Louisville Gas & Electric 10-Q 1 Nov 24 2022 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2024	Oct. 28, 2024
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-11459
Entity Incorporation, State or 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
Document Type	10-Q
Document Period End Date	Sep. 30, 2024
Amendment Flag	false
Entity Registrant Name	PPL Corporation
Entity Tax Identification Number	23-2758192
Entity Central Index Key	0000922224
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		737,970,005
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q3
Document Quarterly Report	true
Document Transition Report	false
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
2007 Series A Junior Subordinated Notes 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
PPL Electric Utilities Corp [Member]
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-905
Entity Incorporation, State or 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
Amendment Flag	false
Entity Registrant Name	PPL Electric Utilities Corporation
Entity Tax Identification Number	23-0959590
Entity Central Index Key	0000317187
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		66,368,056
Louisville Gas And Electric Co [Member]
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-2893
Entity Incorporation, State or 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
Amendment Flag	false
Entity Registrant Name	Louisville Gas and Electric Company
Entity Tax Identification Number	61-0264150
Entity Central Index Key	0000060549
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		21,294,223
Kentucky Utilities Co [Member]
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-3464
Entity Incorporation, State or Country Code	KY
Entity Incorporation, State or Country Code	VA
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
Amendment Flag	false
Entity Registrant Name	Kentucky Utilities Company
Entity Tax Identification Number	61-0247570
Entity Central Index Key	0000055387
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		37,817,878

CONDENSED CONSOLIDATED STATEMEN

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (Unaudited) - USD ($) shares in Thousands, $ in Millions		3 Months Ended			9 Months Ended
		Sep. 30, 2024		Sep. 30, 2023	Sep. 30, 2024		Sep. 30, 2023
Operating Revenues
Operating Revenues		$ 2,066		$ 2,043	$ 6,251		$ 6,281
Operation
Fuel		207		199	597		567
Energy purchases		338		356	1,133		1,430
Other operation and maintenance		681		637	1,930		1,805
Depreciation		322		314	957		940
Taxes, other than income		90		100	271		299
Total Operating Expenses		1,638		1,606	4,888		5,041
Operating Income		428		437	1,363		1,240
Other Income (Expense) - net		32		16	86		51
Interest Expense		188		165	549		494
Income Taxes		58		58	189		170
Income from continuing operations after income taxes					711
Net Income (Loss)		$ 214		$ 230	$ 711		$ 627
Net Income:
Diluted (in dollars per share)		$ 0.29		$ 0.31	$ 0.96		$ 0.85
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		737,773		737,107	737,678		737,005
Diluted (in shares)		739,965		738,184	739,450		738,021
Income from Continuing Operations Before Income Taxes		$ 272		$ 288	$ 900		$ 797
Income (Loss) from Continuing Operations After Income Taxes, Basic		$ 0.29		$ 0.31	$ 0.96		$ 0.85
Income (Loss) from Continuing Operations after income taxes, Diluted		$ 0.29		$ 0.31	$ 0.96		$ 0.85
Rhode Island Regulated
Operating Revenues
Operating Revenues		$ 455		$ 413	$ 1,393		$ 1,355
Operation
Net Income (Loss)		14		6	90		70
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		716		737	2,159		2,295
Operation
Energy purchases		177		226	544		788
Other operation and maintenance		176		151	511		454
Depreciation		101		99	300		297
Taxes, other than income		32		36	98		110
Total Operating Expenses		486		512	1,453		1,649
Operating Income		230		225	706		646
Other Income (Expense) - net		13		8	33		29
Interest Expense		61		54	184		165
Income Taxes		47		43	141		126
Net Income (Loss)	[1]	142		136	441		384
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		189		179	582		510
PPL Electric Utilities Corp [Member] | Related Party
Operation
Interest Income from affiliate		7		0	27		0
Louisville Gas And Electric Co [Member]
Operating Revenues
Operating Revenues		397		398	1,239		1,227
Operation
Fuel		75		70	228		217
Energy purchases		19		17	105		123
Energy purchases from affiliate		11		8	19		11
Other operation and maintenance		84		91	259		275
Depreciation		76		76	229		227
Taxes, other than income		13		12	38		36
Total Operating Expenses		278		274	878		889
Operating Income		119		124	361		338
Other Income (Expense) - net		3		0	9		2
Interest Expense		26		25	78		76
Income Taxes		20		21	61		55
Net Income (Loss)		77	[2]	79	232	[2]	210
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		97		100	293		265
Louisville Gas And Electric Co [Member] | Related Party
Operating Revenues
Retail and wholesale		1		2	20		23
Operation
Interest Income from affiliate		1		1	1		1
Louisville Gas And Electric Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		396		396	1,219		1,204
Kentucky Utilities Co [Member]
Operating Revenues
Operating Revenues		509		505	1,498		1,439
Operation
Fuel		131		129	369		350
Energy purchases		7		6	19		18
Energy purchases from affiliate		1		2	20		23
Other operation and maintenance		103		101	306		327
Depreciation		102		98	302		294
Taxes, other than income		12		12	36		34
Total Operating Expenses		356		348	1,052		1,046
Operating Income		153		157	446		393
Other Income (Expense) - net		4		1	10		6
Interest Expense					102		99
Income Taxes		24		24	70		59
Net Income (Loss)	[3]	98		101	283		240
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		122		125	353		299
Kentucky Utilities Co [Member] | Related Party
Operating Revenues
Retail and wholesale		11		8	19		11
Operation
Interest Expense		0		0	1		1
Kentucky Utilities Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		498		497	$ 1,479		$ 1,428
Operation
Interest Expense		$ 35		$ 33
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Net income (loss)	$ 214	$ 230	$ 711	$ 627
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investees' other comprehensive income (loss), net of tax	0	0	1	1
Other Comprehensive (Income) Loss, Defined Benefit Plan, before Reclassification Adjustment, after Tax [Abstract]
Defined benefit plan, Net actuarial gain (loss), amounts arising during the period, net of tax	(4)	(6)	(2)	(21)
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	2	1	3	2
Other Comprehensive (Income) Loss, Defined Benefit Plans, after Reclassification Adjustment, after Tax [Abstract]
Defined benefit plans, Prior service costs, net of tax	0	0	0	1
Defined benefit plans, Net actuarial (gain) loss, net of tax	(1)	0	(2)	(1)
Total other comprehensive income (loss)	(3)	(5)	0	(18)
Comprehensive income (loss)	$ 211	$ 225	$ 711	$ 609

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Tax effect of net actuarial (gain) loss arising during period	$ 1	$ 2	$ 0	$ (7)
Tax effect of qualifying derivatives reclassified from AOCI	1	0	0	(1)
Tax effect of prior service costs reclassified from AOCI	0	0	0	0
Tax effect of net actuarial (gain) loss reclassified from AOCI	0	(1)	1	0
Tax effect of equity investee's other comprehensive income (loss)	$ 0	$ 0	$ 0	$ 0

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2024		Sep. 30, 2023
Cash Flows from Operating Activities
Net income (loss)		$ 711		$ 627
Income from continuing operations (net of income taxes)		711
Depreciation		957		940
Amortization		61		61
Defined benefit plans - (income) expense		(52)		(55)
Deferred income taxes and investment tax credits		147		142
Other		13		(1)
Change in current assets and current liabilities
Accounts receivable		259		(37)
Accounts payable		(236)		(129)
Unbilled revenues		109		224
Fuel, materials and supplies		(9)		(43)
Prepayments		(75)		(44)
Taxes payable		(8)		(15)
Regulatory assets and liabilities, net		(54)		(27)
Accrued interest		104		123
Other		(78)		(2)
Other operating activities
Defined benefit plans - funding		(10)		(14)
Other assets		(66)		(58)
Other liabilities		56		(44)
Net cash provided by operating activities		1,829		1,648
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,945)		(1,741)
Other investing activities		1		2
Net cash used in investing activities		(1,944)		(1,739)
Cash Flows from Financing Activities
Issuance of long-term debt		1,894		3,127
Retirement of long-term debt		0		(1,763)
Payment of common stock dividends		(557)		(526)
Net increase (decrease) in short-term debt		(992)		(698)
Other financing activities		(29)		(52)
Net cash provided by financing activities		316		88
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		201		(3)
Cash and Cash Equivalents at Beginning of Period		331
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		382		357
Cash and Cash Equivalents at End of Period		542
Cash, Cash Equivalents and Restricted Cash at End of Period		583		354
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		281		200
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	441		384
Depreciation		300		297
Amortization		35		31
Defined benefit plans - (income) expense		(30)		(32)
Deferred income taxes and investment tax credits		91		59
Other		(9)		(19)
Change in current assets and current liabilities
Accounts receivable		67		(104)
Accounts payable		(63)		(56)
Unbilled revenues		50		110
Fuel, materials and supplies		(16)		(33)
Prepayments		(64)		(22)
Taxes payable		(36)		(24)
Regulatory assets and liabilities, net		(77)		(41)
Accrued interest		32		50
Other		(4)		(5)
Other operating activities
Defined benefit plans - funding		(2)		(5)
Other assets		(24)		(2)
Other liabilities		(2)		1
Net cash provided by operating activities		689		589
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(820)		(653)
Expenditures for intangible assets		(6)		(4)
Notes receivable from affiliates		(418)		0
Other investing activities		4		2
Net cash used in investing activities		(1,240)		(655)
Cash Flows from Financing Activities
Issuance of long-term debt		649		1,329
Retirement of long-term debt		0		(1,150)
Payment of common stock dividends to parent		(283)		(235)
Net increase (decrease) in short-term debt		(509)		42
Contributions from parent		685		200
Return of capital to parent		0		(75)
Debt Issuance Costs		(7)		(14)
Net cash provided by financing activities		535		97
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(16)		31
Cash and Cash Equivalents at Beginning of Period		51
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51		25
Cash and Cash Equivalents at End of Period		35
Cash, Cash Equivalents and Restricted Cash at End of Period		35		56
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		168		119
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)		232	[2]	210
Depreciation		229		227
Amortization		10		9
Deferred income taxes and investment tax credits		3		(3)
Other		(3)		(7)
Change in current assets and current liabilities
Accounts receivable		(13)		37
Accounts receivable from affiliates		0		17
Accounts payable		0		(51)
Increase (Decrease) in Accounts Payable, Related Parties		(3)		(9)
Unbilled revenues		21		43
Fuel, materials and supplies		(2)		25
Taxes payable		(1)		(4)
Regulatory assets and liabilities, net		4		34
Accrued interest		22		29
Other		(20)		(3)
Other operating activities
Defined benefit plans - funding		(1)		(1)
Expenditures for asset retirement obligations		(8)		(9)
Other assets		(12)		(19)
Other liabilities		(2)		1
Net cash provided by operating activities		456		526
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(327)		(277)
Net cash used in investing activities		(327)		(277)
Cash Flows from Financing Activities
Issuance of long-term debt		0		399
Retirement of long-term debt		0		(300)
Increase Decrease In Notes Payable To Affiliates		34		6
Payment of common stock dividends to parent		(138)		(115)
Net increase (decrease) in short-term debt		0		(179)
Contributions from parent		37		20
Return of capital to parent		(76)		(161)
Other financing activities		0		(4)
Net cash provided by financing activities		(143)		(334)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(14)		(85)
Cash and Cash Equivalents at Beginning of Period		18
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		44		93
Cash and Cash Equivalents at End of Period		10
Cash, Cash Equivalents and Restricted Cash at End of Period		30		8
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		43		30
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	283		240
Depreciation		302		294
Amortization		14		14
Defined benefit plans - (income) expense		(8)		(4)
Deferred income taxes and investment tax credits		(12)		(7)
Other		(2)		0
Change in current assets and current liabilities
Accounts receivable		(25)		10
Accounts receivable from affiliates		(2)		0
Accounts payable		(3)		(31)
Increase (Decrease) in Accounts Payable, Related Parties		7		(27)
Unbilled revenues		9		28
Fuel, materials and supplies		19		(8)
Taxes payable		7		8
Regulatory assets and liabilities, net		27		30
Accrued interest		31		37
Other		(6)		(2)
Other operating activities
Defined benefit plans - funding		(1)		(1)
Expenditures for asset retirement obligations		(7)		(17)
Other assets		(6)		(22)
Other liabilities		(15)		(2)
Net cash provided by operating activities		612		540
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(463)		(430)
Other investing activities		0		5
Net cash used in investing activities		(463)		(425)
Cash Flows from Financing Activities
Issuance of long-term debt		0		399
Retirement of long-term debt		0		(313)
Increase Decrease In Notes Payable To Affiliates		128		21
Payment of common stock dividends to parent		(167)		(125)
Net increase (decrease) in short-term debt		(93)		(76)
Contributions from parent		84		54
Return of capital to parent		(103)		(84)
Other financing activities		0		(4)
Net cash provided by financing activities		(151)		(128)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(2)		(13)
Cash and Cash Equivalents at Beginning of Period		14
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		38		21
Cash and Cash Equivalents at End of Period		16
Cash, Cash Equivalents and Restricted Cash at End of Period		36		8
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		$ 54		$ 45
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Sep. 30, 2024	Dec. 31, 2023
Assets, Current [Abstract]
Cash and cash equivalents		$ 542	$ 331
Accounts receivable (less reserve:)
Customer		939	950
Other		61	271
Unbilled revenues		319	428
Fuel, materials and supplies		517	505
Prepayments		179	103
Regulatory Assets, Current		342	293
Other current assets		75	51
Total Current Assets		2,974	2,932
Property, Plant and Equipment
Regulated utility plant		40,097	38,608
Less:  accumulated depreciation - regulated utility plant		9,647	9,156
Regulated utility plant, net		30,450	29,452
Non-regulated property, plant and equipment		76	72
Less: accumulated depreciation - non-regulated property, plant and equipment		28	23
Non-regulated property, plant and equipment, net		48	49
Construction work in progress		2,129	1,917
Property, Plant and Equipment, net		32,627	31,418
Other Noncurrent Assets
Regulatory assets		1,894	1,874
Goodwill		2,247	2,247
Other intangibles		314	306
Other noncurrent assets		416	459
Assets, Noncurrent		4,871	4,886
Total Assets		40,472	39,236
Current Liabilities
Short-term debt		0	992
Long-term debt due within one year		1	1
Accounts payable		920	1,104
Taxes		122	130
Interest		228	124
Dividends		186	173
Regulatory liabilities		246	225
Other current liabilities		603	591
Liabilities, Current, Total		2,306	3,340
Long-term Debt, Unclassified [Abstract]
Long-term Debt		16,499	14,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,305	3,105
Investment tax credits		112	114
Accrued pension obligations		218	275
Asset retirement obligations		139	133
Regulatory liabilities		3,371	3,340
Other deferred credits and noncurrent liabilities		430	385
Total Deferred Credits and Other Noncurrent Liabilities		7,575	7,352
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,328	12,326
Treasury Stock		(929)	(948)
Earnings reinvested		2,848	2,710
Accumulated other comprehensive loss		(163)	(163)
Total Equity		14,092	13,933
Total Liabilities and Equity		40,472	39,236
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		35	51
Accounts receivable (less reserve:)
Other		8	8
Unbilled revenues		99	149
Notes Receivable from affiliates		418	0
Fuel, materials and supplies		115	99
Prepayments		108	44
Regulatory Assets, Current		117	57
Other current assets		29	17
Total Current Assets		1,304	869
Property, Plant and Equipment
Regulated utility plant		16,193	15,575
Less:  accumulated depreciation - regulated utility plant		3,994	3,822
Regulated utility plant, net		12,199	11,753
Construction work in progress		823	680
Property, Plant and Equipment, net		13,022	12,433
Other Noncurrent Assets
Regulatory assets		622	598
Other intangibles		272	269
Other noncurrent assets		108	125
Assets, Noncurrent		1,002	992
Total Assets		15,328	14,294
Current Liabilities
Short-term debt		0	509
Taxes		15	51
Interest		75	43
Regulatory liabilities		69	91
Other current liabilities		113	100
Liabilities, Current, Total		749	1,292
Long-term Debt, Unclassified [Abstract]
Long-term Debt		5,213	4,567
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,677	1,573
Regulatory liabilities		844	836
Other deferred credits and noncurrent liabilities		99	123
Total Deferred Credits and Other Noncurrent Liabilities		2,620	2,532
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,725	4,040
Earnings reinvested		1,657	1,499
Total Equity		6,746	5,903
Total Liabilities and Equity		$ 15,328	$ 14,294
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]		CEP Reserves, Inc	CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | Related Party
Accounts receivable (less reserve:)
Customer		$ 15	$ 10
Notes Receivable from affiliates		418	0
Current Liabilities
Accounts payable		35	44
PPL Electric Utilities Corp [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		360	434
Current Liabilities
Accounts payable		442	454
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		10	18
Accounts receivable (less reserve:)
Other		24	17
Unbilled revenues		67	88
Fuel, materials and supplies		145	143
Prepayments		14	11
Regulatory Assets, Current		5	7
Other current assets		7	0
Total Current Assets		423	429
Property, Plant and Equipment
Regulated utility plant		7,826	7,669
Less:  accumulated depreciation - regulated utility plant		1,683	1,549
Regulated utility plant, net		6,143	6,120
Construction work in progress		423	312
Property, Plant and Equipment, net		6,566	6,432
Other Noncurrent Assets
Regulatory assets		389	395
Goodwill		389	389
Other intangibles		14	18
Other noncurrent assets		97	90
Assets, Noncurrent		889	892
Total Assets		7,878	7,753
Current Liabilities
Short-term debt		$ 0	$ 0
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Notes Payable to affiliates		$ 34	$ 0
Taxes		40	41
Price risk management liabilities current		1	1
Interest		43	21
Current Customer Deposits		35	34
Regulatory liabilities		18	16
Asset Retirement Obligation, Current		11	13
Other current liabilities		38	47
Liabilities, Current, Total		393	337
Long-term Debt, Unclassified [Abstract]
Long-term Debt		2,470	2,469
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		794	776
Investment tax credits		30	31
Asset retirement obligations		73	72
Regulatory liabilities		821	827
Price risk management liabilities		6	6
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		1,954	1,993
Earnings reinvested		849	755
Total Equity		3,227	3,172
Total Liabilities and Equity		7,878	7,753
Louisville Gas And Electric Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		29	29
Current Liabilities
Accounts payable		46	49
Louisville Gas And Electric Co [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		122	116
Current Liabilities
Accounts payable		127	115
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		16	14
Accounts receivable (less reserve:)
Customer		161	143
Other		13	12
Unbilled revenues		88	97
Fuel, materials and supplies		168	185
Prepayments		16	13
Regulatory Assets, Current		1	3
Other current assets		10	1
Total Current Assets		475	468
Property, Plant and Equipment
Regulated utility plant		10,369	9,896
Less:  accumulated depreciation - regulated utility plant		2,647	2,476
Regulated utility plant, net		7,722	7,420
Construction work in progress		508	604
Property, Plant and Equipment, net		8,230	8,024
Other Noncurrent Assets
Regulatory assets		438	439
Goodwill		607	607
Other intangibles		29	19
Other noncurrent assets		160	157
Assets, Noncurrent		1,234	1,222
Total Assets		9,939	9,714
Current Liabilities
Short-term debt		$ 0	$ 93
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Notes Payable to affiliates		$ 128	$ 0
Taxes		39	32
Interest		55	24
Current Customer Deposits		39	35
Regulatory liabilities		26	1
Asset Retirement Obligation, Current		10	13
Other current liabilities		59	52
Liabilities, Current, Total		519	402
Long-term Debt, Unclassified [Abstract]
Long-term Debt		3,065	3,064
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		921	912
Investment tax credits		82	83
Asset retirement obligations		56	53
Regulatory liabilities		1,014	1,018
Other deferred credits and noncurrent liabilities		33	30
Total Deferred Credits and Other Noncurrent Liabilities		2,106	2,096
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		3,014	3,033
Earnings reinvested		927	811
Total Equity		4,249	4,152
Total Liabilities and Equity		9,939	9,714
Kentucky Utilities Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		2	0
Current Liabilities
Accounts payable		78	72
Kentucky Utilities Co [Member] | Nonrelated Party
Current Liabilities
Accounts payable		$ 85	$ 80
[1] 1,560,000 shares authorized, 770,015 shares issued and 737,778 shares outstanding at September 30, 2024. 1,560,000 shares authorized, 770,013 shares issued and 737,130 shares outstanding at December 31, 2023. 170,000 shares authorized; 66,368 shares issued and outstanding at September 30, 2024 and December 31, 2023. 75,000 shares authorized; 21,294 shares issued and outstanding at September 30, 2024 and December 31, 2023. 80,000 shares authorized; 37,818 shares issued and outstanding at September 30, 2024 and December 31, 2023.

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 137	$ 123
Unbilled revenues, reserve	3	4
Reserve for accounts receivable (noncurrent)	$ 2	$ 2
Equity
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock shares authorized (in shares)	1,560,000	1,560,000
Common stock shares issued (in shares)	770,015	770,013
Common stock shares outstanding (in shares)	737,778	737,130
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 40	$ 46
Unbilled revenues, reserve	1	2
Reserve for accounts receivable (noncurrent)	$ 2	$ 2
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	170,000	170,000
Common stock shares issued (in shares)	66,368	66,368
Common stock shares outstanding (in shares)	66,368	66,368
Louisville Gas And Electric Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 4	$ 6
Unbilled revenues, reserve	$ 0	$ 0
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	75,000	75,000
Common stock shares issued (in shares)	21,294	21,294
Common stock shares outstanding (in shares)	21,294	21,294
Kentucky Utilities Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 2	$ 2
Unbilled revenues, reserve	$ 0	$ 0
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	80,000	80,000
Common stock shares issued (in shares)	37,818	37,818
Common stock shares outstanding (in shares)	37,818	37,818

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total		Common Stock [Member]		Additional Paid-in Capital [Member]	Earnings Reinvested [Member]		Accumulated Other Comprehensive Loss [Member]	Treasury Stock, Common	Noncontrolling Interest	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member] Common Stock [Member]		PPL Electric Utilities Corp [Member] Additional Paid-in Capital [Member]	PPL Electric Utilities Corp [Member] Earnings Reinvested [Member]	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 [Member]	Louisville Gas And Electric Co [Member] Earnings Reinvested [Member]	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member] Common Stock [Member]		Kentucky Utilities Co [Member] Additional Paid-in Capital [Member]	Kentucky Utilities Co [Member] Earnings Reinvested [Member]
Total Equity	$ 13,918		$ 8		$ 12,317	$ 2,681		$ (124)	$ (967)	$ 3	$ 5,751		$ 364		$ 4,084	$ 1,303	$ 3,166		$ 424		$ 2,087	$ 655	$ 4,038		$ 308		$ 3,041	$ 689
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.7200
Balance at beginning of period - shares at Dec. 31, 2022			736,487	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 22				3				$ 19
Stock Issued During Period, Shares, Treasury Stock Reissued									637
Stock-based compensation	(1)				(1)
Net income (loss)	627					627					384	[5]				384	210					210	240	[6]				240
Capital contributions from parent											200				200		20				20		54				54
Dividends and dividend equivalents	(533)	[7]				(533)	[7]									(235)						(115)						(125)
Dividends declared											(235)						(115)						(125)
Other comprehensive income (loss)	(18)							(18)
Balance at end of period - shares at Sep. 30, 2023			737,124	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Return of Capital to Parent											(75)				(75)		(161)				(161)		(84)				(84)
Noncontrolling Interest, Decrease from Redemptions or Purchase of Interests	(3)
Total Equity	$ 13,959		$ 8		12,316	2,721		(137)	$ (949)	0	6,011		$ 364		4,259	1,388	3,111		$ 424		1,987	700	4,085		$ 308		3,041	736
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2400
Balance at beginning of period - shares at Jun. 30, 2023			737,086										66,368	[2]					21,294	[3]					37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 1								$ 1
Stock Issued During Period, Shares, Treasury Stock Reissued									38
Stock-based compensation	3				3
Net income (loss)	230					230					136	[5]				136	79					79	101	[6]				101
Dividends and dividend equivalents	(176)					(176)
Dividends declared											(72)					(72)	(29)					(29)	(33)					(33)
Other comprehensive income (loss)	(5)							(5)
Balance at end of period - shares at Sep. 30, 2023			737,124	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Return of Capital to Parent											(50)				(50)		(41)				(41)		(30)				(30)
Total Equity	14,012		$ 8		12,319	2,775		(142)	$ (948)	0	6,025		$ 364		4,209	1,452	3,120		$ 424		1,946	750	4,123		$ 308		3,011	804
Total Equity	$ 13,933		$ 8		12,326	2,710		(163)	(948)	0	$ 5,903		$ 364		4,040	1,499	$ 3,172		$ 424		1,993	755	$ 4,152		$ 308		3,033	811
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.7725
Balance at beginning 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]
Common stock shares issued			2
Common stock issued	$ 0
Stock Issued During Period, Value, Treasury Stock Reissued	19								$ 19
Stock Issued During Period, Shares, Treasury Stock Reissued									646
Stock-based compensation	2				2
Net income (loss)	711					711					$ 441	[5]				441	$ 232	[8]				232	$ 283	[6]				283
Capital contributions from parent											685				685		37				37		84				84
Dividends and dividend equivalents	(573)	[7]				(573)	[7]									(283)						(138)						(167)
Dividends declared											$ (283)						$ (138)						$ (167)
Other comprehensive income (loss)	$ 0
Balance at end of period - shares at Sep. 30, 2024	737,778		737,778								66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Return of Capital to Parent																	$ (76)				(76)		$ (103)				(103)
Total Equity	$ 14,065		$ 8		12,321	2,826		(160)	$ (930)	0	$ 6,698		$ 364		4,720	1,614	3,216		$ 424		1,979	813	4,254		$ 308		3,067	879
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2575
Balance at beginning of period - shares at Jun. 30, 2024			737,762										66,368	[2]					21,294	[3]					37,818	[4]
Common stock shares issued			2
Common stock issued	$ 0
Stock Issued During Period, Value, Treasury Stock Reissued	1								$ 1
Stock Issued During Period, Shares, Treasury Stock Reissued									14
Stock-based compensation	7				7
Net income (loss)	214					214					142	[5]				142	77	[8]				77	98	[6]				98
Capital contributions from parent											5				5
Dividends and dividend equivalents	(192)					(192)
Dividends declared											$ (99)					(99)	$ (41)					(41)	$ (50)					(50)
Other comprehensive income (loss)	$ (3)							(3)
Balance at end of period - shares at Sep. 30, 2024	737,778		737,778								66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Return of Capital to Parent																	$ (25)				(25)		$ (53)				(53)
Total Equity	$ 14,092		$ 8		$ 12,328	$ 2,848		$ (163)	$ (929)	$ 0	$ 6,746		$ 364		$ 4,725	$ 1,657	$ 3,227		$ 424		$ 1,954	$ 849	$ 4,249		$ 308		$ 3,014	$ 927
[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 Energy Holdings. 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. Dividends declared per share of common stock were $0.2575 and $0.7725 for the three and nine months ended September 30, 2024 and $0.2400 and $0.7200 for the three and nine months ended September 30, 2023. Net income equals comprehensive income.

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical)	9 Months Ended
	Sep. 30, 2024 vote $ / shares	Sep. 30, 2023 vote $ / shares
Vote per share of PPL's common stock | vote	1	1
Dividends Declared Per Share of Common Stock (in dollars per share) | $ / shares	$ 0.7725	$ 0.7200

Segment and Related Information

Segment and Related Information	9 Months Ended
	Sep. 30, 2024
Segment Reporting [Abstract]
Segment and Related Information	2. Segment and Related Information (PPL) PPL is organized into three segments: Kentucky Regulated, Pennsylvania Regulated and Rhode Island Regulated. PPL's segments are determined by geographic location. The Kentucky Regulated segment includes the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. 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. "Corporate and Other" primarily includes corporate level financing costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Narragansett Electric. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results. Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended September 30 are as follows: Three Months Nine Months 2024 2023 2024 2023 Operating Revenues from external customers Kentucky Regulated $ 895 $ 893 $ 2,698 $ 2,631 Pennsylvania Regulated 716 737 2,159 2,295 Rhode Island Regulated 455 413 1,393 1,355 Corporate and Other — — 1 — Total $ 2,066 $ 2,043 $ 6,251 $ 6,281 Net Income (Loss) Kentucky Regulated $ 169 $ 175 $ 493 $ 432 Pennsylvania Regulated 142 136 441 384 Rhode Island Regulated 14 6 90 70 Corporate and Other (111) (87) (313) (259) Total $ 214 $ 230 $ 711 $ 627 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of: September 30, December 31, Assets Kentucky Regulated $ 17,356 $ 17,029 Pennsylvania Regulated 15,328 14,294 Rhode Island Regulated 6,953 6,515 Corporate and Other (a) 835 1,398 Total $ 40,472 $ 39,236 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions. (PPL Electric, LG&E and KU)

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2024
Earnings Per Share [Abstract]
Earnings Per Share	4. 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 September 30 used in the EPS calculation are: Three Months Nine Months 2024 2023 2024 2023 Income (Numerator) Net income attributable to PPL $ 214 $ 230 $ 711 $ 627 Less amounts allocated to participating securities 1 — 2 1 Net income available to PPL common shareowners - Basic and Diluted $ 213 $ 230 $ 709 $ 626 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,773 737,107 737,678 737,005 Add: Dilutive share-based payment awards (a) 2,192 1,077 1,772 1,016 Weighted-average shares - Diluted EPS 739,965 738,184 739,450 738,021 Basic and Diluted EPS Net Income available to PPL common shareowners $ 0.29 $ 0.31 $ 0.96 $ 0.85 (a) The Treasury Stock Method was applied to non-participating share-based payment awards. For the periods ended September 30, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months Nine Months 2024 2023 2024 2023 Stock-based compensation awards — 179 — 324

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2024
Income Tax Disclosure [Abstract]
Income Taxes	5. Income Taxes Reconciliations of income tax expense (benefit) for the periods ended September 30 are as follows. (PPL) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 57 $ 60 $ 189 $ 167 Increase (decrease) due to: State income taxes, net of federal income tax benefit 20 16 48 49 Income tax credits (a) (2) (9) (4) (11) Utility rate-making tax adjustments (b) (4) (2) (14) (9) Amortization of excess deferred federal and state income taxes (13) (13) (33) (33) Other — 6 3 7 Total increase (decrease) 1 (2) — 3 Total income tax expense (benefit) $ 58 $ 58 $ 189 $ 170 (a) The amounts for the three and nine month periods ended September 30, 2023 primarily consist of a deferred tax benefit from renewable tax credits acquired at a discount. (b) Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL's regulated utility subsidiaries and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. (PPL Electric) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 40 $ 38 $ 122 $ 107 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 13 39 36 Utility rate-making tax adjustments (a) (2) (1) (12) (8) Amortization of excess deferred federal and state income taxes (3) (4) (8) (8) Other (1) (3) — (1) Total increase (decrease) 7 5 19 19 Total income tax expense (benefit) $ 47 $ 43 $ 141 $ 126 (a) Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. (LG&E) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 20 $ 21 $ 62 $ 56 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 4 11 10 Amortization of excess deferred federal and state income taxes (3) (3) (9) (9) Other (1) (1) (3) (2) Total increase (decrease) — — (1) (1) Total income tax expense (benefit) $ 20 $ 21 $ 61 $ 55 (KU) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 26 $ 26 $ 74 $ 63 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 5 13 12 Amortization of excess deferred federal and state income taxes (4) (5) (13) (13) Other (2) (2) (4) (3) Total increase (decrease) (2) (2) (4) (4) Total income tax expense (benefit) $ 24 $ 24 $ 70 $ 59 Other 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. Transfer of Certain Credits under the Inflation Reduction Act (PPL)

Utility Rate Regulation

Utility Rate Regulation	3 Months Ended
	Sep. 30, 2024
Regulated Operations [Abstract]
Utility Rate Regulation	6. Utility Rate Regulation (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Assets: Rate adjustment mechanisms $ 118 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 15 14 — — — — — — Derivative instruments 20 51 — — — — — — Smart meter rider 7 6 7 6 — — — — Universal service rider 7 — 7 — — — — — Storm damage costs 51 12 51 12 — — — — Fuel adjustment clause — 4 — — — 3 — — Transmission service charge 56 43 34 31 — — — — Transmission formula rate 15 5 — — — — — — Distribution system improvement charge 8 7 8 7 — — — — Tax Cuts and Jobs Act (over/under) 9 — 9 — — — — — Gas line tracker 4 — — — 4 — — — Other 32 33 1 1 1 4 1 3 Total current regulatory assets $ 342 $ 293 $ 117 $ 57 $ 5 $ 7 $ 1 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 882 $ 887 $ 428 $ 417 $ 205 $ 217 $ 132 $ 136 Plant outage costs 32 38 — — 8 10 25 28 Net metering 140 112 — — — — — — Environmental cost recovery 97 99 — — — — — — Storm costs 108 97 17 — 19 15 23 14 Unamortized loss on debt 20 22 3 3 9 10 6 7 Interest rate swaps 7 7 — — 7 7 — — Terminated interest rate swaps 54 58 — — 32 34 22 24 Accumulated cost of removal of utility plant 173 178 173 178 — — — — AROs 284 289 — — 75 76 209 213 Derivatives instruments 5 8 — — — — — — Gas line inspections 24 21 — — 22 19 2 2 Advanced metering infrastructure 24 15 — — 12 7 12 8 Other 44 43 1 — — — 7 7 Total noncurrent regulatory assets $ 1,894 $ 1,874 $ 622 $ 598 $ 389 $ 395 $ 438 $ 439 PPL PPL Electric LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 59 $ 51 $ 59 $ 51 $ — $ — $ — $ — Environmental cost recovery 14 — — — 8 — 6 — Tax Cuts and Jobs Act customer refund — 5 — 5 — — — — Act 129 compliance rider 7 15 7 15 — — — — Transmission formula rate 6 21 3 18 — — — — Rate adjustment mechanism 87 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — DSM 15 1 — — 7 — 8 1 Fuel adjustment clause 13 — — — 2 — 11 — Other 20 22 — 2 1 1 1 — Total current regulatory liabilities $ 246 $ 225 $ 69 $ 91 $ 18 $ 16 $ 26 $ 1 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,033 $ 996 $ — $ — $ 316 $ 306 $ 411 $ 399 Power purchase agreement - OVEC 12 19 — — 8 13 4 6 Net deferred taxes 1,923 1,977 750 763 445 459 503 523 Defined benefit plans 280 252 94 73 21 20 63 59 Terminated interest rate swaps 55 57 — — 28 29 27 28 Energy efficiency 32 5 — — — — — — Other 36 34 — — 3 — 6 3 Total noncurrent regulatory liabilities $ 3,371 $ 3,340 $ 844 $ 836 $ 821 $ 827 $ 1,014 $ 1,018 Regulatory Matters Rhode Island Activities (PPL) Rate Case Proceedings Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (the ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under the ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC. The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5. 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 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 (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 Automatic Meter Reading/AMF meter opt-out tariff provisions on September 19, 2024. RIE cannot predict the outcome of these matters. Grid Modernization 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 that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023 to discuss the scope of the RIPUC's review of the GMP and its potential impact on future electric ISR plans. RIE cannot predict the outcome of this matter. Petition for Deferral of Credit Card Fees On January 31, 2024, RIE filed a petition with the RIPUC requesting authority to recognize regulatory assets related to credit card, debit card and related fees transactions ("Electronic Transaction Fees") that RIE has waived and will continue to waive pursuant to the RIPUC orders related to COVID-19 impacts. On July 30, 2024, the RIPUC unanimously approved RIE's request to record a regulatory asset for Electronic Transaction Fees that have been incurred since July 1, 2020 until RIE's next general rate case or as otherwise determined by the RIPUC. RIE plans to include a proposal as part of its next base distribution rate case for the amortization and recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. On January 31, 2024, RIE also filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter. FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. T he RIPUC has not taken any action to date on this issue, including in its action on the FY 2025 Gas ISR Plan. FY 2024 Gas ISR Plan At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below. 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 spend in light of the Pipeline and Hazardous Materials Safety Administration's potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas 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 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), p lus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. FY 2024 Electric ISR Plan The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below. 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 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 approved RIE's compliance filing for rates effective April 1, 2024. Kentucky Activities (PPL, LG&E and KU) Kentucky September 2024 Storm In September 2024, LG&E and KU experienced significant winds and rain activity in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets with total estimated storm costs incurred through September 30, 2024 of $12 million ($2 million at LG&E and $10 million at KU). On October 15, 2024, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance expenses portion of the costs incurred related to the storm. As of September 30, 2024, LG&E and KU recorded regulatory assets related to the storm of $1 million and $5 million. LG&E and KU cannot predict the outcome of this matter. Kentucky May 2024 Storm In May 2024, LG&E and KU experienced significant windstorm activity in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets with total estimated costs incurred through September 30, 2024 of $28 million ($16 million at LG&E and $12 million at KU). On June 13, 2024, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance expenses portion of the costs incurred related to the storm. On July 2, 2024, the KPSC issued an order provisionally approving the request for accounting purposes, noting that the decision on approval of recovery would be determined in the future. On August 18, 2024, LG&E and KU submitted a request that the matter be decided by the KPSC based upon the written record. As of September 30, 2024 , LG&E and KU each recorded regulatory assets related to the storm of $4 million. LG&E and KU cannot predict the outcome of this matter. KPSC Investigation Related to Winter Storm Elliott On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties were granted intervenor status for the proceeding and, after completion of written discovery, a hearing on the matter occurred on May 23, 2024. The parties have filed post-hearing briefs and the case has been submitted for decision. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition. Mill Creek Unit 1 Retired Asset Recovery (RAR) Application (PPL and LG&E) On October 4, 2024, LG&E submitted an application related to the expected retirement of Mill Creek Unit 1 by December 31, 2024, requesting recovery of associated costs under the 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. LG&E expects these costs to be approximately $125 million and proposes to begin application of the RAR rider with bills issued in March 2025. On October 28, 2024, the KPSC issued an order to establish a procedural schedule regarding its investigation of the reasonableness of the proposed tariff. The KPSC intends to rule on the matter by February 28, 2025. LG&E cannot predict the outcome of this proceeding. Pennsylvania Activities (PPL and PPL Electric) PAPUC investigation into billing issues On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC's Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric's hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E had 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The time period to withdraw from the Settlement Agreement expired on June 14, 2024, without PPL Electric or I&E withdrawing from the Settlement Agreement, and the terms of the Settlement Agreement, as modified by the PAPUC's order, are now final. PPL Electric is in the process of complying with the terms of the Settlement Agreement, including making the $1 million contribution to Operation HELP on June 24, 2024. PPL Electric incurred no costs and $17 million for the three and nine month periods ended September 30, 2024 and $12 million and $21 million for the three and nine month periods ended September 30, 2023 related to the billing issue. PPL Electric will not seek regulatory recovery of these costs. DSIC Petition On April 26, 2024, PPL Electric filed a Petition with the PAPUC requesting that the PAPUC waive PPL Electric's DSIC cap of 5% of billed revenues and increase the maximum allowable DSIC to 9% for bills rendered on or after January 1, 2025. The publicly available procedural and litigation schedule currently contemplates that the PAPUC would issue a final order at its January 23, 2025 Public Meeting. PPL Electric cannot predict the outcome of this matter. Act 129 The Pennsylvania Public Utility Code requires electric distribution companies, including PPL Electric, to act as a DSP, which provides electricity generation supply service to customers pursuant to a PAPUC-approved default service procurement plan. A DSP is able to recover the costs associated with its default service procurement plan. In March 2024, PPL Electric filed a Petition for Approval of a new default service program and procurement plan with the PAPUC for the period June 1, 2025 through May 31, 2029. In August 2024, PPL Electric submitted a Joint Petition for Settlement in the proceeding. In September 2024, the Administrative Law Judge issued an Interim Order approving the proposed settlement without modification which remains pending before the PAPUC. PPL Electric cannot predict the outcome of this proceeding. Federal Matters FERC Transmission Rate Filing (PPL, LG&E and KU) In 2018, LG&E and KU applied to the FERC requesting elimination of certain on-going waivers and credits to a sub-set of transmission customers relating to the 1998 merger of LG&E's and KU's parent entities and the 2006 withdrawal of LG&E and KU from the Midcontinent Independent System Operator, Inc. (MISO), a regional transmission operator and energy market. The application sought termination of LG&E's and KU's commitment to provide certain Kentucky municipalities mitigation for certain horizontal market power concerns arising out of the 1998 LG&E and KU merger and 2006 MISO withdrawal. The amounts at issue are generally waivers or credits granted to a limited number of Kentucky municipalities for either certain LG&E and KU or MISO transmission charges incurred for transmission service received. In 2019, the FERC granted LG&E's and KU's request to remove the ongoing credits, conditioned upon the implementation by LG&E and KU of a transition mechanism for certain existing power supply arrangements, which was subsequently filed, modified, and approved by the FERC in 2020 and 2021. In 2020, LG&E and KU and other parties filed appeals with the U.S. Court of Appeals - D.C. Circuit (D.C. Circuit Court of Appeals) regarding the FERC's orders on the elimination of the mitigation and required transition mechanism. In August 2022, the D.C. Circuit Court of Appeals issued an order remanding the proceedings back to the FERC. On May 18, 2023, the FERC issued an order on remand reversing its 2019 decision and requiring LG&E and KU to refund credits previously withheld, including under such transition mechanism. LG&E and KU filed a petition for review of the FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals and provided refunds in accordance with the FERC order on December 1, 2023. The FERC issued an order on LG&E's and KU's compliance filing on November 16, 2023, and LG&E and KU filed a petition for review of this November 16, 2023 order on February 14, 2024. FERC issued the substantive order on rehearing on March 21, 2024, reaffirming its prior decision. LG&E and KU filed their opening brief with the D.C. Circuit Court of Appeals on June 24, 2024 and the FERC and the intervenors have filed briefs as well. LG&E's and KU's reply brief is due November 4, 2024. LG&E and KU cannot predict the ultimate outcome of the proceedings or any other post decision process but do not expect the annual impact to have a material effect on their operations or financial condition. LG&E and KU currently receive recovery of certain waivers and credits primarily through base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings. Recovery of Transmission Costs (PPL) Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum ROE of 11.74% on its transmission assets. The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the NETO cases, the FERC further refined its ROE methodology in another proceeding and has applied that refined methodology to transmission owners' ROEs in other jurisdictions, and the NETOs filed further information in the New England matters to distinguish their case. The proceeding and the final base rate ROE determination in the New England matters remain open, pending a final order from the FERC. PPL cannot predict the outcome of this matter, and an estimate of the impact cannot be determined. Other Purchase of Receivables Program (PPL and PPL Electric) In accordance with a PAPUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three months and nine months ended September 30, 2024, PPL Electric purchased $404 million and $1 billion of accounts receivable from alternative suppliers. During the three and nine months ended September 30, 2023, PPL Electric purchased $391 million and $1 billion of accounts receivable from alternative suppliers. (PPL)

Financing Activities

Financing Activities	9 Months Ended
	Sep. 30, 2024
Debt Disclosure [Abstract]
Financing Activities	7. 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 are attributable 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: September 30, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Borrowed Letters of PPL PPL Capital Funding (a) Syndicated Credit Facility (b) Dec. 2028 $ 1,250 $ — $ — $ 1,250 $ — $ 390 Bilateral Credit Facility Feb. 2025 100 — — 100 — — Bilateral Credit Facility Feb. 2025 100 — 14 86 — 13 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 14 $ 1,436 $ — $ 403 PPL Electric Syndicated Credit Facility Dec. 2028 $ 650 $ — $ 1 $ 649 $ — $ 511 Total PPL Electric Credit Facilities $ 650 $ — $ 1 $ 649 $ — $ 511 LG&E Syndicated Credit Facility Dec. 2028 $ 500 $ — $ — $ 500 $ — $ — Total LG&E Credit Facilities $ 500 $ — $ — $ 500 $ — $ — KU Syndicated Credit Facility Dec. 2028 $ 400 $ — $ — $ 400 $ — $ 93 Total KU Credit Facilities $ 400 $ — $ — $ 400 $ — $ 93 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) The PPL Capital Funding $1.25 billion syndicated credit facility includes a $250 million borrowing sublimit for RIE and a $1 billion sublimit for PPL Capital Funding at September 30, 2024 and December 31, 2023. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At September 30, 2024, PPL Capital Funding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL. (c) Commercial paper issued reflects the undiscounted face value of the issuance. PPL Capital Funding, RIE, PPL Electric, LG&E and KU 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: September 30, 2024 December 31, 2023 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) (b) $ 1,350 $ — $ 1,350 5.66% $ 365 RIE (b) 400 — 400 5.72% 25 PPL Electric 650 — 650 5.67% 510 LG&E 500 — 500 — KU 400 — 400 5.64% 93 Total $ 3,300 $ — $ 3,300 $ 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 has a total capacity of $1.25 billion. At September 30, 2024 and December 31, 2023, the borrowing sublimits were $250 million for RIE and $1 billion for PPL Capital Funding. PPL Capital Funding’s commercial paper program is also backed by a separate bilateral credit facility for $100 million. (c) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL Electric, LG&E, and KU) See Note 11 for discussion of intercompany borrowings. Long-term Debt (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. Dividends

Defined Benefits

Defined Benefits	9 Months Ended
	Sep. 30, 2024
Retirement Benefits [Abstract]
Defined Benefits	9. Defined Benefits (PPL) Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense, regulatory assets and regulatory liabilities, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended September 30: Pension Benefits Three Months Nine Months 2024 2023 2024 2023 PPL Service cost $ 9 $ 8 $ 26 $ 25 Interest cost 45 47 137 141 Expected return on plan assets (74) (77) (224) (232) Amortization of: Prior service cost 1 2 2 5 Actuarial loss 3 1 8 2 Net periodic defined benefit costs (credits) $ (16) $ (19) $ (51) $ (59) Other Postretirement Benefits Three Months Nine Months 2024 2023 2024 2023 PPL Service cost $ 2 $ 1 $ 5 $ 4 Interest cost 8 8 22 23 Expected return on plan assets (8) (7) (23) (22) Amortization of: Prior service cost — — 1 1 Actuarial loss (1) (1) (4) (4) Net periodic defined benefit costs (credits) $ 1 $ 1 $ 1 $ 2 (All Registrants) The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the Statements of Income. See Note 12 for additional information.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2024
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions 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 and LKS charged the following amounts for the periods ended September 30, 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. Three Months Nine Months 2024 2023 2024 2023 PPL Electric from PPL Services $ 53 $ 52 $ 159 $ 166 LG&E from LKS 25 25 82 85 LG&E from PPL Services 15 10 46 30 KU from LKS 31 35 99 110 KU from PPL Services 15 11 45 33 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 September 30, 2024, CEP Reserves had $ 418 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 issued 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 September 30, 2024, LG&E's money pool unused capacity was $716 million. At September 30, 2024, LG&E had borrowings outstanding from KU and/or LKE of $ 34 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 issued 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 September 30, 2024, KU's money pool unused capacity was $522 million. At September 30, 2024, KU had borrowings outstanding from LG&E and/or LKE of $ 128 million no
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions 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 and LKS charged the following amounts for the periods ended September 30, 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. Three Months Nine Months 2024 2023 2024 2023 PPL Electric from PPL Services $ 53 $ 52 $ 159 $ 166 LG&E from LKS 25 25 82 85 LG&E from PPL Services 15 10 46 30 KU from LKS 31 35 99 110 KU from PPL Services 15 11 45 33 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 September 30, 2024, CEP Reserves had $ 418 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 issued 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 September 30, 2024, LG&E's money pool unused capacity was $716 million. At September 30, 2024, LG&E had borrowings outstanding from KU and/or LKE of $ 34 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 issued 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 September 30, 2024, KU's money pool unused capacity was $522 million. At September 30, 2024, KU had borrowings outstanding from LG&E and/or LKE of $ 128 million no
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions 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 and LKS charged the following amounts for the periods ended September 30, 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. Three Months Nine Months 2024 2023 2024 2023 PPL Electric from PPL Services $ 53 $ 52 $ 159 $ 166 LG&E from LKS 25 25 82 85 LG&E from PPL Services 15 10 46 30 KU from LKS 31 35 99 110 KU from PPL Services 15 11 45 33 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 September 30, 2024, CEP Reserves had $ 418 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 issued 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 September 30, 2024, LG&E's money pool unused capacity was $716 million. At September 30, 2024, LG&E had borrowings outstanding from KU and/or LKE of $ 34 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 issued 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 September 30, 2024, KU's money pool unused capacity was $522 million. At September 30, 2024, KU had borrowings outstanding from LG&E and/or LKE of $ 128 million no

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	13. Fair Value Measurements (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 in each Registrant's 2023 Form 10-K for information on the levels in the fair value hierarchy. Recurring Fair Value Measurements The assets and liabilities measured at fair value were: September 30, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 542 $ 542 $ — $ — $ 331 $ 331 $ — $ — Restricted cash and cash equivalents (a) 41 41 — — 51 51 — — Total Cash, Cash Equivalents and Restricted Cash (b) 583 583 — — 382 382 — — Special use funds (a): Money market fund 1 1 — — 1 1 — — Commingled debt fund measured at NAV (c) 4 — — — 9 — — — Commingled equity fund measured at NAV (c) 4 — — — 8 — — — Total special use funds 9 1 — — 18 1 — — Price risk management assets (d): Gas contracts 2 — 1 1 1 — 1 — Total assets $ 594 $ 584 $ 1 $ 1 $ 401 $ 383 $ 1 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 7 $ — $ 7 $ — $ 7 $ — $ 7 $ — Gas contracts 27 — 22 5 60 — 41 19 Total price risk management liabilities $ 34 $ — $ 29 $ 5 $ 67 $ — $ 48 $ 19 PPL Electric Assets Cash and cash equivalents $ 35 $ 35 $ — $ — $ 51 $ 51 $ — $ — Total assets $ 35 $ 35 $ — $ — $ 51 $ 51 $ — $ — LG&E Assets Cash and cash equivalents $ 10 $ 10 $ — $ — $ 18 $ 18 $ — $ — Restricted cash and cash equivalents (a) 20 20 — — 26 26 — — Total Cash, Cash Equivalents and Restricted Cash (b) 30 30 — — 44 44 — — Total assets $ 30 $ 30 $ — $ — $ 44 $ 44 $ — $ — September 30, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Liabilities Price risk management liabilities: Interest rate swaps $ 7 $ — $ 7 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 7 $ — $ 7 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 16 $ 16 $ — $ — $ 14 $ 14 $ — $ — Restricted cash and cash equivalents (a) 20 20 — — 24 24 — — Total Cash, Cash Equivalents and Restricted Cash (b) 36 36 — — 38 38 — — Total assets $ 36 $ 36 $ — $ — $ 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 Balance Sheets. (d) 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. A reconciliation of net liabilities classified as Level 3 for the nine months ended September 30 is as follows: Gas Contracts 2024 Balance at beginning of period $ 19 Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities: 4 Settlements (19) Balance at end of period $ 4 Special Use Funds (PPL) The special use funds are investments restricted for paying active union employee medical costs. In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA to be used to pay medical claims of active bargaining unit employees. The funds are invested primarily in commingled debt and equity funds measured at NAV and are classified as investments in equity securities. Changes in the fair value of the funds are recorded to the Statements of Income. Price Risk Management Assets/Liabilities Interest Rate Swaps ( PPL, LG&E and KU) To manage interest rate risk, PPL, LG&E and KU use interest rate contracts such as forward-starting swaps, floating-to-fixed swaps and fixed-to-floating swaps. An income approach is used to measure the fair value of these contracts, utilizing readily observable inputs, such as forward interest rates (e.g., 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) Long-term debt is classified as Level 2. The effect of third-party credit enhancements is not included in the fair value measurement. The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. September 30, 2024 December 31, 2023 Carrying Fair Value Carrying Fair Value PPL $ 16,500 $ 16,431 $ 14,612 $ 14,031 PPL Electric 5,213 5,230 4,567 4,475 LG&E 2,470 2,424 2,469 2,369 KU 3,065 2,940 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	9 Months Ended
	Sep. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	14. Derivative Instruments and Hedging Activities (All Registrants) Risk Management Objectives 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 required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices. Volumetric Risk Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below: • PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases. • RIE is exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates. Equity Securities Price Risk • PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place. • PPL is exposed to equity securities price risk from future stock sales and/or purchases. Credit Risk Credit risk is the potential loss that may be incurred due to a counterparty's non-performance. PPL is exposed to credit risk from "in-the-money" transactions with counterparties as well as additional credit risk through certain of its subsidiaries, as discussed below. In the event a supplier of PPL, PPL Electric, LG&E or KU defaults on its contractual obligation, those Registrants would 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, if a counterparty's credit ratings fall below investment grade, their tangible net worth falls below specified percentages or its 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 obligation to return or post cash collateral under master netting arrangements at September 30, 2024 and December 31, 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 September 30, 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 the three and nine months ended September 30, 2024 and 2023, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At September 30, 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 September 30, 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. At September 30, 2024, RIE held contracts with notional volumes of 55 Bcf that range in maturity from 2024 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 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 and certain RIE commodity gas contracts that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at September 30, 2024 and December 31, 2023. See Note 1 in each Registrant's 2023 Form 10-K for additional information on accounting policies related to derivative instruments. (PPL) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. September 30, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ — $ 1 $ — $ 1 Gas contracts 2 22 1 51 Total current 2 23 1 52 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps — 6 — 6 Gas contracts — 5 — 9 Total noncurrent — 11 — 15 Total derivatives $ 2 $ 34 $ 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. 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 for the period ended September 30, 2024. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of Gain (Loss) Gain (Loss) Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ (1) $ (3) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Nine Months Gas contracts Energy purchases $ (6) $ (31) Total $ (6) $ (31) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ (3) $ — Gas contracts Regulatory assets - current (2) 31 Regulatory assets - noncurrent (3) 3 Total $ (8) $ 34 The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended September 30, 2023. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of Gain (Loss) Gain (Loss) Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ (1) $ (3) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Nine Months Gas contracts Energy purchases $ (4) $ (11) Other income (expense) - net (1) (1) Total $ (5) $ (12) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 4 $ 4 Gas contracts Regulatory assets - current (14) 12 Regulatory assets - noncurrent 2 (5) Total $ (8) $ 11 The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended September 30, 2024. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 188 $ 549 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 (1) (3) The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended September 30, 2023. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 165 $ 494 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 (1) (3) (LG&E) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. September 30, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 1 Total current — 1 — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 6 — 6 Total noncurrent — 6 — 6 Total derivatives $ — $ 7 $ — $ 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 for the period ended September 30, 2024. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ — $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ (3) $ — The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended September 30, 2023. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ — $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 4 $ 4 (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 September 30, 2024 Derivatives PPL $ 2 $ 2 $ — $ — $ 34 $ 2 $ — $ 32 LG&E — — — — 7 — — 7 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net 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, such amounts would represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features. (PPL) At September 30, 2024, derivative contracts in a net liability position that contain credit risk-related contingent features was $18 million. At September 30, 2024, the aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $19 million.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2024
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LG&E and KU) PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rules. 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 resulting from the 2015 CCR Rule 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 Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 6 3 3 New obligations incurred (a) 8 3 5 Changes in estimated cash flow or settlement date 1 1 (1) Obligations settled (15) (8) (7) Other 2 — — Balance at September 30, 2024 $ 160 $ 84 $ 66
Louisville Gas And Electric Co [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LG&E and KU) PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rules. 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 resulting from the 2015 CCR Rule 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 Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 6 3 3 New obligations incurred (a) 8 3 5 Changes in estimated cash flow or settlement date 1 1 (1) Obligations settled (15) (8) (7) Other 2 — — Balance at September 30, 2024 $ 160 $ 84 $ 66
Kentucky Utilities Co [Member]
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LG&E and KU) PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rules. 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 resulting from the 2015 CCR Rule 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 Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 6 3 3 New obligations incurred (a) 8 3 5 Changes in estimated cash flow or settlement date 1 1 (1) Obligations settled (15) (8) (7) Other 2 — — Balance at September 30, 2024 $ 160 $ 84 $ 66

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2024
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	16. Accumulated Other Comprehensive Income (Loss) (PPL) The after-tax changes in AOCI by component for the periods ended September 30 were as follows. Unrealized gains (losses) Defined benefit plans Equity Prior Actuarial Total PPL June 30, 2024 $ 7 $ 4 $ (4) $ (167) $ (160) Amounts arising during the period — — — (4) (4) Reclassifications from AOCI 2 — — (1) 1 Net OCI during the period 2 — — (5) (3) September 30, 2024 $ 9 $ 4 $ (4) $ (172) $ (163) December 31, 2023 $ 6 $ 3 $ (4) $ (168) $ (163) Amounts arising during the period — 1 — (2) (1) Reclassifications from AOCI 3 — — (2) 1 Net OCI during the period 3 1 — (4) — September 30, 2024 $ 9 $ 4 $ (4) $ (172) $ (163) June 30, 2023 $ 4 $ 3 $ (4) $ (140) $ (137) Amounts arising during the period — — — (6) (6) Reclassifications from AOCI 1 — — — 1 Net OCI during the period 1 — — (6) (5) September 30, 2023 $ 5 $ 3 $ (4) $ (146) $ (142) Unrealized gains (losses) Defined benefit plans Equity Prior Actuarial Total December 31, 2022 $ 3 $ 2 $ (5) $ (124) $ (124) Amounts arising during the period — 1 — (21) (20) Reclassifications from AOCI 2 — 1 (1) 2 Net OCI during the period 2 1 1 (22) (18) September 30, 2023 $ 5 $ 3 $ (4) $ (146) $ (142) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended September 30. Three Months Nine Months Affected Line Item on the Details about AOCI 2024 2023 2024 2023 Statements of Income Qualifying derivatives Interest rate swaps $ (1) $ (1) $ (3) $ (3) Interest Expense Total Pre-tax (1) (1) (3) (3) Income Taxes (1) — — 1 Total After-tax (2) (1) (3) (2) Defined benefit plans Prior service costs (a) — — — (1) Net actuarial loss (a) 1 (1) 3 1 Total Pre-tax 1 (1) 3 — Income Taxes — 1 (1) — Total After-tax 1 — 2 — Total reclassifications during the period $ (1) $ (1) $ (1) $ (2) (a) These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.

Interim Financial Statements

Interim Financial Statements	9 Months Ended
	Sep. 30, 2024
Interim Financial Statements [Abstract]
Interim Financial Statements	1. Interim Financial Statements (All Registrants) Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed 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 Registrant's related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant. The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, 2023 is derived from that Registrant's 2023 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2023 Form 10-K. The results of operations for the three and nine months ended September 30, 2024 are not necessarily indicative of the results to be expected for the full year ending December 31, 2024 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2024
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	XX. Summary of Significant Accounting Policies (All Registrants) The following accounting policy disclosures represent updates to Note 1 in each Registrant's 2023 Form 10-K and should be read in conjunction with those disclosures. Restricted Cash and Cash Equivalents (PPL) Reconciliation of Cash, Cash Equivalents and Restricted Cash The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL September 30, December 31, Cash and cash equivalents $ 542 $ 331 Restricted cash - current (a) 42 1 Total Cash, Cash Equivalents and Restricted Cash $ 584 $ 332 (a) 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. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets."

Acquisitions, Development and D

Acquisitions, Development and Divestitures	9 Months Ended
	Sep. 30, 2024
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures	8. Acquisitions, Developments and Divestitures Acquisitions (PPL) 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 USA, a subsidiary of National Grid plc (the Acquisition) for approximately $3.8 billion. Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid USA 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 were $32 million and $129 million during the three and nine months ended September 30, 2024, and $59 million and $179 million during the three and nine months ended September 30, 2023. 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. See Note 9 in PPL's 2023 Form 10-K for a complete listing of those commitments. The following represents an update to the remaining commitments: • 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) costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $85 million and $250 million for the three and nine months ended September 30, 2024, and $69 million and $193 million for the three and nine months ended September 30, 2023. • RIE will not seek to recover in rates any markup charged by National Grid USA and/or its affiliates under the TSA, which were $5 million and $8 million for the three and nine months ended September 30, 2024, and $2 million and $6 million for the three and nine months ended September 30, 2023. 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. Total project costs are estimated at approximately $1.0 billion, including AFUDC. Commercial operation of the facility is anticipated to begin mid-2027. See Note 7 in PPL's 2023 Form 10-K for additional information on the CPCN filing.

Other Income (Expense) - net

Other Income (Expense) - net	9 Months Ended
	Sep. 30, 2024
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	12. Other Income (Expense) - net (PPL) The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 9 $ 13 $ 32 $ 30 Interest income 10 4 25 22 AFUDC - equity component 13 7 33 21 Charitable contributions — (1) (4) (3) Miscellaneous (a) — (7) — (19) Other Income (Expense) - net $ 32 $ 16 $ 86 $ 51 (a) 2023 includes legal expenses incurred related to litigation with a former affiliate, Talen Montana. (PPL Electric) The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 4 $ 5 $ 13 $ 15 Interest income 3 1 5 6 AFUDC - equity component 6 4 17 12 Charitable contributions — — (3) (2) Miscellaneous — (2) 1 (2) Other Income (Expense) - net $ 13 $ 8 $ 33 $ 29 (LG&E) The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ — $ — $ 3 $ — Interest income — — 1 — AFUDC - equity component 2 1 5 2 Miscellaneous 1 (1) — — Other Income (Expense) - net $ 3 $ — $ 9 $ 2 (KU) The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 2 $ — $ 6 $ 4 Interest income — — 1 — AFUDC - equity component 3 1 6 2 Miscellaneous (1) — (3) — Other Income (Expense) - net $ 4 $ 1 $ 10 $ 6

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	9 Months Ended
	Sep. 30, 2024
Accounting Policies [Abstract]
Accounting Standards Update and Change in Accounting Principle	17. New Accounting Guidance Pending Adoption (All Registrants) Improvements to Reportable Segment Disclosures In November 2023, the FASB issued ASU 2023-07 which improves reportable segment disclosure requirements, primarily through enhanced disclosures about 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 required to provide disclosures required by the new ASU and existing segment disclosure in Topic 280 (Segment Reporting). For public business entities, this guidance will be applied retrospectively and will be effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. Adoption of ASU 2023-07 will result in the Registrants including the additional required disclosures. The Registrants plan to adopt ASU 2023-07 effective for the year ending December 31, 2024. Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09 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.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Policies)	9 Months Ended
	Sep. 30, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives, Offsetting Fair Value Amounts, Policy	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.

Adoption of Accounting Guidance

Adoption of Accounting Guidance (Tables)	9 Months Ended
	Sep. 30, 2024
Summary Of Significant Accounting Policies [Line Items]
Financing Receivable, Allowance for Credit Loss [Table Text Block]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement	The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL September 30, December 31, Cash and cash equivalents $ 542 $ 331 Restricted cash - current (a) 42 1 Total Cash, Cash Equivalents and Restricted Cash $ 584 $ 332 (a) 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. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets."

Segment and Related Informati_2

Segment and Related Information (Tables)	9 Months Ended
	Sep. 30, 2024
Segment Reporting [Abstract]
Segment and Related Information	Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended September 30 are as follows: Three Months Nine Months 2024 2023 2024 2023 Operating Revenues from external customers Kentucky Regulated $ 895 $ 893 $ 2,698 $ 2,631 Pennsylvania Regulated 716 737 2,159 2,295 Rhode Island Regulated 455 413 1,393 1,355 Corporate and Other — — 1 — Total $ 2,066 $ 2,043 $ 6,251 $ 6,281 Net Income (Loss) Kentucky Regulated $ 169 $ 175 $ 493 $ 432 Pennsylvania Regulated 142 136 441 384 Rhode Island Regulated 14 6 90 70 Corporate and Other (111) (87) (313) (259) Total $ 214 $ 230 $ 711 $ 627 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of: September 30, December 31, Assets Kentucky Regulated $ 17,356 $ 17,029 Pennsylvania Regulated 15,328 14,294 Rhode Island Regulated 6,953 6,515 Corporate and Other (a) 835 1,398 Total $ 40,472 $ 39,236 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

Revenue from Contracts with Cus

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2024
Revenue from Contracts with Customers [Line Items]
Disaggregation of Revenue [Table Text Block]	The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended September 30. Three Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 2024 PA Regulated $ 367 $ 111 $ 12 $ 15 $ — $ — $ 204 $ 709 KY Regulated 378 268 161 76 7 20 — 910 RI Regulated 112 38 5 251 — — 52 458 Total PPL $ 857 $ 417 $ 178 $ 342 $ 7 $ 20 $ 256 $ 2,077 2023 PA Regulated $ 389 $ 113 $ 13 $ 14 $ — $ — $ 202 $ 731 KY Regulated 367 260 162 79 6 17 — 891 RI Regulated 110 32 4 223 — — 47 416 Total PPL $ 866 $ 405 $ 179 $ 316 $ 6 $ 17 $ 249 $ 2,038 PPL Electric 2024 $ 367 $ 111 $ 12 $ 15 $ — $ — $ 204 $ 709 2023 $ 389 $ 113 $ 13 $ 14 $ — $ — $ 202 $ 731 LG&E 2024 $ 190 $ 132 $ 48 $ 31 $ — $ 6 $ — $ 407 2023 $ 182 $ 127 $ 49 $ 33 $ — $ 6 $ — $ 397 KU 2024 $ 188 $ 136 $ 113 $ 45 $ 7 $ 26 $ — $ 515 2023 $ 185 $ 133 $ 113 $ 45 $ 6 $ 21 $ — $ 503 Nine Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 2024 PA Regulated $ 1,125 $ 318 $ 34 $ 43 $ — $ — $ 613 $ 2,133 KY Regulated 1,147 780 479 248 18 48 — 2,720 RI Regulated 480 182 17 593 — — 128 1,400 Corp and Other — — — 1 — — — 1 Total PPL $ 2,752 $ 1,280 $ 530 $ 885 $ 18 $ 48 $ 741 $ 6,254 2023 PA Regulated $ 1,266 $ 346 $ 44 $ 40 $ — $ — $ 593 $ 2,289 KY Regulated 1,108 771 486 205 17 37 — 2,624 RI Regulated 480 182 17 586 — — 128 1,393 Total PPL $ 2,854 $ 1,299 $ 547 $ 831 $ 17 $ 37 $ 721 $ 6,306 Nine Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL Electric 2024 $ 1,125 $ 318 $ 34 $ 43 $ — $ — $ 613 $ 2,133 2023 $ 1,266 $ 346 $ 44 $ 40 $ — $ — $ 593 $ 2,289 LG&E 2024 $ 571 $ 391 $ 141 $ 114 $ — $ 34 $ — $ 1,251 2023 $ 574 $ 398 $ 145 $ 75 $ — $ 33 $ — $ 1,225 KU 2024 $ 576 $ 389 $ 338 $ 134 $ 18 $ 53 $ — $ 1,508 2023 $ 534 $ 373 $ 341 $ 130 $ 17 $ 38 $ — $ 1,433 (a) Primarily includes revenues from pole attachments, street lighting, other public authorities and other non-core businesses. 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 the Kentucky Regulated segment.
Credit Loss Recognized from Contracts with Customers [Table Text Block]	The following table shows the accounts receivable and unbilled revenues balances that were impaired for the periods ended September 30. Three Months Nine Months 2024 2023 2024 2023 PPL (a) $ 28 $ 20 $ 72 $ 47 PPL Electric (a) 13 10 37 27 LG&E 1 2 2 3 KU 2 1 3 2 (a) For the nine months ended September 30, 2024, balances include amounts impaired related to PPL Electric's billing issues. See Note 6 for additional information.
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 at December 31, 2023 $ 43 $ 29 $ 6 $ 7 Contract liabilities at September 30, 2024 31 21 5 5 Revenue recognized during the nine months ended September 30, 2024 that was included in the contract liability balance at December 31, 2023 26 12 6 7 Contract liabilities at December 31, 2022 $ 34 $ 23 $ 5 $ 6 Contract liabilities at September 30, 2023 33 21 5 6 Revenue recognized during the nine months ended September 30, 2023 that was included in the contract liability balance at December 31, 2022 21 10 5 6

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 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 September 30 used in the EPS calculation are: Three Months Nine Months 2024 2023 2024 2023 Income (Numerator) Net income attributable to PPL $ 214 $ 230 $ 711 $ 627 Less amounts allocated to participating securities 1 — 2 1 Net income available to PPL common shareowners - Basic and Diluted $ 213 $ 230 $ 709 $ 626 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,773 737,107 737,678 737,005 Add: Dilutive share-based payment awards (a) 2,192 1,077 1,772 1,016 Weighted-average shares - Diluted EPS 739,965 738,184 739,450 738,021 Basic and Diluted EPS Net Income available to PPL common shareowners $ 0.29 $ 0.31 $ 0.96 $ 0.85
Common Stock Issuances
Antidilutive Securities Excluded From Diluted EPS	For the periods ended September 30, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months Nine Months 2024 2023 2024 2023 Stock-based compensation awards — 179 — 324

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2024
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended September 30 are as follows. (PPL) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 57 $ 60 $ 189 $ 167 Increase (decrease) due to: State income taxes, net of federal income tax benefit 20 16 48 49 Income tax credits (a) (2) (9) (4) (11) Utility rate-making tax adjustments (b) (4) (2) (14) (9) Amortization of excess deferred federal and state income taxes (13) (13) (33) (33) Other — 6 3 7 Total increase (decrease) 1 (2) — 3 Total income tax expense (benefit) $ 58 $ 58 $ 189 $ 170 (a) The amounts for the three and nine month periods ended September 30, 2023 primarily consist of a deferred tax benefit from renewable tax credits acquired at a discount. (b) Primarily consists of tax impacts of AFUDC equity and related depreciation across PPL's regulated utility subsidiaries and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended September 30 are as follows. (PPL Electric) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 40 $ 38 $ 122 $ 107 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 13 39 36 Utility rate-making tax adjustments (a) (2) (1) (12) (8) Amortization of excess deferred federal and state income taxes (3) (4) (8) (8) Other (1) (3) — (1) Total increase (decrease) 7 5 19 19 Total income tax expense (benefit) $ 47 $ 43 $ 141 $ 126 (a) Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.
Louisville Gas And Electric Co [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended September 30 are as follows. (LG&E) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 20 $ 21 $ 62 $ 56 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 4 11 10 Amortization of excess deferred federal and state income taxes (3) (3) (9) (9) Other (1) (1) (3) (2) Total increase (decrease) — — (1) (1) Total income tax expense (benefit) $ 20 $ 21 $ 61 $ 55
Kentucky Utilities Co [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended September 30 are as follows. (KU) Three Months Nine Months 2024 2023 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 26 $ 26 $ 74 $ 63 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 5 13 12 Amortization of excess deferred federal and state income taxes (4) (5) (13) (13) Other (2) (2) (4) (3) Total increase (decrease) (2) (2) (4) (4) Total income tax expense (benefit) $ 24 $ 24 $ 70 $ 59

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	9 Months Ended
	Sep. 30, 2024
Utility Rate Regulation [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Assets: Rate adjustment mechanisms $ 118 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 15 14 — — — — — — Derivative instruments 20 51 — — — — — — Smart meter rider 7 6 7 6 — — — — Universal service rider 7 — 7 — — — — — Storm damage costs 51 12 51 12 — — — — Fuel adjustment clause — 4 — — — 3 — — Transmission service charge 56 43 34 31 — — — — Transmission formula rate 15 5 — — — — — — Distribution system improvement charge 8 7 8 7 — — — — Tax Cuts and Jobs Act (over/under) 9 — 9 — — — — — Gas line tracker 4 — — — 4 — — — Other 32 33 1 1 1 4 1 3 Total current regulatory assets $ 342 $ 293 $ 117 $ 57 $ 5 $ 7 $ 1 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 882 $ 887 $ 428 $ 417 $ 205 $ 217 $ 132 $ 136 Plant outage costs 32 38 — — 8 10 25 28 Net metering 140 112 — — — — — — Environmental cost recovery 97 99 — — — — — — Storm costs 108 97 17 — 19 15 23 14 Unamortized loss on debt 20 22 3 3 9 10 6 7 Interest rate swaps 7 7 — — 7 7 — — Terminated interest rate swaps 54 58 — — 32 34 22 24 Accumulated cost of removal of utility plant 173 178 173 178 — — — — AROs 284 289 — — 75 76 209 213 Derivatives instruments 5 8 — — — — — — Gas line inspections 24 21 — — 22 19 2 2 Advanced metering infrastructure 24 15 — — 12 7 12 8 Other 44 43 1 — — — 7 7 Total noncurrent regulatory assets $ 1,894 $ 1,874 $ 622 $ 598 $ 389 $ 395 $ 438 $ 439 PPL PPL Electric LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 59 $ 51 $ 59 $ 51 $ — $ — $ — $ — Environmental cost recovery 14 — — — 8 — 6 — Tax Cuts and Jobs Act customer refund — 5 — 5 — — — — Act 129 compliance rider 7 15 7 15 — — — — Transmission formula rate 6 21 3 18 — — — — Rate adjustment mechanism 87 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — DSM 15 1 — — 7 — 8 1 Fuel adjustment clause 13 — — — 2 — 11 — Other 20 22 — 2 1 1 1 — Total current regulatory liabilities $ 246 $ 225 $ 69 $ 91 $ 18 $ 16 $ 26 $ 1 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,033 $ 996 $ — $ — $ 316 $ 306 $ 411 $ 399 Power purchase agreement - OVEC 12 19 — — 8 13 4 6 Net deferred taxes 1,923 1,977 750 763 445 459 503 523 Defined benefit plans 280 252 94 73 21 20 63 59 Terminated interest rate swaps 55 57 — — 28 29 27 28 Energy efficiency 32 5 — — — — — — Other 36 34 — — 3 — 6 3 Total noncurrent regulatory liabilities $ 3,371 $ 3,340 $ 844 $ 836 $ 821 $ 827 $ 1,014 $ 1,018

Financing Activities (Tables)

Financing Activities (Tables)	9 Months Ended
	Sep. 30, 2024
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The following credit facilities were in place at: September 30, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Borrowed Letters of PPL PPL Capital Funding (a) Syndicated Credit Facility (b) Dec. 2028 $ 1,250 $ — $ — $ 1,250 $ — $ 390 Bilateral Credit Facility Feb. 2025 100 — — 100 — — Bilateral Credit Facility Feb. 2025 100 — 14 86 — 13 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 14 $ 1,436 $ — $ 403 PPL Electric Syndicated Credit Facility Dec. 2028 $ 650 $ — $ 1 $ 649 $ — $ 511 Total PPL Electric Credit Facilities $ 650 $ — $ 1 $ 649 $ — $ 511 LG&E Syndicated Credit Facility Dec. 2028 $ 500 $ — $ — $ 500 $ — $ — Total LG&E Credit Facilities $ 500 $ — $ — $ 500 $ — $ — KU Syndicated Credit Facility Dec. 2028 $ 400 $ — $ — $ 400 $ — $ 93 Total KU Credit Facilities $ 400 $ — $ — $ 400 $ — $ 93 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) The PPL Capital Funding $1.25 billion syndicated credit facility includes a $250 million borrowing sublimit for RIE and a $1 billion sublimit for PPL Capital Funding at September 30, 2024 and December 31, 2023. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At September 30, 2024, PPL Capital Funding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL. (c) Commercial paper issued reflects the undiscounted face value of the issuance.
Schedule of Short-term Debt	The following commercial paper programs were in place at: September 30, 2024 December 31, 2023 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) (b) $ 1,350 $ — $ 1,350 5.66% $ 365 RIE (b) 400 — 400 5.72% 25 PPL Electric 650 — 650 5.67% 510 LG&E 500 — 500 — KU 400 — 400 5.64% 93 Total $ 3,300 $ — $ 3,300 $ 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 has a total capacity of $1.25 billion. At September 30, 2024 and December 31, 2023, the borrowing sublimits were $250 million for RIE and $1 billion for PPL Capital Funding. PPL Capital Funding’s commercial paper program is also backed by a separate bilateral credit facility for $100 million. (c) Commercial paper issued reflects the undiscounted face value of the issuance.

Defined Benefits (Tables)

Defined Benefits (Tables)	9 Months Ended
	Sep. 30, 2024
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended September 30: Pension Benefits Three Months Nine Months 2024 2023 2024 2023 PPL Service cost $ 9 $ 8 $ 26 $ 25 Interest cost 45 47 137 141 Expected return on plan assets (74) (77) (224) (232) Amortization of: Prior service cost 1 2 2 5 Actuarial loss 3 1 8 2 Net periodic defined benefit costs (credits) $ (16) $ (19) $ (51) $ (59) Other Postretirement Benefits Three Months Nine Months 2024 2023 2024 2023 PPL Service cost $ 2 $ 1 $ 5 $ 4 Interest cost 8 8 22 23 Expected return on plan assets (8) (7) (23) (22) Amortization of: Prior service cost — — 1 1 Actuarial loss (1) (1) (4) (4) Net periodic defined benefit costs (credits) $ 1 $ 1 $ 1 $ 2

Commitments and Contingencies (

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2024
Commitments and Contingencies Disclosure [Abstract]
Guarantees	The table below details guarantees provided as of September 30, 2024. Exposure at September 30, 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 $ 105 (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) 2028 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (d) (a) PPL WPD Limited, a PPL indirect U.K. subsidiary, 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. Pursuant to the agreement, 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, pursuant to the agreement, subject to certain adjustments plus the support obligations provided by PPL under sale-leaseback financings. (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 $82 million at September 30, 2024, consisting of LG&E's share of $57 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" in Note 13 in PPL's, LG&E's and KU's 2023 Form 10-K for additional information on the OVEC power purchase contract.

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 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 periods ended September 30, 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. Three Months Nine Months 2024 2023 2024 2023 PPL Electric from PPL Services $ 53 $ 52 $ 159 $ 166 LG&E from LKS 25 25 82 85 LG&E from PPL Services 15 10 46 30 KU from LKS 31 35 99 110 KU from PPL Services 15 11 45 33
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 periods ended September 30, 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. Three Months Nine Months 2024 2023 2024 2023 PPL Electric from PPL Services $ 53 $ 52 $ 159 $ 166 LG&E from LKS 25 25 82 85 LG&E from PPL Services 15 10 46 30 KU from LKS 31 35 99 110 KU from PPL Services 15 11 45 33
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services and LKS charged the following amounts for the periods ended September 30, 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. Three Months Nine Months 2024 2023 2024 2023 PPL Electric from PPL Services $ 53 $ 52 $ 159 $ 166 LG&E from LKS 25 25 82 85 LG&E from PPL Services 15 10 46 30 KU from LKS 31 35 99 110 KU from PPL Services 15 11 45 33

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	9 Months Ended
	Sep. 30, 2024
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 9 $ 13 $ 32 $ 30 Interest income 10 4 25 22 AFUDC - equity component 13 7 33 21 Charitable contributions — (1) (4) (3) Miscellaneous (a) — (7) — (19) Other Income (Expense) - net $ 32 $ 16 $ 86 $ 51 (a)
PPL Electric Utilities Corp [Member]
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 4 $ 5 $ 13 $ 15 Interest income 3 1 5 6 AFUDC - equity component 6 4 17 12 Charitable contributions — — (3) (2) Miscellaneous — (2) 1 (2) Other Income (Expense) - net $ 13 $ 8 $ 33 $ 29
Louisville Gas And Electric Co [Member]
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ — $ — $ 3 $ — Interest income — — 1 — AFUDC - equity component 2 1 5 2 Miscellaneous 1 (1) — — Other Income (Expense) - net $ 3 $ — $ 9 $ 2
Kentucky Utilities Co [Member]
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2024 2023 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 2 $ — $ 6 $ 4 Interest income — — 1 — AFUDC - equity component 3 1 6 2 Miscellaneous (1) — (3) — Other Income (Expense) - net $ 4 $ 1 $ 10 $ 6

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2024
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were: September 30, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 542 $ 542 $ — $ — $ 331 $ 331 $ — $ — Restricted cash and cash equivalents (a) 41 41 — — 51 51 — — Total Cash, Cash Equivalents and Restricted Cash (b) 583 583 — — 382 382 — — Special use funds (a): Money market fund 1 1 — — 1 1 — — Commingled debt fund measured at NAV (c) 4 — — — 9 — — — Commingled equity fund measured at NAV (c) 4 — — — 8 — — — Total special use funds 9 1 — — 18 1 — — Price risk management assets (d): Gas contracts 2 — 1 1 1 — 1 — Total assets $ 594 $ 584 $ 1 $ 1 $ 401 $ 383 $ 1 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 7 $ — $ 7 $ — $ 7 $ — $ 7 $ — Gas contracts 27 — 22 5 60 — 41 19 Total price risk management liabilities $ 34 $ — $ 29 $ 5 $ 67 $ — $ 48 $ 19 PPL Electric Assets Cash and cash equivalents $ 35 $ 35 $ — $ — $ 51 $ 51 $ — $ — Total assets $ 35 $ 35 $ — $ — $ 51 $ 51 $ — $ — LG&E Assets Cash and cash equivalents $ 10 $ 10 $ — $ — $ 18 $ 18 $ — $ — Restricted cash and cash equivalents (a) 20 20 — — 26 26 — — Total Cash, Cash Equivalents and Restricted Cash (b) 30 30 — — 44 44 — — Total assets $ 30 $ 30 $ — $ — $ 44 $ 44 $ — $ — September 30, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Liabilities Price risk management liabilities: Interest rate swaps $ 7 $ — $ 7 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 7 $ — $ 7 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 16 $ 16 $ — $ — $ 14 $ 14 $ — $ — Restricted cash and cash equivalents (a) 20 20 — — 24 24 — — Total Cash, Cash Equivalents and Restricted Cash (b) 36 36 — — 38 38 — — Total assets $ 36 $ 36 $ — $ — $ 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 Balance Sheets. (d) 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. A reconciliation of net liabilities classified as Level 3 for the nine months ended September 30 is as follows: Gas Contracts 2024 Balance at beginning of period $ 19 Total unrealized gains (losses) recognized as Regulatory Assets/Regulatory Liabilities: 4 Settlements (19) Balance at end of period $ 4
Fair Value, by Balance Sheet Grouping	The carrying amounts of long-term debt on the Balance Sheets and their estimated fair values are set forth below. September 30, 2024 December 31, 2023 Carrying Fair Value Carrying Fair Value PPL $ 16,500 $ 16,431 $ 14,612 $ 14,031 PPL Electric 5,213 5,230 4,567 4,475 LG&E 2,470 2,424 2,469 2,369 KU 3,065 2,940 3,064 2,861 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023
Derivative Instruments And Hedging Activities [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. September 30, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities (a): Interest rate swaps $ — $ 1 $ — $ 1 Gas contracts 2 22 1 51 Total current 2 23 1 52 Noncurrent: Price Risk Management Assets/Liabilities (a): Interest rate swaps — 6 — 6 Gas contracts — 5 — 9 Total noncurrent — 11 — 15 Total derivatives $ 2 $ 34 $ 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. Excludes accrued interest, if applicable.
Derivative Instruments, Gain (Loss)	The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended September 30, 2024. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 188 $ 549 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 (1) (3)	The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended September 30, 2023. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 165 $ 494 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 (1) (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 September 30, 2024 Derivatives PPL $ 2 $ 2 $ — $ — $ 34 $ 2 $ — $ 32 LG&E — — — — 7 — — 7 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended September 30, 2024. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of Gain (Loss) Gain (Loss) Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ (1) $ (3) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Nine Months Gas contracts Energy purchases $ (6) $ (31) Total $ (6) $ (31) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ (3) $ — Gas contracts Regulatory assets - current (2) 31 Regulatory assets - noncurrent (3) 3 Total $ (8) $ 34	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended September 30, 2023. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of Gain (Loss) Gain (Loss) Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ (1) $ (3) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Nine Months Gas contracts Energy purchases $ (4) $ (11) Other income (expense) - net (1) (1) Total $ (5) $ (12) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 4 $ 4 Gas contracts Regulatory assets - current (14) 12 Regulatory assets - noncurrent 2 (5) Total $ (8) $ 11
Louisville Gas And Electric Co [Member]
Derivative Instruments And Hedging Activities [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. September 30, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 1 Total current — 1 — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 6 — 6 Total noncurrent — 6 — 6 Total derivatives $ — $ 7 $ — $ 7
Derivative Instruments, Gain (Loss)	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended September 30, 2024. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ — $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ (3) $ —	The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets for the period ended September 30, 2023. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ — $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 4 $ 4
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 September 30, 2024 Derivatives PPL $ 2 $ 2 $ — $ — $ 34 $ 2 $ — $ 32 LG&E — — — — 7 — — 7 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 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 Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 6 3 3 New obligations incurred (a) 8 3 5 Changes in estimated cash flow or settlement date 1 1 (1) Obligations settled (15) (8) (7) Other 2 — — Balance at September 30, 2024 $ 160 $ 84 $ 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 Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 6 3 3 New obligations incurred (a) 8 3 5 Changes in estimated cash flow or settlement date 1 1 (1) Obligations settled (15) (8) (7) Other 2 — — Balance at September 30, 2024 $ 160 $ 84 $ 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 Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 6 3 3 New obligations incurred (a) 8 3 5 Changes in estimated cash flow or settlement date 1 1 (1) Obligations settled (15) (8) (7) Other 2 — — Balance at September 30, 2024 $ 160 $ 84 $ 66

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Sep. 30, 2024
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the periods ended September 30 were as follows. Unrealized gains (losses) Defined benefit plans Equity Prior Actuarial Total PPL June 30, 2024 $ 7 $ 4 $ (4) $ (167) $ (160) Amounts arising during the period — — — (4) (4) Reclassifications from AOCI 2 — — (1) 1 Net OCI during the period 2 — — (5) (3) September 30, 2024 $ 9 $ 4 $ (4) $ (172) $ (163) December 31, 2023 $ 6 $ 3 $ (4) $ (168) $ (163) Amounts arising during the period — 1 — (2) (1) Reclassifications from AOCI 3 — — (2) 1 Net OCI during the period 3 1 — (4) — September 30, 2024 $ 9 $ 4 $ (4) $ (172) $ (163) June 30, 2023 $ 4 $ 3 $ (4) $ (140) $ (137) Amounts arising during the period — — — (6) (6) Reclassifications from AOCI 1 — — — 1 Net OCI during the period 1 — — (6) (5) September 30, 2023 $ 5 $ 3 $ (4) $ (146) $ (142) Unrealized gains (losses) Defined benefit plans Equity Prior Actuarial Total December 31, 2022 $ 3 $ 2 $ (5) $ (124) $ (124) Amounts arising during the period — 1 — (21) (20) Reclassifications from AOCI 2 — 1 (1) 2 Net OCI during the period 2 1 1 (22) (18) September 30, 2023 $ 5 $ 3 $ (4) $ (146) $ (142)
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 periods ended September 30. Three Months Nine Months Affected Line Item on the Details about AOCI 2024 2023 2024 2023 Statements of Income Qualifying derivatives Interest rate swaps $ (1) $ (1) $ (3) $ (3) Interest Expense Total Pre-tax (1) (1) (3) (3) Income Taxes (1) — — 1 Total After-tax (2) (1) (3) (2) Defined benefit plans Prior service costs (a) — — — (1) Net actuarial loss (a) 1 (1) 3 1 Total Pre-tax 1 (1) 3 — Income Taxes — 1 (1) — Total After-tax 1 — 2 — Total reclassifications during the period $ (1) $ (1) $ (1) $ (2) (a) These AOCI components are included in the computation of net periodic defined benefit cost. See Note 9 for additional information.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Summary Of Significant Accounting Policies [Line Items]
Goodwill	$ 2,247	$ 2,247
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	542	331
Restricted Cash, Current	42	1
Cash, Cash Equivalents and Restricted Cash	584	332
PPL Electric Utilities Corp [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	35	51
Louisville Gas And Electric Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Goodwill	389	389
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	10	18
Kentucky Utilities Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Goodwill	607	607
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	$ 16	$ 14

Segment and Related Informati_3

Segment and Related Information (Details) $ in Millions		3 Months Ended			9 Months Ended			12 Months Ended
		Sep. 30, 2024 USD ($)		Sep. 30, 2023 USD ($)	Sep. 30, 2024 USD ($) Integer		Sep. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 2,066		$ 2,043	$ 6,251		$ 6,281
Net income (loss)		214		230	711		627
Balance Sheet Data [Abstract]
Assets		40,472			40,472			$ 39,236
Segment (Numeric) [Abstract]
Goodwill		2,247			$ 2,247			2,247
Number of Reportable Segments | Integer					3
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		895		893	$ 2,698		2,631
Net income (loss)		169		175	493		432
Balance Sheet Data [Abstract]
Assets		17,356			17,356			17,029
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		716		737	2,159		2,295
Net income (loss)		142		136	441		384
Balance Sheet Data [Abstract]
Assets		15,328			15,328			14,294
Corporate and Other [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		0		0	1		0
Net income (loss)		(111)		(87)	(313)		(259)
Balance Sheet Data [Abstract]
Assets		835			835			1,398
Rhode Island Regulated
Income Statement Data [Abstract]
Operating Revenues from external customers		455		413	1,393		1,355	1,400
Net income (loss)		14		6	90		70
Balance Sheet Data [Abstract]
Assets		6,953			6,953			6,515
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		716		737	2,159		2,295
Net income (loss)	[1]	142		136	441		384
Balance Sheet Data [Abstract]
Assets		15,328			$ 15,328			14,294
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer					1
Number of Operating Segments | Integer					2
Louisville Gas And Electric Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		397		398	$ 1,239		1,227
Net income (loss)		77	[2]	79	232	[2]	210
Balance Sheet Data [Abstract]
Assets		7,878			7,878			7,753
Segment (Numeric) [Abstract]
Goodwill		389			$ 389			389
Number of Reportable Segments | Integer					1
Number of Operating Segments | Integer					1
Kentucky Utilities Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		509		505	$ 1,498		1,439
Net income (loss)	[3]	98		$ 101	283		$ 240
Balance Sheet Data [Abstract]
Assets		9,939			9,939			9,714
Segment (Numeric) [Abstract]
Goodwill		$ 607			$ 607			$ 607
Number of Reportable Segments | Integer					1
Number of Operating Segments | Integer					1
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023	Dec. 31, 2022
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	$ 2,066	$ 2,043	$ 6,251	$ 6,281
Alternative Revenue Programs	17	1	21	42
Other Revenue	(6)	(6)	(18)	(17)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	2,077	2,038	6,254	6,306
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	28	20	72	47
Contract with Customer, Liability	31	33	31	33	$ 43	$ 34
Contract with Customer, Liability, Revenue Recognized			26	21
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	857	866	2,752	2,854
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	417	405	1,280	1,299
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	178	179	530	547
Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	342	316	885	831
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	7	6	18	17
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	20	17	48	37
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	256	249	741	721
Pennsylvania Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	716	737	2,159	2,295
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	709	731	2,133	2,289
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	367	389	1,125	1,266
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	111	113	318	346
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	12	13	34	44
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	15	14	43	40
Pennsylvania Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Pennsylvania Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Pennsylvania Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	204	202	613	593
Kentucky Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	895	893	2,698	2,631
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	910	891	2,720	1,393
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	378	367	1,147	480
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	268	260	780	182
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	161	162	479	17
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	76	79	248	586
Kentucky Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	7	6	18	0
Kentucky Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	20	17	48	0
Kentucky Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	128
Corporate and Other [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	0	0	1	0
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			1
Corporate and Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			0
Corporate and Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			0
Corporate and Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			0
Corporate and Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			1
Corporate and Other [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			0
Corporate and Other [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			0
Corporate and Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers			0
Rhode Island Regulated
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	455	413	1,393	1,355	1,400
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	458	416	1,400	2,624
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	112	110	480	1,108
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	38	32	182	771
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	5	4	17	486
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	251	223	593	205
Rhode Island Regulated | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	17
Rhode Island Regulated | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	37
Rhode Island Regulated | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	52	47	128	0
PPL Electric Utilities Corp [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	716	737	2,159	2,295
Alternative Revenue Programs	(3)	(2)	(14)	5
Other Revenue	(4)	(4)	(12)	(11)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	709	731	2,133	2,289
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	13	10	37	27
Contract with Customer, Liability	21	21	21	21	29	23
Contract with Customer, Liability, Revenue Recognized			12	10
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	367	389	1,125	1,266
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	111	113	318	346
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	12	13	34	44
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	15	14	43	40
PPL Electric Utilities Corp [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
PPL Electric Utilities Corp [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	204	202	613	593
Louisville Gas And Electric Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	397	398	1,239	1,227
Alternative Revenue Programs	11	0	15	1
Other Revenue	(1)	(1)	(3)	(3)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	407	397	1,251	1,225
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	2	2	3
Contract with Customer, Liability	5	5	5	5	6	5
Contract with Customer, Liability, Revenue Recognized			6	5
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	190	182	571	574
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	132	127	391	398
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	48	49	141	145
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	31	33	114	75
Louisville Gas And Electric Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Louisville Gas And Electric Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	6	34	33
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Kentucky Utilities Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	509	505	1,498	1,439
Alternative Revenue Programs	7	0	13	(3)
Other Revenue	(1)	(2)	(3)	(3)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	515	503	1,508	1,433
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	2	1	3	2
Contract with Customer, Liability	5	6	5	6	$ 7	$ 6
Contract with Customer, Liability, Revenue Recognized			7	6
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	188	185	576	534
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	136	133	389	373
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	113	113	338	341
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	45	45	134	130
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	7	6	18	17
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	26	21	53	38
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	$ 0	$ 0	$ 0	$ 0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Income (Numerator) [Abstract]
Net income (loss)	$ 214	$ 230	$ 711	$ 627
Less amounts allocated to participating securities	1	0	2	1
Net Income (Loss) Available to Common Stockholders, Basic			709	626
Net income (loss) available to PPL common shareowners - Basic	213	230
Net income (loss) available to PPL common shareowners - Diluted	$ 213	$ 230	$ 709	$ 626
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	737,773	737,107	737,678	737,005
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	2,192	1,077	1,772	1,016
Weighted-average shares - Diluted EPS (in shares)	739,965	738,184	739,450	738,021
Income (Loss) from Continuing Operations after income taxes, Diluted	$ 0.29	$ 0.31	$ 0.96	$ 0.85
Income (Loss) from Continuing Operations After Income Taxes, Basic	0.29	0.31	0.96	0.85
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	0.29	0.31	0.96	0.85
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.29	$ 0.31	$ 0.96	$ 0.85
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Income from continuing operations after income taxes available to PPL common shareowners - Basic and Diluted			$ 711
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	0	179	0	324

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 57	$ 60	$ 189	$ 167
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	20	16	48	49
Depreciation and other items not normalized	(4)	(2)	(14)	(9)
Effective Income Tax Rate Reconciliation, Tax Credit, Amount	(2)	(9)	(4)	(11)
Amortization of excess deferred income taxes	(13)	(13)	(33)	(33)
Other	0	6	3	7
Total increase (decrease)	1	(2)	0	3
Total income tax expense (benefit)	58	58	189	170
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	40	38	122	107
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	13	13	39	36
Depreciation and other items not normalized	(2)	(1)	(12)	(8)
Amortization of excess deferred income taxes	(3)	(4)	(8)	(8)
Other	(1)	(3)	0	(1)
Total increase (decrease)	7	5	19	19
Total income tax expense (benefit)	47	43	141	126
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	20	21	62	56
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	4	4	11	10
Amortization of excess deferred income taxes	(3)	(3)	(9)	(9)
Other	(1)	(1)	(3)	(2)
Total increase (decrease)	0	0	(1)	(1)
Total income tax expense (benefit)	20	21	61	55
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	26	26	74	63
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	4	5	13	12
Amortization of excess deferred income taxes	(4)	(5)	(13)	(13)
Other	(2)	(2)	(4)	(3)
Total increase (decrease)	(2)	(2)	(4)	(4)
Total income tax expense (benefit)	$ 24	$ 24	$ 70	$ 59

Utility Rate Regulation - Regul

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Current regulatory assets	$ 342	$ 293
Noncurrent regulatory assets	1,894	1,874
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	32	38
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	6
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	15	5
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	56	43
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	882	887
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	108	97
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	7	7
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	54	58
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	173	178
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	284	289
Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	51	12
Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	4
Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	140	112
Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	118	118
Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	15	14
Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	20	51
Noncurrent regulatory assets	5	8
Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	0
Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	7
Gas line tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	0
Other
Regulatory Assets [Line Items]
Current regulatory assets	32	33
Noncurrent regulatory assets	44	43
Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	97	99
Tax Cuts and Jobs Act (over/under)
Regulatory Assets [Line Items]
Current regulatory assets	9	0
Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent regulatory assets	24	21
Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	24	15
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	117	57
Noncurrent regulatory assets	622	598
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] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	34	31
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	428	417
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	17	0
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] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	51	12
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	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 tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	1	1
Noncurrent regulatory assets	1	0
PPL Electric Utilities Corp [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Tax Cuts and Jobs Act (over/under)
Regulatory Assets [Line Items]
Current regulatory assets	9	0
PPL Electric Utilities Corp [Member] | Gas line Inspections
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	7
Noncurrent regulatory assets	389	395
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	8	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] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
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] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	205	217
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	19	15
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	7	7
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	32	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] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	75	76
Louisville Gas And Electric Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	3
Louisville Gas And Electric Co [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent 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 certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Universal Service Rider [Member]
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 tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	0
Louisville Gas And Electric Co [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	1	4
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Tax Cuts and Jobs Act (over/under)
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] | Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	12	7
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	1	3
Noncurrent regulatory assets	438	439
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	25	28
Kentucky Utilities Co [Member] | Smart Meter Rider [Member]
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] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	132	136
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	23	14
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] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	209	213
Kentucky Utilities Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent 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 certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Universal Service Rider [Member]
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 tracker [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	1	3
Noncurrent regulatory assets	7	7
Kentucky Utilities Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Tax Cuts and Jobs Act (over/under)
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] | Advance metering Infrastructure
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 12	$ 8

Utility Rate Regulation - Reg_2

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	3 Months Ended
	Sep. 30, 2024	Dec. 31, 2023
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 246	$ 225
Noncurrent regulatory liabilities	$ 3,371	3,340
Utility Rate Regulation	6. Utility Rate Regulation (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Assets: Rate adjustment mechanisms $ 118 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 15 14 — — — — — — Derivative instruments 20 51 — — — — — — Smart meter rider 7 6 7 6 — — — — Universal service rider 7 — 7 — — — — — Storm damage costs 51 12 51 12 — — — — Fuel adjustment clause — 4 — — — 3 — — Transmission service charge 56 43 34 31 — — — — Transmission formula rate 15 5 — — — — — — Distribution system improvement charge 8 7 8 7 — — — — Tax Cuts and Jobs Act (over/under) 9 — 9 — — — — — Gas line tracker 4 — — — 4 — — — Other 32 33 1 1 1 4 1 3 Total current regulatory assets $ 342 $ 293 $ 117 $ 57 $ 5 $ 7 $ 1 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 882 $ 887 $ 428 $ 417 $ 205 $ 217 $ 132 $ 136 Plant outage costs 32 38 — — 8 10 25 28 Net metering 140 112 — — — — — — Environmental cost recovery 97 99 — — — — — — Storm costs 108 97 17 — 19 15 23 14 Unamortized loss on debt 20 22 3 3 9 10 6 7 Interest rate swaps 7 7 — — 7 7 — — Terminated interest rate swaps 54 58 — — 32 34 22 24 Accumulated cost of removal of utility plant 173 178 173 178 — — — — AROs 284 289 — — 75 76 209 213 Derivatives instruments 5 8 — — — — — — Gas line inspections 24 21 — — 22 19 2 2 Advanced metering infrastructure 24 15 — — 12 7 12 8 Other 44 43 1 — — — 7 7 Total noncurrent regulatory assets $ 1,894 $ 1,874 $ 622 $ 598 $ 389 $ 395 $ 438 $ 439 PPL PPL Electric LG&E KU September 30, December 31, September 30, December 31, September 30, December 31, September 30, December 31, Current Regulatory Liabilities: Generation supply charge $ 59 $ 51 $ 59 $ 51 $ — $ — $ — $ — Environmental cost recovery 14 — — — 8 — 6 — Tax Cuts and Jobs Act customer refund — 5 — 5 — — — — Act 129 compliance rider 7 15 7 15 — — — — Transmission formula rate 6 21 3 18 — — — — Rate adjustment mechanism 87 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — DSM 15 1 — — 7 — 8 1 Fuel adjustment clause 13 — — — 2 — 11 — Other 20 22 — 2 1 1 1 — Total current regulatory liabilities $ 246 $ 225 $ 69 $ 91 $ 18 $ 16 $ 26 $ 1 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,033 $ 996 $ — $ — $ 316 $ 306 $ 411 $ 399 Power purchase agreement - OVEC 12 19 — — 8 13 4 6 Net deferred taxes 1,923 1,977 750 763 445 459 503 523 Defined benefit plans 280 252 94 73 21 20 63 59 Terminated interest rate swaps 55 57 — — 28 29 27 28 Energy efficiency 32 5 — — — — — — Other 36 34 — — 3 — 6 3 Total noncurrent regulatory liabilities $ 3,371 $ 3,340 $ 844 $ 836 $ 821 $ 827 $ 1,014 $ 1,018 Regulatory Matters Rhode Island Activities (PPL) Rate Case Proceedings Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (the ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under the ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC. The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5. 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 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 (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 Automatic Meter Reading/AMF meter opt-out tariff provisions on September 19, 2024. RIE cannot predict the outcome of these matters. Grid Modernization 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 that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023 to discuss the scope of the RIPUC's review of the GMP and its potential impact on future electric ISR plans. RIE cannot predict the outcome of this matter. Petition for Deferral of Credit Card Fees On January 31, 2024, RIE filed a petition with the RIPUC requesting authority to recognize regulatory assets related to credit card, debit card and related fees transactions ("Electronic Transaction Fees") that RIE has waived and will continue to waive pursuant to the RIPUC orders related to COVID-19 impacts. On July 30, 2024, the RIPUC unanimously approved RIE's request to record a regulatory asset for Electronic Transaction Fees that have been incurred since July 1, 2020 until RIE's next general rate case or as otherwise determined by the RIPUC. RIE plans to include a proposal as part of its next base distribution rate case for the amortization and recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. On January 31, 2024, RIE also filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter. FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. T he RIPUC has not taken any action to date on this issue, including in its action on the FY 2025 Gas ISR Plan. FY 2024 Gas ISR Plan At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below. 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 spend in light of the Pipeline and Hazardous Materials Safety Administration's potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas 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 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), p lus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. FY 2024 Electric ISR Plan The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below. 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 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 approved RIE's compliance filing for rates effective April 1, 2024. Kentucky Activities (PPL, LG&E and KU) Kentucky September 2024 Storm In September 2024, LG&E and KU experienced significant winds and rain activity in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets with total estimated storm costs incurred through September 30, 2024 of $12 million ($2 million at LG&E and $10 million at KU). On October 15, 2024, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance expenses portion of the costs incurred related to the storm. As of September 30, 2024, LG&E and KU recorded regulatory assets related to the storm of $1 million and $5 million. LG&E and KU cannot predict the outcome of this matter. Kentucky May 2024 Storm In May 2024, LG&E and KU experienced significant windstorm activity in their service territories, resulting in substantial damage to certain of LG&E's and KU's assets with total estimated costs incurred through September 30, 2024 of $28 million ($16 million at LG&E and $12 million at KU). On June 13, 2024, LG&E and KU submitted a filing with the KPSC requesting regulatory asset treatment of the extraordinary operations and maintenance expenses portion of the costs incurred related to the storm. On July 2, 2024, the KPSC issued an order provisionally approving the request for accounting purposes, noting that the decision on approval of recovery would be determined in the future. On August 18, 2024, LG&E and KU submitted a request that the matter be decided by the KPSC based upon the written record. As of September 30, 2024 , LG&E and KU each recorded regulatory assets related to the storm of $4 million. LG&E and KU cannot predict the outcome of this matter. KPSC Investigation Related to Winter Storm Elliott On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties were granted intervenor status for the proceeding and, after completion of written discovery, a hearing on the matter occurred on May 23, 2024. The parties have filed post-hearing briefs and the case has been submitted for decision. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition. Mill Creek Unit 1 Retired Asset Recovery (RAR) Application (PPL and LG&E) On October 4, 2024, LG&E submitted an application related to the expected retirement of Mill Creek Unit 1 by December 31, 2024, requesting recovery of associated costs under the 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. LG&E expects these costs to be approximately $125 million and proposes to begin application of the RAR rider with bills issued in March 2025. On October 28, 2024, the KPSC issued an order to establish a procedural schedule regarding its investigation of the reasonableness of the proposed tariff. The KPSC intends to rule on the matter by February 28, 2025. LG&E cannot predict the outcome of this proceeding. Pennsylvania Activities (PPL and PPL Electric) PAPUC investigation into billing issues On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC's Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric's hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E had 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The time period to withdraw from the Settlement Agreement expired on June 14, 2024, without PPL Electric or I&E withdrawing from the Settlement Agreement, and the terms of the Settlement Agreement, as modified by the PAPUC's order, are now final. PPL Electric is in the process of complying with the terms of the Settlement Agreement, including making the $1 million contribution to Operation HELP on June 24, 2024. PPL Electric incurred no costs and $17 million for the three and nine month periods ended September 30, 2024 and $12 million and $21 million for the three and nine month periods ended September 30, 2023 related to the billing issue. PPL Electric will not seek regulatory recovery of these costs. DSIC Petition On April 26, 2024, PPL Electric filed a Petition with the PAPUC requesting that the PAPUC waive PPL Electric's DSIC cap of 5% of billed revenues and increase the maximum allowable DSIC to 9% for bills rendered on or after January 1, 2025. The publicly available procedural and litigation schedule currently contemplates that the PAPUC would issue a final order at its January 23, 2025 Public Meeting. PPL Electric cannot predict the outcome of this matter. Act 129 The Pennsylvania Public Utility Code requires electric distribution companies, including PPL Electric, to act as a DSP, which provides electricity generation supply service to customers pursuant to a PAPUC-approved default service procurement plan. A DSP is able to recover the costs associated with its default service procurement plan. In March 2024, PPL Electric filed a Petition for Approval of a new default service program and procurement plan with the PAPUC for the period June 1, 2025 through May 31, 2029. In August 2024, PPL Electric submitted a Joint Petition for Settlement in the proceeding. In September 2024, the Administrative Law Judge issued an Interim Order approving the proposed settlement without modification which remains pending before the PAPUC. PPL Electric cannot predict the outcome of this proceeding. Federal Matters FERC Transmission Rate Filing (PPL, LG&E and KU) In 2018, LG&E and KU applied to the FERC requesting elimination of certain on-going waivers and credits to a sub-set of transmission customers relating to the 1998 merger of LG&E's and KU's parent entities and the 2006 withdrawal of LG&E and KU from the Midcontinent Independent System Operator, Inc. (MISO), a regional transmission operator and energy market. The application sought termination of LG&E's and KU's commitment to provide certain Kentucky municipalities mitigation for certain horizontal market power concerns arising out of the 1998 LG&E and KU merger and 2006 MISO withdrawal. The amounts at issue are generally waivers or credits granted to a limited number of Kentucky municipalities for either certain LG&E and KU or MISO transmission charges incurred for transmission service received. In 2019, the FERC granted LG&E's and KU's request to remove the ongoing credits, conditioned upon the implementation by LG&E and KU of a transition mechanism for certain existing power supply arrangements, which was subsequently filed, modified, and approved by the FERC in 2020 and 2021. In 2020, LG&E and KU and other parties filed appeals with the U.S. Court of Appeals - D.C. Circuit (D.C. Circuit Court of Appeals) regarding the FERC's orders on the elimination of the mitigation and required transition mechanism. In August 2022, the D.C. Circuit Court of Appeals issued an order remanding the proceedings back to the FERC. On May 18, 2023, the FERC issued an order on remand reversing its 2019 decision and requiring LG&E and KU to refund credits previously withheld, including under such transition mechanism. LG&E and KU filed a petition for review of the FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals and provided refunds in accordance with the FERC order on December 1, 2023. The FERC issued an order on LG&E's and KU's compliance filing on November 16, 2023, and LG&E and KU filed a petition for review of this November 16, 2023 order on February 14, 2024. FERC issued the substantive order on rehearing on March 21, 2024, reaffirming its prior decision. LG&E and KU filed their opening brief with the D.C. Circuit Court of Appeals on June 24, 2024 and the FERC and the intervenors have filed briefs as well. LG&E's and KU's reply brief is due November 4, 2024. LG&E and KU cannot predict the ultimate outcome of the proceedings or any other post decision process but do not expect the annual impact to have a material effect on their operations or financial condition. LG&E and KU currently receive recovery of certain waivers and credits primarily through base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings. Recovery of Transmission Costs (PPL) Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum ROE of 11.74% on its transmission assets. The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the NETO cases, the FERC further refined its ROE methodology in another proceeding and has applied that refined methodology to transmission owners' ROEs in other jurisdictions, and the NETOs filed further information in the New England matters to distinguish their case. The proceeding and the final base rate ROE determination in the New England matters remain open, pending a final order from the FERC. PPL cannot predict the outcome of this matter, and an estimate of the impact cannot be determined. Other Purchase of Receivables Program (PPL and PPL Electric) In accordance with a PAPUC-approved purchase of accounts receivable program, PPL Electric purchases certain accounts receivable from alternative electricity suppliers at a discount, which reflects a provision for uncollectible accounts. The alternative electricity suppliers have no continuing involvement or interest in the purchased accounts receivable. Accounts receivable that are acquired are initially recorded at fair value on the date of acquisition. During the three months and nine months ended September 30, 2024, PPL Electric purchased $404 million and $1 billion of accounts receivable from alternative suppliers. During the three and nine months ended September 30, 2023, PPL Electric purchased $391 million and $1 billion of accounts receivable from alternative suppliers. (PPL)
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 59	51
Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	0
Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	13	0
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	7	15
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,033	996
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	12	19
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,923	1,977
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	280	252
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	55	57
Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	25	23
Noncurrent regulatory liabilities	32	5
Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	87	72
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	21
Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	15
Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	15	1
Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	20	22
Noncurrent regulatory liabilities	36	34
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	69	91
Noncurrent regulatory liabilities	844	836
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	59	51
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
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	7	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 OVEC [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	750	763
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	94	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] | Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
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] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	3	18
PPL Electric Utilities Corp [Member] | Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	2
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	18	16
Noncurrent regulatory liabilities	821	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	8	0
Louisville Gas And Electric Co [Member] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	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	316	306
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	8	13
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	445	459
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	20
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	28	29
Louisville Gas And Electric Co [Member] | Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	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] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	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] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	0
Louisville Gas And Electric Co [Member] | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	1
Noncurrent regulatory liabilities	3	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	26	1
Noncurrent regulatory liabilities	1,014	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] | Fuel adjustment clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	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	411	399
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	4	6
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	503	523
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	63	59
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	27	28
Kentucky Utilities Co [Member] | Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Rate adjustment mechanism
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] | Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Demand Side Management [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	8	1
Kentucky Utilities Co [Member] | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	1	0
Noncurrent regulatory liabilities	$ 6	$ 3

Utility Rate Regulation - Reg_3

Utility Rate Regulation - Regulatory Matters (Details) $ in Millions

1 Months Ended

3 Months Ended

9 Months Ended

Mar. 26, 2024 USD ($)

Nov. 06, 2023 MW

Sep. 27, 2023 USD ($)

Mar. 29, 2023 USD ($)

Oct. 16, 2018

Aug. 24, 2018

Dec. 31, 2023 USD ($)

Sep. 30, 2024 USD ($)

Sep. 30, 2023 USD ($)

Sep. 30, 2016

Sep. 30, 2024 USD ($)

Sep. 30, 2023 USD ($)

Oct. 04, 2024 USD ($)

Jun. 24, 2024 USD ($)

Apr. 26, 2024

Apr. 25, 2024 USD ($)

Nov. 21, 2023 USD ($)

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

$ 1,874

$ 1,894

$ 1,894

Storm Costs [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

97

108

108

Kentucky Public Service Commission [Member] | May 2024 Kentucky Storm

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

28

28

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

12

12

PPL Electric [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Billing Issues, Expenses Incurred

$ 0

$ 12

$ 17

$ 21

Distribution System Improvement Charge Cap

5%

5%

PPL Electric [Member] | Unaffiliated Third Party Entity [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Accounts Receivable, Purchase

$ 404

391

$ 1,000

1,000

PPL Electric [Member] | Pennsylvania Public Utility Commission

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

PPL Electric Billing Issue, Civil Penalty to be Paid

$ 1

PPL Electric Billing Issue, Donation to be Paid

$ 1

Requested Distribution System Improvement Charge Cap

9%

PPL Electric Billing Issue donation paid per the settlement

$ 1

LGE [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

CPCN NGCC Combustion Turbine Facilities Power | MW

640

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

16

16

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

4

4

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

2

2

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

1

1

LGE [Member] | Kentucky Public Service Commission [Member] | Subsequent Event [Member] | Mill Creek Unit 1 retirement

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

$ 125

KU [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

CPCN NGCC Combustion Turbine Facilities Power | MW

640

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

12

12

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

4

4

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

10

10

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

5

$ 5

Rhode Island Energy | Federal Energy Regulatory Commsion [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

New ROE prosed by NETO and approved by FERC

10.41%

Initial minimum base ROE to be reset by the FERC

11.14%

Maximum Base ROE reset by FERC

11.74%

Minimum base ROE reset by FERC

10.57%

Rhode Island Energy | Federal Energy Regulatory Commsion [Member] | Maximum ROE authorized

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

FERC Granted ROE

11.74%

Rhode Island Energy | Rhode Island Public Utility Commission

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Public Utilities, Approved Return on Equity, Percentage

9.275%

RIPUC Approved FY 2024 Gas ISR Plan for capital investment spend

$ 163

Recovery Cap on Capital Investment Related to AMF Program

$ 153

Capital Investment Spend on FY 2025 Gas ISR Plan

185

Proposed Capital Investment Spend on FY 2025 Electric ISR Plan

141

Proposed Contingency Plan Spend on FY 2025 Gas ISR Plan

11

Approved Capital Investment Spend on FY 2025 Gas ISR Plan

$ 180

Approved Contingency Plan Spend on FY 2025 Gas ISR Plan

11

Rhode Island Energy | Rhode Island Public Utility Commission | Capital Investment

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Approved Capital Investment Spend on FY 2025 Gas ISR Plan

168

Rhode Island Energy | Rhode Island Public Utility Commission | Paving Costs

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Approved Capital Investment Spend on FY 2025 Gas ISR Plan

12

Rhode Island Energy | Rhode Island Public Utility Commission | Vegetation management

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Proposed 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 Utility Commission | Other O&M

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Proposed 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 Utility Commission | Capital Investment

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

$ 132

Rhode Island Energy | Rhode Island Public Utility Commission | Vegetation management

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend

14

Rhode Island Energy | Rhode Island Public Utility Commission | Other O&M

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend

1

Rhode Island Energy | Rhode Island Public Utility Commission | Capital Investment

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend

$ 112

Rhode Island Energy | Rhode Island Public Utility Commission | Common equity percentage related to approved rate

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Percentage of common equity used on allowed ROE

51%

PPL Electric Utilities Corp [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Billing Issues, Expenses Incurred

$ 0

12

$ 17

21

Distribution System Improvement Charge Cap

5%

5%

Regulatory assets

598

$ 622

$ 622

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

0

17

17

PPL Electric Utilities Corp [Member] | Unaffiliated Third Party Entity [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Accounts Receivable, Purchase

404

$ 391

1,000

$ 1,000

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

PPL Electric Billing Issue, Civil Penalty to be Paid

$ 1

PPL Electric Billing Issue, Donation to be Paid

$ 1

Requested Distribution System Improvement Charge Cap

9%

PPL Electric Billing Issue donation paid per the settlement

$ 1

Louisville Gas And Electric Co [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

CPCN NGCC Combustion Turbine Facilities Power | MW

640

New NGCC LG&E Planned Ownership Percentage

31%

Regulatory assets

395

389

389

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

15

19

19

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

16

16

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

4

4

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

2

2

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

1

1

Louisville Gas And Electric Co [Member] | Kentucky Public Service Commission [Member] | Subsequent Event [Member] | Mill Creek Unit 1 retirement

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

$ 125

Kentucky Utilities Co [Member]

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

CPCN NGCC Combustion Turbine Facilities Power | MW

640

New NGCC KU Planned Ownership Percentage

69%

Regulatory assets

439

438

438

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

$ 14

23

23

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

12

12

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

4

4

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Amount of Regulatory Costs Not yet Approved

10

10

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

Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]

Regulatory assets

$ 5

$ 5

Utility Rate Regulation - Other

Utility Rate Regulation - Other (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 404	$ 391	$ 1,000	$ 1,000
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 404	$ 391	$ 1,000	$ 1,000

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	$ 0	$ 993
PPL Capital Funding [Member]
Line of Credit Facility [Line Items]
Capacity	1,450
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	14	403
Unused Capacity	1,436
PPL Capital Funding [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	365
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	1,250
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	390
Unused Capacity	1,250
Line of Credit Facility, Borrowing Capacity Sublimit	1,000
PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	365
PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	100
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	14	13
Unused Capacity	86
PPL Capital Funding [Member] | Bilateral Credit Facility #2
Line of Credit Facility [Line Items]
Capacity	100
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	100
PPL Electric [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
PPL Electric [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	510
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	500
LGE [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	0
LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	500
KU [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	93
Unused Capacity	400
KU [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	93
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	93
Unused Capacity	400
Rhode Island Energy | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	25
Rhode Island Energy | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Borrowing Capacity Sublimit	250
Line of Credit Facility, Borrowing Capacity Sublimit, Maximum	600
Rhode Island Energy | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	25
PPL Electric Utilities Corp [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
PPL Electric Utilities Corp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	510
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	500
Louisville Gas And Electric Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	0
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	500
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	93
Unused Capacity	400
Kentucky Utilities Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	93
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	0	$ 93
Unused Capacity	$ 400

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Short-term Debt [Line Items]
Capacity	$ 3,300
Commercial Paper Issuances (c)	0	$ 993
Unused Capacity	3,300
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.66%
Capacity	1,350
Commercial Paper Issuances (c)	0	$ 365
Unused Capacity	1,350
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.67%
Capacity	650
Commercial Paper Issuances (c)	0	$ 510
Unused Capacity	650
LGE [Member]
Short-term Debt [Line Items]
Capacity	500
Commercial Paper Issuances (c)	0	$ 0
Unused Capacity	500
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.64%
Capacity	400
Commercial Paper Issuances (c)	0	$ 93
Unused Capacity	400
Rhode Island Energy
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.72%
Capacity	400
Commercial Paper Issuances (c)	0	$ 25
Unused Capacity	400
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.67%
Capacity	650
Commercial Paper Issuances (c)	0	$ 510
Unused Capacity	650
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Capacity	500
Commercial Paper Issuances (c)	0	$ 0
Unused Capacity	500
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.64%
Capacity	400
Commercial Paper Issuances (c)	0	$ 93
Unused Capacity	$ 400

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended
	Mar. 31, 2024	Jan. 31, 2024	Sep. 30, 2024	Dec. 31, 2023
Long-term Debt (Numeric) [Abstract]
Long-term debt due within one year			$ 1	$ 1
Long-term Debt, Excluding Current Maturities			16,499	14,611
PPL Electric [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			650
Borrowed			0	0
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 650
Stated interest rate		4.85%
Proceeds from Issuance of First Mortgage Bond		$ 644
PPL Capital Funding [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			1,450
Borrowed			0	0
PPL Capital Funding [Member] | First Mortgage Bond [Member] | Senior Notes due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 750
Stated interest rate			5.25%
Proceeds from Issuance of First Mortgage Bond	$ 741
LGE [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			$ 500
Borrowed			0	0
KU [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			400
Borrowed			0	0
Rhode Island Energy | First Mortgage Bond [Member] | Senior Notes due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount			$ 500
Stated interest rate			5.35%
Proceeds from Issuance of First Mortgage Bond	$ 496
PPL Electric Utilities Corp [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			$ 650
Borrowed			0	0
Long-term Debt, Excluding Current Maturities			5,213	4,567
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 650
Stated interest rate		4.85%
Proceeds from Issuance of First Mortgage Bond		$ 644
Louisville Gas And Electric Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			500
Borrowed			0	0
Long-term Debt, Excluding Current Maturities			2,470	2,469
Kentucky Utilities Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			400
Borrowed			0	0
Long-term Debt, Excluding Current Maturities			$ 3,065	$ 3,064

Financing Activities - Equity S

Financing Activities - Equity Securities (Details) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Securities Financing Transaction [Line Items]
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.03
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2575	$ 0.2400	$ 0.7725	$ 0.7200

Financing Activities - Distribu

Financing Activities - Distributions (Details) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Distributions (Numeric) [Abstract]
Current quarterly common stock dividend (in dollars per share)	$ 0.2575	$ 0.2400	$ 0.7725	$ 0.7200
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.03

Acquisitions, Development and_2

Acquisitions, Development and Divestitures - Development (Details) $ in Millions			3 Months Ended			6 Months Ended	9 Months Ended			12 Months Ended
		Nov. 06, 2023 MW	Sep. 30, 2024 USD ($)		Sep. 30, 2023 USD ($)	Jun. 30, 2022 USD ($)	Sep. 30, 2024 USD ($)		Sep. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)
Business Acquisition [Line Items]
Transition Service Agreement Cost			$ 32		$ 59		$ 129		$ 179
Goodwill			2,247				2,247			$ 2,247
Operating Revenues from external customers			2,066		2,043		6,251		6,281
Net income (loss)			214		230		711		627
Indemnification for Safari sale/leaseback							25
Louisville Gas And Electric Co [Member]
Business Acquisition [Line Items]
Goodwill			389				389			389
Operating Revenues from external customers			397		398		1,239		1,227
Net income (loss)			77	[1]	79		232	[1]	210
New NGCC LG&E Planned Ownership Percentage		31%
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Kentucky Utilities Co [Member]
Business Acquisition [Line Items]
Goodwill			607				607			607
Operating Revenues from external customers			509		505		1,498		1,439
Net income (loss)	[2]		98		101		283		240
New NGCC KU Planned Ownership Percentage		69%
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Narragansett Electric
Business Acquisition [Line Items]
Total cash consideration						$ 3,800
Rhode Island Regulated
Business Acquisition [Line Items]
Operating Revenues from external customers			455		413		1,393		1,355	$ 1,400
Net income (loss)			14		6		90		70
Corporate and Other [Member]
Business Acquisition [Line Items]
Operating Revenues from external customers			0		0		1		0
Net income (loss)			(111)		(87)		(313)		(259)
Rhode Island Energy | Rhode Island Energy TSA
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense			85		69		250		193
Rhode Island Energy | Accrual for TSA Markup
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense			5		$ 2		8		$ 6
LGE [Member]
Business Acquisition [Line Items]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
KU [Member]
Business Acquisition [Line Items]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
LKE [Member]
Business Acquisition [Line Items]
ExpectedCapitalCostOfExpansionProject			$ 1,000				$ 1,000
[1] Net income equals comprehensive income. Net income equals comprehensive income.

Defined Benefits (Details)

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			$ 10	$ 14
Pension Plan [Member] | U.S.
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	$ 9	$ 8	26	25
Interest cost	45	47	137	141
Expected return on plan assets	(74)	(77)	(224)	(232)
Amortization of: [Abstract]
Prior service cost	1	2	2	5
Actuarial loss	3	1	8	2
Net periodic defined benefit costs (credits)	(16)	(19)	(51)	(59)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	2	1	5	4
Interest cost	8	8	22	23
Expected return on plan assets	(8)	(7)	(23)	(22)
Amortization of: [Abstract]
Prior service cost	0	0	1	1
Actuarial loss	(1)	(1)	(4)	(4)
Net periodic defined benefit costs (credits)	$ 1	$ 1	1	2
PPL Electric Utilities Corp [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			2	5
Louisville Gas And Electric Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			1	1
Kentucky Utilities Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			$ 1	$ 1

Commitments and Contingencies -

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Jun. 24, 2024	Dec. 31, 2023
Claim By Former Affiliate [Abstract]
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
Claim By Former Affiliate [Abstract]
Environmental Costs Recognized, Recovery Credited to Expense	$ 3
Gas Rates
Claim By Former Affiliate [Abstract]
Environmental Costs Recognized, Recovery Credited to Expense	1
RIE Environmental Remediation
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	99		$ 99
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		8
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 8		$ 8

Commitments and Contingencies_2

Commitments and Contingencies - Environmental Matters and Other (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (13)	$ (13)	$ (33)	$ (33)
Period RIE Environmental Remediation Costs To Be Incurred Over	30 years		30 years
RIE Environmental Remediation
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 99		$ 99		$ 99
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		8		8
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(3)	(4)	(8)	(8)
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		8		$ 8
Louisville Gas And Electric Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(3)	(3)	(9)	(9)
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (4)	$ (5)	$ (13)	$ (13)

Commitments and Contingencies_3

Commitments and Contingencies - Guarantees and Other Assurances (Details) - 9 months ended Sep. 30, 2024 £ in Millions, $ in Millions	USD ($)	GBP (£)	USD ($)
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
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | LGE [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			57
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | KU [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			25
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business [Domain]
Other Guarantee (Numeric) [Abstract]
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
Other Guarantee (Numeric) [Abstract]
Maximum exposure			105
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
Other Guarantee (Numeric) [Abstract]
Maximum exposure			140
LKE Guarantee [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			82
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Louisville Gas And Electric Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			57
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable
Kentucky Utilities Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			$ 25
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable from affiliates	$ 418		$ 418		$ 0
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]	CEP Reserves, Inc		CEP Reserves, Inc		CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 53	$ 52	$ 159	$ 166
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	800		800
Louisville Gas And Electric Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 34		$ 34		$ 0
Notes Payable, Related Party, Type [Extensible Enumeration]	Affiliated Entity [Member]		Affiliated Entity [Member]		Affiliated Entity [Member]
Louisville Gas And Electric Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 15	10	$ 46	30
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	716		716
Louisville Gas And Electric Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	25	25	82	85
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 128		$ 128		$ 0
Notes Payable, Related Party, Type [Extensible Enumeration]	Affiliated Entity [Member]		Affiliated Entity [Member]		Affiliated Entity [Member]
Kentucky Utilities Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 15	11	$ 45	33
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	522		522
Kentucky Utilities Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 31	$ 35	$ 99	$ 110

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Other Income
Defined benefit plans - non-service credits	$ 9	$ 13	$ 32	$ 30
AFUDC - equity component	13	7	33	21
Miscellaneous	0	(7)	0	(19)
Other Expense
Charitable Contributions	0	(1)	(4)	(3)
Other Income (Expense) - net	32	16	86	51
Interest Income (Expense), Nonoperating, Net	10	4	25	22
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	4	5	13	15
AFUDC - equity component	6	4	17	12
Miscellaneous	0	(2)	1	(2)
Other Expense
Charitable Contributions	0	0	(3)	(2)
Other Income (Expense) - net	13	8	33	29
Interest Income (Expense), Nonoperating, Net	3	1	5	6
Louisville Gas And Electric Co [Member]
Other Income
Defined benefit plans - non-service credits	0	0	3	0
AFUDC - equity component	2	1	5	2
Miscellaneous	1	(1)	0	0
Other Expense
Other Income (Expense) - net	3	0	9	2
Interest Income (Expense), Nonoperating, Net	0	0	1	0
Kentucky Utilities Co [Member]
Other Income
Defined benefit plans - non-service credits	2	0	6	4
AFUDC - equity component	3	1	6	2
Miscellaneous	(1)	0	(3)	0
Other Expense
Other Income (Expense) - net	4	1	10	6
Interest Income (Expense), Nonoperating, Net	$ 0	$ 0	$ 1	$ 0

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2024	Dec. 31, 2023
Assets
Cash and cash equivalents	$ 542	$ 331
Restricted cash and cash equivalents	41	51
Total Cash, Cash Equivalents and Restricted Cash	583	382
Special Use Funds [Abstract]
Money market fund	1	1
Commingled debt fund measured at NAV	4	9
Commingled equity fund measured at NAV	4	8
Total special use funds	9	18
Gas Contracts	2	1
Price risk management assets:
Total Assets	594	401
Price risk management liabilities:
Interest rate swaps	7	7
Gas Contracts	27	60
Total price risk management liabilities	34	67
Level 1 [Member]
Assets
Cash and cash equivalents	542	331
Restricted cash and cash equivalents	41	51
Total Cash, Cash Equivalents and Restricted Cash	583	382
Special Use Funds [Abstract]
Money market fund	1	1
Total special use funds	1	1
Gas Contracts	0	0
Price risk management assets:
Total Assets	584	383
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	0	0
Total price risk management liabilities	0	0
Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Special Use Funds [Abstract]
Money market fund	0	0
Total special use funds	0	0
Gas Contracts	1	1
Price risk management assets:
Total Assets	1	1
Price risk management liabilities:
Interest rate swaps	7	7
Gas Contracts	22	41
Total price risk management liabilities	29	48
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Special Use Funds [Abstract]
Money market fund	0	0
Total special use funds	0	0
Gas Contracts	1	0
Price risk management assets:
Total Assets	1	0
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	5	19
Total price risk management liabilities	5	19
Level 3 [Member] | Gas Contracts
Price risk management liabilities:
Gas Contracts, Liability, Settlements	(19)
Gas Contracts, Asset (Liability), Balance	4	19
Total unrealized gains (losses) on Regulatory Asset/Regulatory Liability	4
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	35	51
Price risk management assets:
Total Assets	35	51
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	35	51
Price risk management assets:
Total Assets	35	51
PPL Electric Utilities Corp [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
PPL Electric Utilities Corp [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	10	18
Restricted cash and cash equivalents	20	26
Total Cash, Cash Equivalents and Restricted Cash	30	44
Price risk management assets:
Total Assets	30	44
Price risk management liabilities:
Interest rate swaps	7	7
Total price risk management liabilities	7	7
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	10	18
Restricted cash and cash equivalents	20	26
Total Cash, Cash Equivalents and Restricted Cash	30	44
Price risk management assets:
Total Assets	30	44
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	7	7
Total price risk management liabilities	7	7
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	16	14
Restricted cash and cash equivalents	20	24
Total Cash, Cash Equivalents and Restricted Cash	36	38
Price risk management assets:
Total Assets	36	38
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	16	14
Restricted cash and cash equivalents	20	24
Total Cash, Cash Equivalents and Restricted Cash	36	38
Price risk management assets:
Total Assets	36	38
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	$ 0	$ 0

Fair Value Measurements - Finan

Fair Value Measurements - Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 16,500	$ 14,612
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	16,431	14,031
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,213	4,567
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,230	4,475
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	2,470	2,469
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	2,424	2,369
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	3,065	3,064
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 2,940	$ 2,861

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Master Netting Arrangements (Numeric) [Line Items]
Cash collateral obligation under master netting arrangements	$ 0	$ 0
Cash collateral posted under master netting arrangements	0	0
Louisville Gas And Electric Co [Member]
Master Netting Arrangements (Numeric) [Line Items]
Cash collateral obligation under master netting arrangements	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 arrangements	0	0
Cash collateral posted under master netting arrangements	$ 0	$ 0

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Risk Disclosures (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024 USD ($) Bcf	Sep. 30, 2023 USD ($)	Sep. 30, 2024 USD ($)	Sep. 30, 2023 USD ($)	Dec. 31, 2023 USD ($)
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	$ 0
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	0		0		$ 0
Cash collateral pledged - eligible for offset	0		0		0
Cash collateral pledged - eligible for offset	0		0		0
Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	2		2		1
Liability value	34		34		67
Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	2		2		1
Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	23		23		52
Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	11		11		15
Interest Rate Swaps [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Interest Rate Swaps [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Interest Rate Swaps [Member] | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value					1
Interest Rate Swaps [Member] | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value					6
Gas Contract | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	2		2		1
Gas Contract | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Gas Contract | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	22		22		51
Gas Contract | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	5		5		9
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Derivative, Notional Amount	$ 64		64
Rhode Island Energy | Economic Hedges [Member] | Gas Contract
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf	55
Louisville Gas And Electric Co [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	$ 0		0		0
Cash collateral pledged - eligible for offset	0		0		0
Cash collateral pledged - eligible for offset	0		0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Liability value	7		7		7
Louisville Gas And Electric Co [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Louisville Gas And Electric Co [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Derivative, Notional Amount	64		64
Kentucky Utilities Co [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	0		0		0
Cash collateral pledged - eligible for offset	0		0		0
Cash collateral pledged - eligible for offset	$ 0		$ 0		$ 0

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Fair Values (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 2	$ 1
Liability value	34	67
Louisville Gas And Electric Co [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	$ 7	$ 7

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023	Dec. 31, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	$ 188	$ 165	$ 549	$ 494
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	32	16	86	51
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Comprehensive Income (Loss) [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Derivative Gain (Loss) Recognized in OCI	0	0	0	0
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income	(1)	(1)	(3)	(3)
Amount of gain (loss) reclassified from AOCI to income	(1)	(1)	(3)	(3)
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(6)	(5)	(31)	(12)
Gain (loss) recognized as regulatory liabilities/assets	(8)	(8)	34	11
Asset value	2		2		$ 1
Liability value	34		34		67
Not Designated As Hedging Instruments [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		0
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		0
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	(3)	4	0	4
Not Designated As Hedging Instruments [Member] | Gas Contracts
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(6)		$ (31)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]			Energy purchases
Not Designated As Hedging Instruments [Member] | Gas Contracts | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	(3)		$ 3
Not Designated As Hedging Instruments [Member] | Gas Contracts | Regulatory Assets, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	(2)		31
Not Designated As Hedging Instruments [Member] | Gas Contracts | Other Nonoperating Income (Expense)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative		(1)		(1)
Not Designated As Hedging Instruments [Member] | Gas Contracts | Purchased Power And Gas
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative		(4)		(11)
Not Designated As Hedging Instruments [Member] | Gas Contract | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		0
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		2		(5)
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		(14)		12
Louisville Gas And Electric Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	26	25	78	76
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	3	0	9	2
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		0
Liability value	7		7		7
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Price risk management liabilities, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1		1		1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Price risk management, liabilities, noncurrent
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	6		6		6
Louisville Gas And Electric Co [Member] | 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	$ 0	$ 0
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense	Interest Expense	Interest Expense	Interest Expense
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	$ 0		$ 0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Price risk management liabilities, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value					1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Price risk management, liabilities, noncurrent
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value					$ 6
Louisville Gas And Electric Co [Member] | 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	(3)	$ 4	0	$ 4
Kentucky Utilities Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense			102	99
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	$ 4	$ 1	$ 10	$ 6

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Assets [Abstract]
Cash collateral received - eligible for offset	$ 0	$ 0
Liabilities [Abstract]
Cash collateral pledged - eligible for offset	0	0
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	19
Derivative, Net Liability Position, Aggregate Fair Value	18
Treasury Derivatives [Member]
Assets [Abstract]
Gross	2	1
Derivative instruments - eligible for offset	2	0
Cash collateral received - eligible for offset	0	0
Net	0	1
Liabilities [Abstract]
Gross	34	67
Derivative instruments - eligible for offset	2	0
Cash collateral pledged - eligible for offset	0	0
Net	32	67
Louisville Gas And Electric Co [Member]
Assets [Abstract]
Cash collateral received - eligible for offset	0	0
Liabilities [Abstract]
Cash collateral pledged - eligible for offset	0	0
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross		7
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 7	$ 7

Derivative Instruments and He_9

Derivative Instruments and Hedging Activities - Commodity Purchases (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Sep. 30, 2024	Dec. 31, 2023
Commodity Purchases [Line Items]
Liability value	$ 34	$ 67
Asset value	2	1
Other Current Assets
Commodity Purchases [Line Items]
Asset value	2	1
Other Current Assets | Gas Contract
Commodity Purchases [Line Items]
Asset value	2	1
Other Current Assets | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Current Liabilities
Commodity Purchases [Line Items]
Liability value	23	52
Other Current Liabilities | Gas Contract
Commodity Purchases [Line Items]
Liability value	22	51
Other Current Liabilities | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Liability value		1
Other Noncurrent Assets [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Assets [Member] | Gas Contract
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Liabilities
Commodity Purchases [Line Items]
Liability value	11	15
Other Noncurrent Liabilities | Gas Contract
Commodity Purchases [Line Items]
Liability value	$ 5	9
Other Noncurrent Liabilities | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Liability value		$ 6

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Millions	9 Months Ended
	Sep. 30, 2024 USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 158
Accretion	6
New Obligation s Incurred	8
Changes in estimated timing or cost	1
Obligations settled	(15)
Asset Retirement Obligations, Period Change, Miscellaneous	2
Balance at End of Period	160
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	85
Accretion	3
New Obligation s Incurred	3
Changes in estimated timing or cost	1
Obligations settled	(8)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	84
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	66
Accretion	3
New Obligation s Incurred	5
Changes in estimated timing or cost	(1)
Obligations settled	(7)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	$ 66

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (160)	$ (137)	$ (163)	$ (124)
Amounts arising during the period	(4)	(6)	(1)	(20)
Reclassifications from AOCI	1	1	1	2
Net OCI during the period	(3)	(5)	0	(18)
Balance at end of period	(163)	(142)	(163)	(142)
Unrealized gains (losses) on qualifying derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	7	4	6	3
Amounts arising during the period	0	0	0	0
Reclassifications from AOCI	2	1	3	2
Net OCI during the period	2	1	3	2
Balance at end of period	9	5	9	5
Equity Investees' OCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	4	3	3	2
Amounts arising during the period	0	0	1	1
Reclassifications from AOCI	0	0	0	0
Net OCI during the period	0	0	1	1
Balance at end of period	4	3	4	3
Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(167)	(140)	(168)	(124)
Amounts arising during the period	(4)	(6)	(2)	(21)
Reclassifications from AOCI	(1)	0	(2)	(1)
Net OCI during the period	(5)	(6)	(4)	(22)
Balance at end of period	(172)	(146)	(172)	(146)
Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(4)	(4)	(4)	(5)
Amounts arising during the period	0	0	0	0
Reclassifications from AOCI	0	0	0	1
Net OCI during the period	0	0	0	1
Balance at end of period	$ (4)	$ (4)	$ (4)	$ (4)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2024	Sep. 30, 2023	Sep. 30, 2024	Sep. 30, 2023
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (188)	$ (165)	$ (549)	$ (494)
Other Income (Expense) - net	32	16	86	51
Income Tax Expense (Benefit)	(58)	(58)	(189)	(170)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(1)	(1)	(1)	(2)
Defined Benefit Plans [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	1	(1)	3	0
Income Tax Expense (Benefit)	0	1	(1)	0
Total After-tax	1	0	2	0
Defined Benefit Plans [Member] | Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	1	(1)	3	1
Defined Benefit Plans [Member] | Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	0	0	0	(1)
Unrealized gains (losses) on qualifying derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	(1)	(1)	(3)	(3)
Income Tax Expense (Benefit)	(1)	0	0	1
Total After-tax	(2)	(1)	(3)	(2)
Unrealized gains (losses) on qualifying derivatives [Member] | Interest Rate Swaps [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (1)	$ (1)	$ (3)	$ (3)