Derivative Instruments Gain Loss [Line Items]
Interest Expense, Operating and Nonoperating	$ 738	$ 666	$ 513
Other Income (Expense) - net	114	(40)	54
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Income (Loss) from Discontinued Operations (net of income taxes)	0	0	42
Cash Flow Hedges [Member]
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) Reclassified from AOCI into Income	(3)	(3)	(3)
Cash Flow Hedges [Member] | Other Comprehensive Income [Member]
Derivative Instruments Gain Loss [Line Items]
Derivative Gain (Loss) Recognized in OCI	0	0	0
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	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)	(3)	(3)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	(3)	(3)	(3)
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	(40)	(20)	39
Gain (loss) recognized as regulatory liabilities/assets	59	1	50
Asset value	9	1
Liability value	16	67
Derivatives Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	7	1
Derivatives Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	10	52
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	2	0
Derivatives Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	6	15
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	$ 0	0	(2)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense, Operating and Nonoperating
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	0	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	3	6
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	4	0	11
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	7	1
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	10	51
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	2	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	3	9
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	48	9	39
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	7	(8)	0
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Energy Purchases
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(40)	(19)	41
Derivatives Not Designated As Hedging Instruments [Member] | Gas Contract | Other Income (Expense) - net
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	0	(1)	0
Louisville Gas And Electric Co [Member]
Derivative Instruments Gain Loss [Line Items]
Interest Expense, Operating and Nonoperating	105	102	89
Other Income (Expense) - net	12	3	4
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	3	7
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	0	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	3	6
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	$ 0	0	(2)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense, Operating and Nonoperating
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	0	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	3	6
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	4	0	11
Kentucky Utilities Co [Member]
Derivative Instruments Gain Loss [Line Items]
Other Income (Expense) - net	$ 15	$ 8	$ 8

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities (Offsetting Derivative Instruments and Credit Risk-Related Features) (Details) - USD ($) $ in Millions	Dec. 31, 2024	Dec. 31, 2023
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	$ 4
Derivative Net Liability Position Containing Credit Risk Related Contingency Features	3
Treasury Derivatives [Member]
Offsetting Assets And Liabilities [Line Items]
Gross assets	9	$ 1
Derivative instruments eligible for offset - assets	5	0
Cash collateral received eligible for offset - assets	0	0
Net assets	4	1
Gross liabilities	16	67
Derivative instruments eligible for offset - liabilities	5	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	11	67
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	3	7
Derivative instruments eligible for offset - liabilities	0	0
Cash collateral pledged eligible for offset - liabilities	0	0
Net liabilities	3	7
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	$ 2,247
Balance at end of period	2,247	$ 2,247
Goodwill, Period Increase (Decrease)	0	(1)
Goodwill		2,247	$ 2,248
Kentucky Regulated [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	662	662
Balance at end of period	662	662
Goodwill, Period Increase (Decrease)	0	0
Corporate And Other [Member]
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	860	861
Balance at end of period	860	860
Goodwill, Period Increase (Decrease)	0	(1)
Rhode Island Regulated
Changes in the Carrying Amount of Goodwill by Segment [Roll Forward]
Balance at beginning of period	725	725
Balance at end of period	725	725
Goodwill, Period Increase (Decrease)	$ 0	$ 0

Goodwill and Other Intangible_4

Goodwill and Other Intangible Assets (Other Intangibles - Finite-Lived) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Subject to amortization: [Abstract]
Gross carrying amount	$ 579	$ 553
Accumulated amortization	263	250
Contracts [Member]
Subject to amortization: [Abstract]
Gross carrying amount	125	125
Accumulated amortization	116	107
Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	432	411
Accumulated amortization	147	143
Licenses And Other [Member]
Subject to amortization: [Abstract]
Gross carrying amount	2	2
Accumulated amortization	0	0
Intangible assets with no regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	5	5	$ 5
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
Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	8	9	9
Forecasted amortization in 2021	8
Forecasted amortization in 2022	2
Forecasted amortization in 2023	0
Forecasted amortization in 2024	0
Forecasted amortization in 2025	0
Other Intangibles Excluding Emission Allowances And Or Renewable Energy Credits [Member]
Subject to amortization: [Abstract]
Amortization expense	13	14	14
Forecasted amortization in 2021	12
Forecasted amortization in 2022	6
Forecasted amortization in 2023	4
Forecasted amortization in 2024	4
Forecasted amortization in 2025	4
Renewable energy credit
Subject to amortization: [Abstract]
Gross carrying amount	20	15
Accumulated amortization	0	0
PPL Electric Utilities Corp [Member]
Subject to amortization: [Abstract]
Gross carrying amount	398	391
Accumulated amortization	142	139
PPL Electric Utilities Corp [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	396	389
Accumulated amortization	141	138
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	81	75
Louisville Gas And Electric Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	7	7
Accumulated amortization	2	2
Louisville Gas And Electric Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	86	86
Accumulated amortization	79	73
Louisville Gas And Electric Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	6	6	6
Forecasted amortization in 2021	6
Forecasted amortization in 2022	1
Forecasted amortization in 2023	0
Forecasted amortization in 2024	0
Forecasted amortization in 2025	0
Kentucky Utilities Co [Member]
Subject to amortization: [Abstract]
Gross carrying amount	68	56
Accumulated amortization	40	37
Kentucky Utilities Co [Member] | Land Rights And Easements [Member]
Subject to amortization: [Abstract]
Gross carrying amount	29	17
Accumulated amortization	4	4
Kentucky Utilities Co [Member] | OVEC power purchase agreement [Member]
Subject to amortization: [Abstract]
Gross carrying amount	39	39
Accumulated amortization	36	33
Kentucky Utilities Co [Member] | Intangible assets with regulatory offset [Member]
Subject to amortization: [Abstract]
Amortization expense	2	$ 3	$ 3
Forecasted amortization in 2021	2
Forecasted amortization in 2022	1
Forecasted amortization in 2023	0
Forecasted amortization in 2024	0
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, 2024	Dec. 31, 2023	Dec. 31, 2022
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	$ 18	$ 18
Gross carrying amount - other intangible assets	597	571
Intangible assets with no regulatory offset [Member]
Not subject to amortization due to indefinite life: [Line Items]
Amortization expense	5	5	$ 5
Land Rights and Easements [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount	18	18
PPL Electric Utilities Corp [Member]
Not subject to amortization due to indefinite life: [Line Items]
Gross carrying amount - other intangible assets	416	408
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	$ 18	$ 17

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	$ 158	$ 177
Accretion	8	9
Obligations incurred	9	2
Changes in estimated cash flow or settlement date	4	15
Obligations settled	(24)	(39)
Other	2	(6)
Balance at End of Period	157	158
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	85	86
Accretion	4	4
Obligations incurred	3	1
Changes in estimated cash flow or settlement date	3	11
Obligations settled	(11)	(11)
Other	0	(6)
Balance at End of Period	84	85
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Rollforward]
Balance at Beginning of Period	66	82
Accretion	4	5
Obligations incurred	6	1
Changes in estimated cash flow or settlement date	1	6
Obligations settled	(13)	(28)
Other		0
Balance at End of Period	$ 64	$ 66

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) (After-tax Changes by Component) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	$ (163)	$ (124)	$ (157)
Amounts arising during the year	(21)	(40)	12
Reclassifications from AOCI	0	1	21
Net OCI during the year	(21)	(39)	33
Balance at end of year	(184)	(163)	(124)
Foreign Currency Translation Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	0	0	0
Amounts arising during the year	0	0	0
Reclassifications from AOCI	0	0	0
Net OCI during the year	0	0	0
Balance at end of year	0	0	0
Qualifying Derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	6	3	1
Amounts arising during the year	0	0	0
Reclassifications from AOCI	3	3	2
Net OCI during the year	3	3	2
Balance at end of year	9	6	3
Equity Investees AOCI [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	3	2	0
Amounts arising during the year	1	1	2
Reclassifications from AOCI	0	0	0
Net OCI during the year	1	1	2
Balance at end of year	4	3	2
Prior Service Costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(4)	(5)	(6)
Amounts arising during the year	0	0	(1)
Reclassifications from AOCI	1	1	2
Net OCI during the year	1	1	1
Balance at end of year	(3)	(4)	(5)
Defined Benefit Plans Actuarial Gain (Loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of year	(168)	(124)	(152)
Amounts arising during the year	(22)	(41)	11
Reclassifications from AOCI	(4)	(3)	17
Net OCI during the year	(26)	(44)	28
Balance at end of year	$ (194)	$ (168)	$ (124)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) (Income (Expense) Effect of Reclassifications) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2024	Dec. 31, 2023	Dec. 31, 2022
Affected Line Item on the Statements of Income
Interest Expense, Operating and Nonoperating	$ (738)	$ (666)	$ (513)
Other Income (Expense) - net	114	(40)	54
Total Pre-tax	1,116	924	915
Income Taxes	(228)	(184)	(201)
Income (Loss) from Discontinued Operations (net of income taxes)	0	0	42
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total After-Tax	0	(1)	(21)
Qualifying Derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	(3)	(3)	(3)
Income Taxes	0	0	1
Total After-Tax	(3)	(3)	(2)
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, Operating and Nonoperating	(3)	(3)	(3)
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income
Total Pre-tax	3	1	(27)
Income Taxes	0	1	8
Total After-Tax	3	2	(19)
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	(1)	(2)	(3)
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	$ 4	$ 3	$ (24)

New Accounting Guidance Pendi_2

New Accounting Guidance Pending Adoption New Accounting Guidance Pending Adoption (Details) $ in Millions	Dec. 31, 2024 USD ($)
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset	$ 0
Current lease liabilities	0
Non-current lease liabilities	0
Louisville Gas And Electric Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset
Current lease liabilities
Non-current lease liabilities
Kentucky Utilities Co [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Right of Use Asset
Current lease liabilities
Non-current lease liabilities