PPL Electric Utilities 10-Q 2 Nov 23 2022 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2023	Oct. 30, 2023
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	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
Document Type	10-Q
Document Period End Date	Sep. 30, 2023
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		737,124,389
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	Two North Ninth Street
Entity Address, City or Town	Allentown,
Entity Address, State or Province	PA
Entity Address, Postal Zip Code	18101-1179
City Area Code	(610)
Local Phone Number	774-5151
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, 2023		Sep. 30, 2022		Sep. 30, 2023		Sep. 30, 2022
Operating Revenues
Operating Revenues		$ 2,043		$ 2,134		$ 6,281		$ 5,612
Operation
Fuel		199		267		567		708
Energy purchases		356		436		1,430		1,093
Other operation and maintenance		637		678		1,805		1,671
Depreciation		314		312		940		872
Taxes, other than income		100		100		299		230
Total Operating Expenses		1,606		1,793		5,041		4,574
Operating Income		437		341		1,240		1,038
Other Income (Expense) - net		16		10		51		36
Interest Expense		165		136		494		361
Income Taxes		58		41		170		147
Net Income (Loss)		$ 230		$ 174		$ 627		$ 566
Net Income:
Diluted (in dollars per share)		$ 0.31		$ 0.24		$ 0.85		$ 0.77
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		737,107		736,247		737,005		735,912
Diluted (in shares)		738,184		737,074		738,021		736,679
Income from Continuing Operations Before Income Taxes		$ 288		$ 215		$ 797		$ 713
Income (Loss) from Continuing Operations After Income Taxes, Basic		$ 0.31		$ 0.24		$ 0.85		$ 0.77
Income (Loss) from Continuing Operations after income taxes, Diluted		$ 0.31		$ 0.24		$ 0.85		$ 0.77
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		$ 737		$ 766		$ 2,295		$ 2,217
Operation
Energy purchases		226		285		788		759
Other operation and maintenance		151		127		454		415
Depreciation		99		99		297		296
Taxes, other than income		36		39		110		108
Total Operating Expenses		512		550		1,649		1,578
Operating Income		225		216		646		639
Other Income (Expense) - net		8		6		29		19
Interest Expense		54		43		165		122
Income Taxes		43		37		126		131
Net Income (Loss)	[1]	136		143		384		410
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		179		180		510		541
PPL Electric Utilities Corp [Member] | Related Party
Operation
Interest Income from affiliate		0		1		0		5
Louisville Gas And Electric Co [Member]
Operating Revenues
Operating Revenues		398		436		1,227		1,339
Operation
Fuel		70		94		217		265
Energy purchases		17		28		123		162
Energy purchases from affiliate		8		9		11		18
Other operation and maintenance		91		98		275		301
Depreciation		76		74		227		223
Taxes, other than income		12		12		36		36
Total Operating Expenses		274		315		889		1,005
Operating Income		124		121		338		334
Other Income (Expense) - net		0		0		2		3
Interest Expense		25		23		76		64
Income Taxes		21		21		55		49
Net Income (Loss)		79	[2]	77	[2]	210	[2]	224
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		100		98		265		273
Louisville Gas And Electric Co [Member] | Related Party
Operating Revenues
Retail and wholesale		2		3		23		26
Operation
Interest Income from affiliate		1		0		1		0
Louisville Gas And Electric Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		396		433		1,204		1,313
Kentucky Utilities Co [Member]
Operating Revenues
Operating Revenues		505		553		1,439		1,569
Operation
Fuel		129		174		350		444
Energy purchases		6		6		18		18
Energy purchases from affiliate		2		3		23		26
Other operation and maintenance		101		115		327		348
Depreciation		98		96		294		289
Taxes, other than income		12		11		34		33
Total Operating Expenses		348		405		1,046		1,158
Operating Income		157		148		393		411
Other Income (Expense) - net		1		2		6		6
Income Taxes		24		24		59		63
Net Income (Loss)	[3]	101		95		240		268
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		125		119		299		331
Kentucky Utilities Co [Member] | Related Party
Operating Revenues
Retail and wholesale		8		9		11		18
Operation
Interest Expense		0		0		1		0
Kentucky Utilities Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		497		544		1,428		1,551
Operation
Interest Expense		$ 33		$ 31		$ 99		$ 86
[1]Net income equals comprehensive income.[2]Net income equals comprehensive income.[3]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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net income (loss)	$ 230	$ 174	$ 627	$ 566
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investees' other comprehensive income (loss), net of tax	0	0	1	2
Prior Service Costs, net of tax	0	0	0	(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	(6)	(10)	(21)	11
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	1	0	2	1
Other Comprehensive (Income) Loss, Defined Benefit Plans, after Reclassification Adjustment, after Tax [Abstract]
Defined benefit plans, Prior service costs, net of tax	0	1	1	2
Defined benefit plans, Net actuarial (gain) loss, net of tax	0	3	(1)	12
Total other comprehensive income (loss)	(5)	(6)	(18)	27
Comprehensive income (loss)	$ 225	$ 168	$ 609	$ 593

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Tax effect of net actuarial (gain) loss arising during period	$ 2	$ 4	$ 7	$ (3)
Tax effect of qualifying derivatives reclassified from AOCI	0	0	(1)	(1)
Tax effect of prior service costs reclassified from AOCI	0	(1)	0	1
Tax effect of net actuarial (gain) loss reclassified from AOCI	(1)	(2)	0	(5)
Tax effect of equity investee's other comprehensive income (loss)	0	0	0	0
Tax effect of Prior Service Costs	$ 0	$ 0	$ 0	$ 0

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		9 Months Ended
		Sep. 30, 2023		Sep. 30, 2022
Cash Flows from Operating Activities
Net income (loss)		$ 627		$ 566
Depreciation		940		872
Amortization		61		30
Defined benefit plans - (income) expense		(55)		(12)
Deferred income taxes and investment tax credits		142		55
Stock-based compensation expense		22		23
Impairment of assets held for sale		0		67
Other		(23)		21
Change in current assets and current liabilities
Accounts receivable		(37)		(103)
Accounts payable		(129)		120
Unbilled revenues		224		42
Fuel, materials and supplies		(43)		(71)
Prepayments		(44)		(23)
Taxes payable		(15)		(14)
Regulatory assets and liabilities, net		(27)		(158)
Accrued interest		123		59
Other		(2)		52
Other operating activities
Defined benefit plans - funding		(14)		(8)
Other assets		(58)		(77)
Other liabilities		(44)		70
Net cash provided by operating activities		1,648		1,511
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(1,741)		(1,515)
Acquisition of Narragansett Electric, net of cash acquired		0		(3,674)
Other investing activities		2		3
Net cash used in investing activities		(1,739)		(5,186)
Cash Flows from Financing Activities
Issuance of long-term debt		3,127		850
Retirement of long-term debt		(1,763)		(263)
Payment of common stock dividends		(526)		(620)
Net increase (decrease) in short-term debt		(698)		441
Other financing activities		(52)		(1)
Net cash provided by financing activities		88		407
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(3)		(3,268)
Cash and Cash Equivalents at Beginning of Period		356
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		357		3,572
Cash and Cash Equivalents at End of Period		353
Cash, Cash Equivalents and Restricted Cash at End of Period		354		304
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		200		239
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	384		410
Depreciation		297		296
Amortization		31		10
Defined benefit plans - (income) expense		(32)		(17)
Deferred income taxes and investment tax credits		59		67
Other		(19)		(12)
Change in current assets and current liabilities
Accounts receivable		(104)		(73)
Accounts payable		(56)		(39)
Unbilled revenues		110		11
Fuel, materials and supplies		(33)		(22)
Prepayments		(22)		(12)
Taxes payable		(24)		(26)
Regulatory assets and liabilities, net		(41)		(57)
Accrued interest		50		10
Other		(5)		(25)
Other operating activities
Defined benefit plans - funding		(5)		0
Other assets		(2)		(15)
Other liabilities		1		(8)
Net cash provided by operating activities		589		498
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(653)		(621)
Expenditures for intangible assets		(4)		0
Notes receivable from affiliates		0		499
Other investing activities		2		2
Net cash used in investing activities		(655)		(120)
Cash Flows from Financing Activities
Issuance of long-term debt		1,329		250
Retirement of long-term debt		(1,150)		(250)
Payment of common stock dividends to parent		(235)		(246)
Net increase (decrease) in short-term debt		42		0
Contributions from parent		200		0
Return of capital to parent		(75)		(130)
Other financing activities		0		(1)
Debt Issuance Costs		(14)		0
Net cash provided by financing activities		97		(377)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		31		1
Cash and Cash Equivalents at Beginning of Period		25
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		25		21
Cash and Cash Equivalents at End of Period		56
Cash, Cash Equivalents and Restricted Cash at End of Period		56		22
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		119		150
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)		210	[2]	224
Depreciation		227		223
Amortization		9		(1)
Defined benefit plans - (income) expense		0		(1)
Deferred income taxes and investment tax credits		(3)		(3)
Other		(7)		3
Change in current assets and current liabilities
Accounts receivable		37		15
Accounts receivable from affiliates		17		5
Accounts payable		(51)		10
Increase (Decrease) in Accounts Payable, Related Parties		(9)		19
Unbilled revenues		43		11
Fuel, materials and supplies		25		(22)
Taxes payable		(4)		4
Regulatory assets and liabilities, net		34		(12)
Accrued interest		29		17
Other		(3)		(4)
Other operating activities
Defined benefit plans - funding		(1)		(2)
Expenditures for asset retirement obligations		(9)		(10)
Other assets		(19)		(3)
Other liabilities		1		0
Net cash provided by operating activities		526		473
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(277)		(273)
Net cash used in investing activities		(277)		(273)
Cash Flows from Financing Activities
Issuance of long-term debt		399		300
Retirement of long-term debt		(300)		0
Increase Decrease In Notes Payable To Affiliates		6		(310)
Payment of common stock dividends to parent		(115)		(224)
Net increase (decrease) in short-term debt		(179)		41
Contributions from parent		20		10
Return of capital to parent		(161)		0
Other financing activities		(4)		(1)
Net cash provided by financing activities		(334)		(184)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(85)		16
Cash and Cash Equivalents at Beginning of Period		93		9
Cash and Cash Equivalents at End of Period		8		25
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		30		36
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	240		268
Depreciation		294		289
Amortization		14		12
Defined benefit plans - (income) expense		(4)		(3)
Deferred income taxes and investment tax credits		(7)		(2)
Other		0		3
Change in current assets and current liabilities
Accounts receivable		10		(17)
Accounts payable		(31)		7
Increase (Decrease) in Accounts Payable, Related Parties		(27)		22
Unbilled revenues		28		4
Fuel, materials and supplies		(8)		(17)
Taxes payable		8		15
Regulatory assets and liabilities, net		30		(20)
Accrued interest		37		26
Other		(2)		(5)
Other operating activities
Defined benefit plans - funding		(1)		(1)
Expenditures for asset retirement obligations		(17)		(23)
Other assets		(22)		1
Other liabilities		(2)		(3)
Net cash provided by operating activities		540		556
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(430)		(397)
Other investing activities		5		0
Net cash used in investing activities		(425)		(397)
Cash Flows from Financing Activities
Issuance of long-term debt		399		300
Retirement of long-term debt		(313)		0
Increase Decrease In Notes Payable To Affiliates		21		(272)
Payment of common stock dividends to parent		(125)		(234)
Net increase (decrease) in short-term debt		(76)		0
Contributions from parent		54		60
Return of capital to parent		(84)		0
Other financing activities		(4)		(1)
Net cash provided by financing activities		(128)		(147)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(13)		12
Cash and Cash Equivalents at Beginning of Period		21		13
Cash and Cash Equivalents at End of Period		8		25
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at September 30,		$ 45		$ 46
[1]Net income equals comprehensive income.[2]Net income equals comprehensive income.[3]Net income equals comprehensive income.

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Sep. 30, 2023	Dec. 31, 2022
Assets, Current [Abstract]
Cash and cash equivalents		$ 353	$ 356
Accounts receivable (less reserve:)
Customer		1,019	896
Other		49	150
Unbilled revenues		328	552
Fuel, materials and supplies		488	443
Prepayments		143	92
Regulatory Assets, Current		315	258
Other current assets		59	77
Total Current Assets		2,754	2,824
Property, Plant and Equipment
Regulated utility plant		38,148	36,961
Less:  accumulated depreciation - regulated utility plant		8,976	8,352
Regulated utility plant, net		29,172	28,609
Non-regulated property, plant and equipment		70	92
Less:  accumulated depreciation - non-regulated property, plant and equipment		21	46
Non-regulated property, plant and equipment, net		49	46
Construction work in progress		1,849	1,583
Property, Plant and Equipment, net		31,070	30,238
Other Noncurrent Assets
Regulatory assets		1,787	1,819
Goodwill		2,247	2,248
Other intangibles		307	313
Other noncurrent assets		464	395
Assets, Noncurrent		4,805	4,775
Total Assets		38,629	37,837
Current Liabilities
Short-term debt		287	985
Long-term debt due within one year		91	354
Accounts payable		1,178	1,201
Taxes		109	124
Interest		220	97
Dividends		173	166
Regulatory liabilities		280	238
Other current liabilities		541	624
Liabilities, Current, Total		2,879	3,789
Long-term Debt, Unclassified [Abstract]
Long-term Debt		14,484	12,889
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,049	3,007
Investment tax credits		114	117
Accrued pension obligations		199	206
Asset retirement obligations		140	138
Regulatory liabilities		3,384	3,412
Other deferred credits and noncurrent liabilities		368	361
Total Deferred Credits and Other Noncurrent Liabilities		7,254	7,241
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,319	12,317
Treasury Stock		(948)	(967)
Earnings reinvested		2,775	2,681
Accumulated other comprehensive loss		(142)	(124)
Total Shareowners' Common Equity		14,012	13,915
Noncontrolling interests		0	3
Total Equity		14,012	13,918
Total Liabilities and Equity		38,629	37,837
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		56	25
Accounts receivable (less reserve:)
Other		6	12
Unbilled revenues		114	224
Notes Receivable from affiliates		0	0
Fuel, materials and supplies		102	69
Prepayments		63	34
Regulatory Assets, Current		52	13
Other current assets		32	22
Total Current Assets		876	759
Property, Plant and Equipment
Regulated utility plant		15,323	14,794
Less:  accumulated depreciation - regulated utility plant		3,761	3,544
Regulated utility plant, net		11,562	11,250
Construction work in progress		664	593
Property, Plant and Equipment, net		12,226	11,843
Other Noncurrent Assets
Regulatory assets		561	568
Other intangibles		268	269
Other noncurrent assets		138	126
Assets, Noncurrent		967	963
Total Assets		14,069	13,565
Current Liabilities
Short-term debt		187	145
Long-term debt due within one year		90	340
Taxes		12	36
Interest		85	35
Regulatory liabilities		83	85
Other current liabilities		92	86
Liabilities, Current, Total		972	1,223
Long-term Debt, Unclassified [Abstract]
Long-term Debt		4,566	4,146
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,576	1,514
Regulatory liabilities		838	820
Other deferred credits and noncurrent liabilities		92	111
Total Deferred Credits and Other Noncurrent Liabilities		2,506	2,445
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,209	4,084
Earnings reinvested		1,452	1,303
Total Equity		6,025	5,751
Total Liabilities and Equity		14,069	13,565
PPL Electric Utilities Corp [Member] | Related Party
Accounts receivable (less reserve:)
Customer		4	3
Current Liabilities
Accounts payable		30	16
PPL Electric Utilities Corp [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		447	357
Current Liabilities
Accounts payable		393	480
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		8	93
Accounts receivable (less reserve:)
Other		20	13
Unbilled revenues		69	112
Fuel, materials and supplies		141	166
Prepayments		15	13
Regulatory Assets, Current		5	23
Other current assets		3	2
Total Current Assets		396	616
Property, Plant and Equipment
Regulated utility plant		7,591	7,429
Less:  accumulated depreciation - regulated utility plant		1,495	1,355
Regulated utility plant, net		6,096	6,074
Construction work in progress		305	268
Property, Plant and Equipment, net		6,401	6,342
Other Noncurrent Assets
Regulatory assets		380	373
Goodwill		389	389
Other intangibles		19	24
Other noncurrent assets		75	66
Assets, Noncurrent		863	852
Total Assets		7,660	7,810
Current Liabilities
Short-term debt		$ 0	$ 179
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Notes Payable to affiliates		$ 6	$ 0
Taxes		37	41
Price risk management liabilities current		0	1
Interest		44	15
Current Customer Deposits		34	32
Regulatory liabilities		23	7
Asset Retirement Obligation, Current		12	13
Other current liabilities		48	46
Liabilities, Current, Total		356	559
Long-term Debt, Unclassified [Abstract]
Long-term Debt		2,404	2,307
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		781	771
Investment tax credits		31	31
Asset retirement obligations		74	73
Regulatory liabilities		830	833
Price risk management liabilities		3	6
Other deferred credits and noncurrent liabilities		61	64
Total Deferred Credits and Other Noncurrent Liabilities		1,780	1,778
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,946	2,087
Earnings reinvested		750	655
Total Equity		3,120	3,166
Total Liabilities and Equity		7,660	7,810
Louisville Gas And Electric Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		19	37
Current Liabilities
Accounts payable		48	60
Louisville Gas And Electric Co [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		116	157
Current Liabilities
Accounts payable		104	165
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		8	21
Accounts receivable (less reserve:)
Customer		150	158
Other		10	13
Unbilled revenues		86	114
Fuel, materials and supplies		176	167
Prepayments		15	14
Regulatory Assets, Current		7	32
Other current assets		0	1
Total Current Assets		452	520
Property, Plant and Equipment
Regulated utility plant		9,794	9,515
Less:  accumulated depreciation - regulated utility plant		2,404	2,201
Regulated utility plant, net		7,390	7,314
Construction work in progress		597	522
Property, Plant and Equipment, net		7,987	7,836
Other Noncurrent Assets
Regulatory assets		442	442
Goodwill		607	607
Other intangibles		19	21
Other noncurrent assets		128	116
Assets, Noncurrent		1,196	1,186
Total Assets		9,635	9,542
Current Liabilities
Short-term debt		25	101
Long-term debt due within one year		$ 0	$ 13
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Notes Payable to affiliates		$ 21	$ 0
Taxes		35	26
Interest		56	19
Current Customer Deposits		35	33
Regulatory liabilities		11	6
Asset Retirement Obligation, Current		16	26
Other current liabilities		53	51
Liabilities, Current, Total		404	499
Long-term Debt, Unclassified [Abstract]
Long-term Debt		3,004	2,907
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		909	896
Investment tax credits		84	85
Asset retirement obligations		58	56
Regulatory liabilities		1,022	1,029
Other deferred credits and noncurrent liabilities		31	32
Total Deferred Credits and Other Noncurrent Liabilities		2,104	2,098
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		3,011	3,041
Earnings reinvested		804	689
Total Equity		4,123	4,038
Total Liabilities and Equity		9,635	9,542
Kentucky Utilities Co [Member] | Related Party
Current Liabilities
Accounts payable		70	101
Kentucky Utilities Co [Member] | Nonrelated Party
Current Liabilities
Accounts payable		$ 82	$ 123
[1]1,560,000 shares authorized, 770,013 shares issued and 737,124 shares outstanding at September 30, 2023. 1,560,000 shares authorized, 770,013 shares issued and 736,487 shares outstanding at December 31, 2022.[2]170,000 shares authorized; 66,368 shares issued and outstanding at September 30, 2023 and December 31, 2022.[3]75,000 shares authorized; 21,294 shares issued and outstanding at September 30, 2023 and December 31, 2022.[4]80,000 shares authorized; 37,818 shares issued and outstanding at September 30, 2023 and December 31, 2022.

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 114	$ 87
Unbilled revenues, reserve	3	6
Reserve for accounts receivable (noncurrent)	$ 3	$ 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)	770,013	770,013
Common stock shares outstanding (in shares)	737,124	736,487
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 43	$ 28
Unbilled revenues, reserve	1	2
Reserve for accounts receivable (noncurrent)	$ 3	$ 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	$ 5	$ 4
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	$ 3
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		$ 13,723	$ 8		$ 12,303	$ 2,572	$ (157)	$ (1,003)	$ 0	$ 5,736		$ 364		$ 4,254	$ 1,118	$ 3,079		$ 424		$ 1,997	$ 658	$ 3,928		$ 308		$ 2,957	$ 663
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.650
Balance at beginning of period - shares at Dec. 31, 2021			735,112	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Common stock shares issued	[1]		123
Common stock issued		$ 12			12
Stock Issued During Period, Value, Treasury Stock Reissued		31						$ 31
Stock Issued During Period, Shares, Treasury Stock Reissued								1,076
Stock-based compensation		2			2
Net income (loss)		566				566				410	[5]				410	224					224	268	[6]				268
Capital contributions from parent																10				10		60				60
Dividends and dividend equivalents	[7]	(480)				(480)
Dividends declared										(246)					(246)	(224)					(224)	(234)					(234)
Other comprehensive income (loss)		27					27
Balance at end of period - shares at Sep. 30, 2022			736,311	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Contributions from parent										0						10						60
Return of Capital to Parent										(130)				(130)
Preferred stock		3
Total Equity		$ 13,873	$ 8		12,313	2,649	(124)	$ (976)	3	5,773		$ 364		4,189	1,220	3,100		$ 424		2,007	669	4,002		$ 308		3,017	677
Dividends Declared Per Share of Common Stock (in dollars per share)		$ 0.225
Balance at beginning of period - shares at Jun. 30, 2022			736,157									66,368	[2]					21,294	[3]					37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued		$ 4						$ 4
Stock Issued During Period, Shares, Treasury Stock Reissued								154
Stock-based compensation		4			4
Net income (loss)		174				174				143	[5]				143	77	[8]				77	95	[6]				95
Dividends and dividend equivalents		(165)				(165)
Dividends declared										(81)					(81)	(88)					(88)	(75)					(75)
Other comprehensive income (loss)		(6)					(6)
Balance at end of period - shares at Sep. 30, 2022			736,311	[1]								66,368	[2]					21,294	[3]					37,818	[4]
Return of Capital to Parent										(65)				(65)
Total Equity		13,884	$ 8		12,317	2,658	(130)	$ (972)	3	5,770		$ 364		4,124	1,282	3,089		$ 424		2,007	658	4,022		$ 308		3,017	697
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)		$ 0.720
Balance at beginning of period - shares at Dec. 31, 2022		736,487	736,487	[1]						66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at beginning of period at Dec. 31, 2022		$ 13,915
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	[8]				210	$ 240	[6]				240
Capital contributions from parent										200				200						20						54
Dividends and dividend equivalents	[7]	(533)				(533)
Dividends declared										$ (235)					(235)	$ (115)					(115)	$ (125)					(125)
Other comprehensive income (loss)		$ (18)					(18)
Balance at end of period - shares at Sep. 30, 2023		737,124	737,124							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Sep. 30, 2023		$ 14,012
Contributions from parent										$ 200						$ 20						$ 54
Return of Capital to Parent										(75)				(75)						(161)						(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)		$ 0.240
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			0			$ 1
Treasury stock acquired								38
Stock-based compensation		3			3
Net income (loss)		230				230				136	[5]				136	79	[8]				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	737,124							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Balance at end of period at Sep. 30, 2023		$ 14,012
Return of Capital to Parent										$ (50)				(50)						(41)						(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
[1]Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting.[2]Shares in thousands. All common shares of PPL Electric stock are owned by PPL Energy Holdings.[3]Shares in thousands. All common shares of LG&E stock are owned by LKE.[4]Shares in thousands. All common shares of KU stock are owned by LKE.[5]Net income equals comprehensive income.[6]Net income equals comprehensive income.[7] Dividends declared per share of common stock were $0.240 and $0.720 for the three and nine months ended September 30, 2023 and $0.225 and $0.650 for the three and nine months ended September 30, 2022.

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical) - vote	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
Vote per share of PPL's common stock	1	1

Segment and Related Information

Segment and Related Information	9 Months Ended
	Sep. 30, 2023
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. Beginning on January 1, 2023, the Kentucky Regulated segment consists primarily of the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. Prior to January 1, 2023, the Kentucky Regulated segment also included the financing activities of LKE. The financing activity of LKE is presented in "Corporate and Other" beginning on January 1, 2023. Prior periods have been adjusted to reflect this change. As a result, PPL’s segments consist of its regulated operations in Kentucky, Pennsylvania and Rhode Island and exclude any incremental financing activities of holding companies, which Management believes is a more meaningful presentation as it provides information on the core regulated operations of PPL. The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. The Rhode Island Regulated segment includes the regulated electricity transmission and distribution and natural gas distribution operations of RIE, which were acquired on May 25, 2022. "Corporate and Other" primarily includes corporate level financing costs, certain unallocated costs, certain non-recoverable costs incurred in conjunction with the acquisition of Narragansett Electric and the financial results of Safari Energy, prior to its sale on November 1, 2022. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results. 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 2023 2022 2023 2022 Operating Revenues from external customers Kentucky Regulated $ 893 $ 977 $ 2,631 $ 2,864 Pennsylvania Regulated 737 766 2,295 2,217 Rhode Island Regulated 413 384 1,355 512 Corporate and Other — 7 — 19 Total $ 2,043 $ 2,134 $ 6,281 $ 5,612 Net Income (Loss) Kentucky Regulated $ 175 $ 164 $ 432 $ 465 Pennsylvania Regulated 136 143 384 410 Rhode Island Regulated 6 (26) 70 (55) Corporate and Other (87) (107) (259) (254) Total $ 230 $ 174 $ 627 $ 566 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 $ 16,867 $ 16,904 Pennsylvania Regulated 14,069 13,565 Rhode Island Regulated 6,393 6,081 Corporate and Other (a) 1,300 1,287 Total $ 38,629 $ 37,837 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2023
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 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. The If-Converted Method will be applied to the Exchangeable Senior Notes due 2028 issued in February 2023. See Note 7 for additional information. 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 2023 2022 2023 2022 Income (Numerator) Net income attributable to PPL $ 230 $ 174 $ 627 $ 566 Less amounts allocated to participating securities — — 1 — Net income available to PPL common shareowners - Basic and Diluted $ 230 $ 174 $ 626 $ 566 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,107 736,247 737,005 735,912 Add: Dilutive share-based payment awards 1,077 827 1,016 767 Weighted-average shares - Diluted EPS 738,184 737,074 738,021 736,679 Basic and Diluted EPS Net Income available to PPL common shareowners $ 0.31 $ 0.24 $ 0.85 $ 0.77 For the periods ended September 30, PPL issued shares of common stock related to stock-based compensation plans as follows (in thousands): Three Months Nine Months 2023 2022 2023 2022 Stock-based compensation plans — — — 124 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 2023 2022 2023 2022 Stock-based compensation awards 179 17 324 79

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 60 $ 45 $ 167 $ 150 Increase (decrease) due to: State income taxes, net of federal income tax benefit 16 8 49 56 Valuation allowance adjustments 1 (1) 6 9 Income tax credits (a) (9) (1) (11) (3) Amortization of investment tax credit including deferred taxes on basis adjustment (1) — (2) (7) Depreciation and other items not normalized (2) — (9) (8) Amortization of excess deferred federal and state income taxes (13) (7) (33) (47) Federal and state income tax return adjustments 3 — (2) (1) State income tax rate change (b) 1 (5) — (5) Other 2 2 5 3 Total increase (decrease) (2) (4) 3 (3) Total income tax expense (benefit) $ 58 $ 41 $ 170 $ 147 (a) The three and nine month periods ended September 30, 2023 primarily include a deferred tax benefit from renewable tax credits that will be acquired at a discount. (b) The three and nine months ended September 30, 2022 include a deferred tax benefit of $5 million, due to the corporate net income tax rate reduction. See "Pennsylvania State Tax Reform" below for additional information. (PPL Electric) Three Months Nine Months 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 38 $ 38 $ 107 $ 114 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 14 36 43 Depreciation and other items not normalized (1) (1) (8) (7) Amortization of excess deferred federal and state income taxes (4) (4) (8) (9) State income tax rate change (a) — (9) (1) (9) Other (3) (1) — (1) Total increase (decrease) 5 (1) 19 17 Total income tax expense (benefit) $ 43 $ 37 $ 126 $ 131 (a) The three and nine months ended September 30, 2022 include a deferred tax benefit of $9 million, due to the corporate net income tax rate reduction. See "Pennsylvania State Tax Reform" below for additional information. (LG&E) Three Months Nine Months 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 21 $ 21 $ 56 $ 57 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 4 10 11 Amortization of excess deferred federal and state income taxes (3) (3) (9) (17) Other (1) (1) (2) (2) Total increase (decrease) — — (1) (8) Total income tax expense (benefit) $ 21 $ 21 $ 55 $ 49 (KU) Three Months Nine Months 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 26 $ 25 $ 63 $ 70 Increase (decrease) due to: State income taxes, net of federal income tax benefit 5 5 12 13 Amortization of excess deferred federal and state income taxes (5) (4) (13) (16) Other (2) (2) (3) (4) Total increase (decrease) (2) (1) (4) (7) Total income tax expense (benefit) $ 24 $ 24 $ 59 $ 63 Other Narragansett Electric Acquisition (PPL) The acquisition of Narragansett Electric on May 25, 2022 was deemed an asset acquisition for federal and state income tax purposes, as a result of PPL and National Grid making a tax election under Internal Revenue Code (IRC) §338(h)(10). Accordingly, the tax bases of substantially all of the assets acquired were increased to fair market value, which equaled net book value, thereby eliminating the related deferred tax assets and liabilities. This election resulted in tax goodwill that will be amortized for tax purposes over 15 years. Pennsylvania State Tax Reform (PPL and PPL Electric) On July 8, 2022, the Governor of Pennsylvania signed into law Pennsylvania House Bill 1342 (H.B. 1342). Among other changes to the state tax code, the bill reduces the corporate net income tax rate from 9.99% to 8.99% beginning January 1, 2023, and further reduces the rate annually by half a percentage point until the rate reaches 4.99% in 2031. Inflation Reduction Act (All Registrants) On August 16, 2022, the Inflation Reduction Act (IRA) was signed into law. Among other things, the IRA enacted a new 15% corporate "book minimum tax," which is based on adjusted GAAP pre-tax income and is only applicable to corporations whose pre-tax income exceeds a certain threshold. PPL does not expect to be subject to the book minimum tax in 2023. The Registrants will continue to assess the impacts of the IRA on their financial statements and will monitor guidance issued by the U.S. Treasury in the future. In addition, the IRA enacted numerous new tax credits, largely associated with renewable energy. IRS Revenue Procedure 2023-15 (PPL and LG&E) On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized for tax purposes. PPL and LG&E are currently reviewing the revenue procedure to determine what impact the guidance may have on their financial statements.

Utility Rate Regulation

Utility Rate Regulation	9 Months Ended
	Sep. 30, 2023
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: Gas supply clause $ — $ 41 $ — $ — $ — $ 13 $ — $ — Rate adjustment mechanisms 210 96 — — — — — — Renewable energy certificates 13 14 — — — — — — Derivative instruments 29 41 — — — — — — Smart meter rider 5 5 5 5 — — — — Storm damage costs 5 — 5 — — — — — Universal service rider 10 3 10 3 — — — — Fuel adjustment clause 8 38 — — 3 9 5 29 Transmission service charge 24 — 24 — — — — — Distribution system improvement charge 8 5 8 5 — — — — Other 3 15 — — 2 1 2 3 Total current regulatory assets $ 315 $ 258 $ 52 $ 13 $ 5 $ 23 $ 7 $ 32 Noncurrent Regulatory Assets: Defined benefit plans $ 795 $ 778 $ 371 $ 353 $ 204 $ 209 $ 137 $ 140 Plant outage costs 40 46 — — 10 12 30 34 Net metering 98 61 — — — — — — Environmental cost recovery 100 102 — — — — — — Taxes recoverable through future rates — 47 — — — — — — Storm costs 97 118 — — 15 7 14 3 Unamortized loss on debt 24 21 4 3 11 11 7 7 Interest rate swaps 3 7 — — 3 7 — — Terminated interest rate swaps 59 63 — — 35 37 24 26 Accumulated cost of removal of utility plant 186 212 186 212 — — — — AROs 290 295 — — 76 76 214 219 Derivatives instruments 5 — — — — — — — Other 90 69 — — 26 14 16 13 Total noncurrent regulatory assets $ 1,787 $ 1,819 $ 561 $ 568 $ 380 $ 373 $ 442 $ 442 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 $ 41 $ 37 $ 41 $ 37 $ — $ — $ — $ — Transmission service charge — 14 — 7 — — — — TCJA customer refund 7 15 7 15 — — — — Act 129 compliance rider 17 14 17 14 — — — — Transmission formula rate 18 12 18 12 — — — — Rate adjustment mechanism 147 96 — — — — — — Energy efficiency 23 23 — — — — — — Gas supply clause 18 — — — 18 — — — Other 9 27 — — 5 7 11 6 Total current regulatory liabilities $ 280 $ 238 $ 83 $ 85 $ 23 $ 7 $ 11 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 991 $ 950 $ — $ — $ 301 $ 287 $ 400 $ 389 Power purchase agreement - OVEC 20 26 — — 14 18 6 8 Net deferred taxes 1,999 2,094 772 775 465 477 528 546 Defined benefit plans 240 187 66 45 21 21 57 56 Terminated interest rate swaps 58 60 — — 29 30 29 30 Energy efficiency 39 32 — — — — — — Other 37 63 — — — — 2 — Total noncurrent regulatory liabilities $ 3,384 $ 3,412 $ 838 $ 820 $ 830 $ 833 $ 1,022 $ 1,029 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 (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 five 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 May 25, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under 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 on track for timely completion, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is now 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 has 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, and which, among other things, sought approval to deploy smart meters throughout the service territory. In 2021, the RIPUC stayed the AMF and GMP proceedings pending further consideration following the issuance of a final Order by the Rhode Island Division of Public Utilities and Carriers on the acquisition of RIE. RIE filed notice of withdrawal of the original Updated AMF Business Case and GMP with the RIPUC, and in November 2022 filed a new AMF Business Case with the RIPUC. The new AMF Business Case filing consists of a detailed proposal for full-scale deployment of AMF across its electric service territory. The proposal will enable significant customer and grid benefits in line with the state’s climate mandates. In its filing, RIE estimated that the proposed program would cost $188 million on a net present value (NPV) basis and provide benefits of $729 million NPV over the 20-year project life, yielding a benefit-cost ratio of 3.9x. RIE believes AMF is a foundational technology that is a necessary first step to transforming Rhode Island’s electric distribution system. 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 is required to file with the RIPUC (i) by December 27, 2023, an updated electric Service Quality Plan for RIPUC review and approval, and (ii) additional tariff provisions regarding recovery and plans that address certain programs related to AMF. 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 issue 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 how it would impact future electric ISR plans. COVID-19 Deferral Filing On April 30, 2021, RIE filed a petition for approval to recognize regulatory assets related to COVID-19 impacts (RIPUC Docket No. 5154). In its petition, RIE sought the RIPUC's authorization to create regulatory assets and consideration of future cost recovery for the following COVID-19 costs: (i) the increased cost of customer accounts receivable that RIE will be unable to collect as a result of the COVID-19 pandemic, and the executive orders and RIPUC orders restricting RIE's collection activities as a result of the pandemic, which will result in increased net charge-offs; (ii) lost revenue from unassessed late payment charges; and (iii) charges to RIE for other fees that RIE has waived pursuant to the RIPUC's orders in RIPUC Docket No. 5022. RIE is evaluating its request to create a regulatory asset for COVID-19-related bad debt expense to consider the impact, if any, of the proposed arrearage forgiveness sought in RIE’s Petition to Forgive Certain Arrearage Balances for Low-Income and Protected Customers in Docket No. 22-08-GE, which RIE filed with the RIPUC to fulfill its obligations under PPL's settlement with the Rhode Island Attorney General. 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. The RIPUC held an Open Meeting on September 13, 2022, and issued its Order on November 18, 2022 regarding the Proactive Main Replacement Program and made the following rulings: (i) commencing with the Gas ISR plan to be filed in this calendar year 2022 (prospectively), new main constructed to replace leak prone pipe will not be considered used and useful, and therefore not eligible for rate base treatment, until the related old main is abandoned; and (ii) approved the proactive main replacement revenue requirement set forth in the FY 2023 Gas ISR plan. Also, the RIPUC directed RIE to submit prefiled testimony on the issue of its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and to address three issues, specifically: (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. RIE filed this testimony with the RIPUC on May 16, 2022, the RIPUC has not taken any action to date on this issue. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan process. A new docket has been opened to address this matter with the goal of implementing changes for the FY 2025 ISR Plan. RIE cannot predict the outcome of these matters. The RIPUC held an evidentiary hearing on October 18, 2023, regarding RIE’s FY 2023 Gas ISR reconciliation, which is part of the distribution adjustment clause rates for effect November 1, 2023. During the hearing, a draft framework with conceptual parameters and principles for future gas ISR plans was introduced, which will be further discussed on November 7, 2023. FY 2024 Gas ISR Plan On December 23, 2022, RIE filed its FY 2024 Gas ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget that was filed with the RIPUC on January 27, 2023 includes $187 million of capital investment spend. The supplemental rate schedules were filed on February 3, 2023. RIE and the Rhode Island Division of Public Utilities and Carrier s reached an agreement on an approximately $171 million capital investment spending plan, and RIE filed a second supplemental budget on March 13, 2023. The RIPUC held a hearing on the plan on March 14, 2023. At an Open Meeting on March 29, 2023, the RIPUC approved the 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. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan review and approval process starting with the FY 2025 ISR Plan. A new docket will be opened to address this matter with the goal of implementing changes for the FY 2025 ISR Plan. RIE cannot predict the outcome of these matters. FY 2024 Electric ISR Plan On December 23, 2022, RIE filed its FY 2024 Electric ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget filed with the RIPUC on January 27, 2023 includes $176 million of capital investment spend, $14 million of vegetation operations and management (O&M) spend and $3 million of Other O&M spend. The supplemental rate schedules were filed on February 3, 2023. RIE filed second supplemental budget schedules on March 21, 2023, which includes $166 million of capital investment spend, $14 million of vegetation management O&M spend and $1 million of Other O&M spend. The RIPUC held hearings in March 2023, and on March 29, 2023, approved the plan 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 March 30, 2023 compliance filing for rates effective April 1, 2023. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan review and approval process. A new docket has been opened to address this matter with the goal of implementing changes for the FY 2025 ISR Plan. RIE cannot predict the outcome of these matters. Kentucky Activities (PPL, LG&E and KU) CPCN and SB 4 Application On December 15, 2022, LG&E and KU filed an application with the KPSC for a CPCN for the construction of two 621 MW net summer rating NGCC combustion turbine facilities, one at LG&E's Mill Creek Generating Station in Jefferson County, Kentucky and the other at KU's E.W. Brown Generating Station in Mercer County, Kentucky, including on-site natural gas and electric transmission construction associated with those facilities and site compatibility certificates. LG&E and KU also applied for a CPCN to construct a 120 MWac solar photovoltaic electric generating facility in Mercer County, Kentucky, and for a CPCN to acquire a 120 MWac solar facility to be built by a third-party solar developer in Marion County, Kentucky. LG&E and KU further applied for a CPCN to construct a 125 MW, 4-hour battery energy storage system facility at KU's E.W. Brown Generating Station and for approval of their proposed 2024-2030 DSM programs. The plan includes adding 14 new, adjusted or expanded energy efficiency programs, which would reduce LG&E's and KU's overall need by approximately 100 MW each. Finally, LG&E and KU requested a declaratory order to confirm that their entry into non-firm energy-only power-purchase agreements for the output of four solar photovoltaic facilities with a combined capacity of 637 MW does not require KPSC approval and that LG&E and KU may recover the costs of the solar PPAs through their fuel adjustment clause mechanisms as previously approved for a prior solar PPA. LG&E and KU plan to accrue AFUDC on the constructed NGCC facilities, the solar facility in Mercer County, Kentucky and the battery energy storage system facility and have requested regulatory asset treatment to recover the financing costs of these projects. The new NGCC facilities would be jointly owned by LG&E (31%) and KU (69%) and the solar units would be jointly owned by LG&E (37%) and KU (63%), the battery storage unit would be owned by LG&E, and the proposed PPA transactions and DSM programs would be entered into or conducted jointly by LG&E and KU, consistent with LG&E and KU's shared dispatch, cost allocation, tariff or other frameworks. The filing also notes planned retirement dates for certain existing coal-fired generation units, including Mill Creek 1 (300 MW) in 2024 and E.W. Brown 3 (412 MW) in 2028 , and updates and advances the planned retirement dates for Mill Creek 2 (297 MW) to 2027 and Ghent 2 (486 MW) to 2028 . LG&E and KU anticipate the recovery of associated retirement costs, including the remaining net book value, for these coal-fired generating units through the RAR or other rate mechanisms. The KPSC accepted the CPCN filing as of January 6, 2023. On March 24, 2023, Kentucky Senate Bill 4 (SB 4) went into effect, which requires KPSC approval of fossil fuel-fired electric generating unit retirements in the state. On May 10, 2023, LG&E and KU filed an application with the KPSC seeking approval of the retirement of seven fossil fuel-fired generating units as required by the recently enacted SB 4. On May 16, 2023, the KPSC entered an Order consolidating the SB 4 filing proceeding into the CPCN case. On August 29, 2023, a hearing with the KPSC and all parties concluded, and all post-hearing briefs have been filed. The KPSC has indicated its intention to issue an order on all issues by November 6, 2023. PPL, LG&E and KU cannot predict the outcome of these matters. Kentucky March 2023 Storm On March 3, 2023, 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 costs incurred through September 30, 2023 of $75 million ($33 million at LG&E and $42 million at KU). On March 17, 2023, 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 windstorm. On April 5, 2023, the KPSC issued an order approving the request for accounting purposes, noting that approval for recovery would be determined in LG&E’s and KU’s next base rate cases. As of September 30, 2023, LG&E and KU recorded regulatory assets related to the storm of $8 million and $11 million. 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 25, 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 has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric has submitted its responses to the information request and is cooperating fully with the investigation. PPL Electric cannot predict the outcome of this matter. 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 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 requested and received an extension of time to process refunds until December 2023. LG&E and KU filed a request for rehearing of the May 18, 2023 order, which was denied by operation of law on July 17, 2023. LG&E and KU filed petition for review of FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals on July 28, 2023. The FERC has indicated in its filings before the D.C. Circuit Court of Appeals that it intends to issue a substantive order on rehearing before November 13, 2023. The D.C. Circuit Court of Appeals will likely set the procedural schedule soon after FERC files the certified index to the record in mid-November 2023. LG&E and KU recorded regulatory liabilities of $3 million and $9 million related to potential refunds resulting from the FERC’s May 18, 2023 order. 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 provided primarily through base rates with increases associated with the FERC's May 18, 2023 order expected to be primarily subject to base rate recovery in 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'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 New England Transmission Owners 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. Those determinations in other jurisdictions have recently been vacated and remanded back to the FERC for further proceedings by the D.C. Circuit Court of Appeals. 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 and nine months ended September 30, 2023, PPL Electric purchased $391 million and $1 billion of accounts receivable from alternative suppliers. During the three and nine months ended September 30, 2022, PPL Electric purchased $352 million and $974 million of receivables. (PPL)

Financing Activities

Financing Activities	9 Months Ended
	Sep. 30, 2023
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 except for borrowings under PPL Electric's term loan agreement due March 2024 and borrowings under LG&E's and KU's term loan agreements due July 2024, which are reflected in "Long-term debt" at December 31, 2022. The following credit facilities were in place at: September 30, 2023 December 31, 2022 Expiration Capacity Borrowed Letters of Unused Borrowed Letters of PPL PPL Capital Funding (a) Syndicated Credit Facility (b) Dec. 2027 $ 1,250 $ — $ 75 $ 1,175 $ — $ 561 Bilateral Credit Facility Mar. 2024 100 — — 100 — — Bilateral Credit Facility Mar. 2024 100 — 13 87 — 58 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 88 $ 1,362 $ — $ 619 PPL Electric Syndicated Credit Facility Dec. 2027 $ 650 $ — $ 188 $ 462 $ — $ 146 Term Loan Credit Facility Mar. 2024 — — — — 250 — Total PPL Electric Credit Facilities $ 650 $ — $ 188 $ 462 $ 250 $ 146 LG&E Syndicated Credit Facility Dec. 2027 $ 500 $ — $ — $ 500 $ — $ 180 Term Loan Credit Facility Jul. 2024 — — — — 300 — Total LG&E Credit Facilities $ 500 $ — $ — $ 500 $ 300 $ 180 KU Syndicated Credit Facility Dec. 2027 $ 400 $ — $ 25 $ 375 $ — $ 101 Term Loan Credit Facility Jul. 2024 — — — — 300 — Total KU Credit Facilities $ 400 $ — $ 25 $ 375 $ 300 $ 101 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) Includes a $250 million borrowing sublimit for RIE and a $1 billion sublimit for PPL Capital Funding. At September 30, 2023, PPL Capital Funding had no commercial paper outstanding and RIE had $75 million of 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) In March 2023, RIE was added as an authorized borrower under the PPL Capital Funding syndicated credit facility. At September 30, 2023, RIE’s borrowing limit under the facility was set at $250 million and PPL Capital Funding's borrowing limit was set at $1 billion. At September 30, 2023, PPL Capital Funding had no commercial paper outstanding and RIE had $75 million of commercial paper outstanding. (PPL and PPL Electric) In March 2023, PPL Electric repaid its $250 million term loan expiring in March 2024 and terminated the facility. (PPL and LG&E) In March 2023, LG&E repaid its $300 million term loan expiring in July 2024 and terminated the facility. (PPL and KU) In March 2023, KU repaid its $300 million term loan expiring in July 2024 and terminated the facility. (All Registrants) 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, 2023 December 31, 2022 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) (b) $ 1,350 $ — $ 1,350 4.84% $ 561 RIE (b) 5.49% 400 75 325 — PPL Electric 5.47% 650 187 463 4.74% 145 LG&E 500 — 500 4.94% 180 KU 5.45% 400 25 375 4.90% 101 Total $ 3,300 $ 287 $ 3,013 $ 987 (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 and under which they are both borrowers. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. The PPL Capital Funding syndicated credit facility includes a borrowing sublimit for RIE, which is currently set at $250 million with the remaining $1 billion allocated to PPL Capital Funding. RIE's obligations under the facility are not guaranteed by PPL. The sublimits of each borrower may be decreased or increased at the borrowers’ option up to a prescribed amount such that all borrowings under the syndicated credit facility cannot exceed the size of the credit facility of $1.25 billion. (c) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL) In June 2023, RIE established a commercial paper program with a capacity of $400 million. This program is supported by PPL Capital Funding's syndicated credit facility, under which RIE is a co-borrower. (PPL Electric, LG&E, and KU) See Note 11 for discussion of intercompany borrowings. Long-term Debt (PPL) In February 2023, PPL Capital Funding issued $1.0 billion of 2.875% Exchangeable Senior Notes due 2028 (the Notes). PPL Capital Funding received proceeds of $980 million, net of underwriting fees, which were used to repay short-term debt and for general corporate purposes. The Notes are senior unsecured notes, fully guaranteed by PPL. The Notes are scheduled to mature on March 15, 2028, unless earlier exchanged, redeemed or repurchased. The Notes are exchangeable at an initial exchange rate of 29.3432 shares of PPL's common stock per $1,000 principal amount (equivalent to an initial exchange price of approximately $34.08 per share of common stock). The initial exchange rate is subject to adjustment, as provided in the indenture for anti-dilutive events and fundamental change and redemption provisions. Upon exchange of the Notes, PPL Capital Funding will redeem the aggregate principal amount of the Notes in cash. PPL Capital Funding will pay cash, deliver shares of common stock or a combination of cash and shares of common stock, at PPL Capital Funding's election, in respect of the remainder, if any, of its exchange obligation in excess of the aggregate principal amount of the Notes being exchanged. Prior to December 15, 2027, the Notes will be exchangeable at the option of the noteholders only upon the satisfaction of specified conditions and during certain periods described in the indenture pursuant to which the Notes were issued. On or after December 15, 2027 until the maturity date, the Notes will be exchangeable at the option of the noteholders at any time regardless of these conditions or periods. PPL Capital Funding may redeem all or any portion of the Notes, at its option, on or after March 20, 2026, if the last reported sale price of the common stock has been at least 130% of the exchange price then in effect for at least 20 trading days (whether or not consecutive), during any 30 consecutive trading day period, at a redemption price equal to 100% of the principal amount of the Notes to be redeemed, plus any accrued and unpaid interest. No sinking fund is provided for the Notes. Subject to certain conditions, holders of the Notes will have the right to require PPL Capital Funding to repurchase all or a portion of their Notes upon the occurrence of a fundamental change, as defined in the indenture pursuant to which the Notes were issued at a repurchase price of 100% of their principal amount plus any accrued and unpaid interest. In connection with certain corporate events or if PPL Capital Funding calls any Notes for redemption, PPL Capital Funding will, under certain circumstances, increase the exchange rate for noteholders who elect to exchange their Notes in connection with any such corporate event or exchange their Notes called for redemption. (PPL and PPL Electric) In March 2023, PPL Electric issued $600 million of 5.00% First Mortgage Bonds due 2033 and $750 million of 5.25% First Mortgage Bonds due 2053. PPL Electric received proceeds of $1.32 billion, net of discounts and underwriting fees, which were used to repay debt, including PPL Electric's $250 million term loan, and for other general corporate purposes. In March 2023, PPL Electric redeemed all of the outstanding $650 million aggregate principal amount of its First Mortgage Bonds, Floating Rate Series due 2024. In March 2023, PPL Electric redeemed all of the outstanding $250 million aggregate principal amount of its First Mortgage Bonds, Floating Rate Series due 2023. (PPL and LG&E) In March 2023, LG&E issued $400 million of 5.45% First Mortgage Bonds due 2033. LG&E received proceeds of $396 million, net of discounts and underwriting fees, which were used to repay LG&E's $300 million term loan and for other general corporate purposes. (PPL and KU) In March 2023, KU issued $400 million of 5.45% First Mortgage Bonds due 2033. KU received proceeds of $396 million, net of discounts and underwriting fees, which were used to repay KU's $300 million term loan and for general corporate purposes. (PPL) Equity Securities In June 2023, RIE redeemed all 49,089 shares of its outstanding preferred stock at a redemption price equal to the par value of $50 per share, plus a premium of $5 per share, plus a prorated dividend of $0.1875 per share. The total payment was $3 million. Dividends

Defined Benefits

Defined Benefits	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 PPL Service cost $ 8 $ 11 $ 25 $ 36 Interest cost 47 33 141 95 Expected return on plan assets (77) (62) (232) (189) Amortization of: Prior service cost 2 2 5 6 Actuarial loss 1 11 2 40 Net periodic defined benefit costs (credits) before settlements (19) (5) (59) (12) Settlements (a) — 7 — 19 Net periodic defined benefit costs (credits) $ (19) $ 2 $ (59) $ 7 (a) Due to the amount of lump sum payment distributions from the LKE qualified pension plan, settlement charges were incurred during the three and nine months ended, September 30, 2022. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized over 15 years. Other Postretirement Benefits Three Months Nine Months 2023 2022 2023 2022 PPL Service cost $ 1 $ 1 $ 4 $ 4 Interest cost 8 3 23 11 Expected return on plan assets (7) (5) (22) (17) Amortization of: Prior service cost — — 1 1 Actuarial loss (1) — (4) (2) Net periodic defined benefit costs (credits) $ 1 $ (1) $ 2 $ (3) (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.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	10. Commitments and Contingencies Long-term Contracts for Renewable Energy (PPL) In July 2022, Rhode Island passed an amendment to the Affordable Clean Energy Security Act (ACES) that required RIE to issue a request for proposals (RFP) for at least 600 MW but no greater than 1,000 MW of newly developed offshore wind capacity no later than October 15, 2022. The RFP was issued on October 14, 2022, following a public comment period, and subsequently revised on November 7, 2022. On March 17, 2023, RIE announced that it will evaluate a joint proposal from Orsted and Eversource to develop 884 MW of offshore wind, which was the sole response to RIE’s RFP. On July 18, 2023, RIE announced it would not be proceeding with conditional selection of the bid because it did not meet the terms of the ACES statute. RIE filed its supporting documentation with the RIPUC on September 27, 2023. The RIPUC is required to issue its Order within 90 days of that filing. Legal Matters (All Registrants) PPL and its subsidiaries are involved in legal proceedings, claims and litigation in the ordinary course of business. PPL and its subsidiaries cannot predict the outcome of such matters, or whether such matters may result in material liabilities, unless otherwise noted. Talen Litigation Background (PPL) In September 2013, one of PPL's former subsidiaries, PPL Montana entered into an agreement to sell its hydroelectric generating facilities. In June 2014, PPL and PPL Energy Supply, the parent company of PPL Montana, entered into various definitive agreements with affiliates of Riverstone to spin off PPL Energy Supply and ultimately combine it with Riverstone's competitive power generation businesses to form a stand-alone company named Talen Energy. In November 2014, after executing the spinoff agreements but prior to the closing of the spinoff transaction, PPL Montana closed the sale of its hydroelectric generating facilities. Subsequently, on June 1, 2015, the spinoff of PPL Energy Supply was completed. Following the spinoff transaction, PPL had no continuing ownership interest in or control of PPL Energy Supply. In connection with the spinoff transaction, PPL Montana became Talen Montana, LLC (Talen Montana), a subsidiary of Talen Energy and Talen Energy Marketing, LLC also became a subsidiary of Talen Energy. Talen Energy has owned and operated both Talen Montana and Talen Energy Marketing, LLC since the spinoff. At the time of the spinoff, affiliates of Riverstone acquired a 35% ownership interest in Talen Energy. Riverstone subsequently acquired the remaining interests in Talen Energy in a take private transaction in December 2016. In October 2018, Talen Montana Retirement Plan and Talen Energy Marketing, LLC filed a putative class action complaint on behalf of current and contingent creditors of Talen Montana (the Montana Action) who allegedly suffered harm or allegedly will suffer reasonably foreseeable harm as a result of, among other things, the November 2014 allegedly fraudulent transfer of proceeds from the sale of then-PPL Montana's hydroelectric generating facilities. In November 2018, PPL, certain PPL affiliates, and certain current and former officers and directors (PPL plaintiffs) filed a complaint in the Court of Chancery of the State of Delaware seeking various forms of relief against Riverstone, Talen Energy and certain of their affiliates (the Delaware Action), in response to the Montana Action and as part of the defense strategy. Talen Energy Supply, LLC et al. and Talen Montana LLC v. PPL Corp., PPL Capital Funding, Inc., PPL Electric Utilities Corp., and PPL Energy Funding (PPL and PPL Electric) On May 9, 2022, Talen Energy Supply, LLC and 71 affiliates, including Talen Montana, LLC, filed petitions for protection under Chapter 11 of the Bankruptcy Code in the U.S. Bankruptcy Court for the Southern District of Texas (Texas Bankruptcy Court). On May 10, 2022, Talen Montana, LLC, as debtor-in-possession, filed a complaint initiating an adversary proceeding (Adversary Proceeding) in the Texas Bankruptcy Court against PPL Corporation, PPL Capital Funding, Inc., PPL Electric Utilities Corporation, and PPL Energy Funding Corporation. Similar to the litigation in Montana, the Adversary Proceeding seeks the recovery of an allegedly fraudulent transfer relating to PPL Montana’s November 2014 sale of hydroelectric assets to Northwestern and subsequent distribution of certain proceeds of that sale of approximately $900 million, reiterating claims that the parties had already been litigating in Montana and Delaware. Both the Montana Action and the Delaware Action have now been transferred to and consolidated in the Texas Bankruptcy Court. PPL has filed its Answer and asserted a Counterclaim against the Talen and Riverstone entities, similar to the claims previously asserted in the Delaware Action, and has filed a motion for partial summary judgment that was heard on October 31, 2022. Mediation occurred on February 22, 2023 before Judge David R. Jones of the Texas Bankruptcy Court. The parties did not settle the case, and mediation was discontinued. On June 14, 2023, the Texas Bankruptcy Court entered an Order denying the defendants’ motion for partial summary judgment. A hearing on Riverstone’s motion for summary judgment occurred on August 24, 2023. The court ordered supplemental briefing from each party following the hearing. Defendants filed a second partial motion for summary judgment based on a safe harbor provision in the bankruptcy code on September 29, 2023, and that motion is set for hearing on December 19, 2023. Trial is set to begin on February 7, 2024, in Houston. PPL believes that the 2014 distribution of proceeds was made in compliance with all applicable laws and that PPL Montana was solvent at all relevant times. Additionally, the agreements entered into in connection with the spinoff, which PPL and affiliates of Talen Energy and Riverstone negotiated and executed prior to the 2014 distribution, directly address the treatment of the proceeds from the sale of PPL Montana's hydroelectric generating facilities; in those agreements, Talen Energy and Riverstone definitively agreed that PPL was entitled to retain the proceeds. PPL believes that it has meritorious defenses to the claims made in the Adversary Proceeding and intends to vigorously defend against this action. At this time, PPL cannot predict the outcome of the Adversary Proceeding or estimate the range of possible losses, if any, that PPL might incur as a result of the claims, although they could be material. Narragansett Electric Litigation (PPL) Energy Efficiency Programs Investigation Narragansett Electric, while under the ownership of National Grid, performed an internal investigation into conduct associated with its energy efficiency programs. On June 27, 2022, the RIPUC opened a new docket (RIPUC Docket No. 22-05-EE) to investigate RIE’s actions and the actions of its National Grid employees during the time RIE was a National Grid USA affiliate being provided services by National Grid USA Service Company, Inc. relating to the manipulation of the reporting of invoices affecting the calculation of past energy efficiency shareholder incentives and the resulting impact on customers. The Rhode Island Attorney General and National Grid USA intervened in the docket. On January 19, 2023, the Rhode Island Division of Public Utilities and Carriers (the Division) filed a motion to dismiss RIPUC Docket No. 22-05-EE without prejudice. As grounds for its motion, the Division stated that sufficient evidence exists in the docket to warrant an independent summary investigation by the Division, to include an audit of RIE, pursuant to Rhode Island General Laws Section 39-4-13. If the Division finds sufficient grounds, the Division may proceed to a formal hearing regarding the matters under investigation pursuant to Rhode Island General Laws Sections 39-4-14 and 39-4-15. Upon the conclusion of its investigation, the Division will provide the RIPUC with a report outlining the Division’s findings and final decision. On January 30, 2023, the Rhode Island Attorney General filed an objection to the Division’s motion to dismiss; RIE and National Grid each filed responses with the RIPUC requesting that any additional action taken by the RIPUC or the Division be considered after National Grid completes its internal investigation report, which National Grid filed with the RIPUC on March 10, 2023. On February 24, 2023, the Division initiated the independent summary investigation that it had referenced in its motion to dismiss RIPUC Docket No. 22-05-EE. The RIPUC held a hearing on March 28, 2023 to hear oral arguments regarding the Division’s motion to dismiss and subsequently denied the motion. RIPUC Docket No. 22-05-EE remains open and, in parallel, the Division’s summary investigation remains ongoing. At this time, it is not possible to predict the final outcome or determine the total amount of any additional liabilities that may be incurred by RIE in connection with RIPUC Docket No. 22-05-EE or the Division’s summary investigation. RIE does not expect this matter will have a material adverse effect on its results of operations, financial position or cash flows. E.W. Brown Environmental Assessment ( PPL and KU) KU is undertaking extensive remedial measures at the E.W. Brown plant including closure of the former ash pond, implementation of a groundwater remedial action plan and performance of a corrective action plan including aquatic study of adjacent surface waters and risk assessment. The aquatic study and risk assessment are being undertaken pursuant to a 2017 agreed Order with the Kentucky Energy and Environment Cabinet (KEEC). KU conducted sampling of Herrington Lake in 2017 and 2018. In June 2019, KU submitted to the KEEC the required aquatic study and risk assessment, conducted by an independent third-party consultant, finding that discharges from the E.W. Brown plant have not had any significant impact on Herrington Lake and that the water in the lake is safe for recreational use and meets safe drinking water standards. On May 31, 2021, the KEEC approved the report and released a response to public comments. On August 6, 2021, KU submitted a Supplemental Remedial Alternatives Analysis report to the KEEC that outlines proposed additional fish, water, and sediment testing. On February 18, 2022, the KEEC provided approval to KU to proceed with the proposed sampling, which commenced in the spring of 2022. On November 17, 2022, KU submitted a Supplemental Performance Monitoring Report to the KEEC finding that there are no significant unaddressed risks to human health or the environment at the plant. KU revised the Supplemental Performance Monitoring Report on June 8, 2023 in response to KEEC comments from April 24, 2023. On September 1, 2023, the KEEC requested KU to propose additional monitoring or remedial measures. Discussions between KU and the KEEC are ongoing. Water/Waste (PPL, LG&E and KU) ELGs In 2015, the EPA finalized ELGs for wastewater discharge permits for new and existing steam electricity generating facilities. These guidelines require deployment of additional control technologies providing physical, chemical and biological treatment and mandate operational changes including "zero discharge" requirements for certain wastewaters. The implementation date for individual generating stations was to be determined by the states on a case-by-case basis according to criteria provided by the EPA. Legal challenges to the final rule were consolidated before the U.S. Court of Appeals for the Fifth Circuit. In April 2017, the EPA announced that it would grant petitions for reconsideration of the rule. In September 2017, the EPA issued a rule to postpone the compliance date for certain requirements. In October 2020, the EPA published final revisions to its best available technology standards for certain wastewaters and potential extensions to compliance dates (the Reconsideration Rule). In March 2023, the EPA released a proposed rule that would modify the 2020 ELG revisions. The proposed rule would increase the stringency of previous control technology and zero discharge requirements, revise certain exemptions for generating units planned for retirement, and require case-by-case limitations for legacy wastewaters based on the best professional judgment of the state regulators. Compliance with the Reconsideration Rule is required during the pendency of the rulemaking process. The proposed rule is currently under evaluation, but could potentially result in significant operational changes and additional controls for LG&E and KU plants. The ELGs are expected to be implemented by the states or applicable permitting authorities in the course of their normal permitting activities. LG&E and KU are currently implementing responsive compliance strategies and schedules. Certain aspects of these compliance plans and estimates relate to developments in state water quality standards, which are separate from the ELG rule or its implementation. Certain costs are included in the Registrants' capital plans and expected to be recovered from customers through rate recovery mechanisms, but additional costs and recovery will depend on further regulatory developments at the state level. CCRs In 2015, the EPA issued a final rule governing management of CCRs which include fly ash, bottom ash and sulfur dioxide scrubber wastes. The CCR Rule imposes extensive new requirements for certain CCR impoundments and landfills, including public notifications, location restrictions, design and operating standards, groundwater monitoring and corrective action requirements, and closure and post-closure care requirements, and specifies restrictions relating to the beneficial use of CCRs. In July 2018, the EPA issued a final rule extending the deadline for closure of certain impoundments and adopting other substantive changes. In August 2018, the D.C. Circuit Court of Appeals vacated and remanded portions of the CCR Rule. In December 2019, the EPA addressed certain deficiencies identified by the court and proposed amendments to change the closure deadline. In August 2020, the EPA published a final rule extending the deadline to initiate closure to April 11, 2021, while providing for certain extensions. The EPA is conducting ongoing rulemaking actions regarding various other amendments to the rule including potentially making the rule applicable to certain inactive impoundments and landfills not currently subject to the rule. Certain ongoing legal challenges to various provisions of the CCR Rule have been held in abeyance pending review by the EPA pursuant to the President's executive order. PPL, LG&E, and KU are monitoring the EPA’s ongoing efforts to refine and implement the regulatory program under the CCR Rule. In January 2022, the EPA issued several proposed regulatory determinations, facility notifications, and public announcements which indicate increased scrutiny by the EPA to determine the adequacy of measures taken by facility owners and operators to achieve closure of CCR surface impoundments and landfills. In particular, the agency indicated that it will focus on certain practices which it views as posing a threat of continuing groundwater contamination. On May 18, 2023, the EPA published a proposed rule establishing regulatory requirements for inactive surface impoundments at inactive electricity generation facilities. The EPA proposes to establish groundwater monitoring, corrective action, closure, and post-closure care requirements for all CCR management units at regulated CCR facilities regardless of how or when the CCR was placed. The proposed rule, if finalized, would require PPL to complete applicability determinations, implement site security measures, initiate weekly inspections and monthly monitoring of the impoundment, create a website, and complete hazard assessments and reports for its legacy impoundments within three months of the proposed rule’s effective date. Additionally, the proposed rule could potentially subject management units that have previously completed remedial action and closure and certain beneficial use projects to additional federal regulatory requirements. Future guidance, regulatory determinations, rulemakings, and other developments could potentially require revisions to current LG&E and KU compliance plans including additional monitoring and remediation at surface impoundments and landfills, the cost of which could be substantial. PPL, LG&E and KU are unable to predict the outcome of the ongoing litigation, rulemaking, and regulatory determinations or potential impacts on current LG&E and KU compliance plans. PPL, LG&E and KU are currently finalizing closure plans and schedules in accordance with existing regulations. In January 2017, Kentucky issued a new state rule relating to CCR management, effective May 2017, aimed at reflecting the requirements of the federal CCR rule. As a result of a subsequent legal challenge, in January 2018, the Franklin County, Kentucky Circuit Court issued an opinion invalidating certain procedural elements of the rule. LG&E and KU presently operate their facilities under continuing permits authorized under the former program and do not currently anticipate material impacts as a result of the judicial ruling. Associated costs are expected to be subject to rate recovery. LG&E and KU received KPSC approval for a compliance plan providing for the closure of impoundments at the Mill Creek, Trimble County, E.W. Brown, and Ghent stations, and construction of process water management facilities at those plants. In addition to the foregoing measures required for compliance with the federal CCR rule, KU also received KPSC approval for its plans to close impoundments at the retired Green River, Pineville and Tyrone plants to comply with applicable state law. LG&E and KU have completed planned closure measures at most of the subject impoundments and have commenced post closure groundwater monitoring as required at those facilities. LG&E and KU generally expect to complete all impoundment closures within five years of commencement, although a longer period may be required to complete closure of some facilities. Associated costs are expected to be subject to rate recovery. In connection with the final CCR rule, LG&E and KU recorded adjustments to existing AROs beginning in 2015 and continue to record adjustments as required. See Note 15 for additional information. Further changes to AROs, current capital plans or operating costs may be required as estimates are refined based on closure developments, groundwater monitoring results, and regulatory or legal proceedings. Costs relating to this rule are expected to be subject to rate recovery. Superfund and Other Remediation (All Registrants) The Registrants are potentially responsible for investigating and remediating contamination under the federal Superfund program and similar state programs. Actions are under way at certain sites including former coal gas manufacturing plants in Pennsylvania, Rhode Island and Kentucky previously owned or operated by, or currently owned by predecessors or affiliates of, PPL subsidiaries. Depending on the outcome of investigations at identified sites where investigations have not begun or been completed, or developments at sites for which information is incomplete, additional costs of remediation could be incurred. PPL, PPL Electric, LG&E and KU lack sufficient information about such additional sites to estimate any potential liability or range of reasonably possible losses, if any, related to these sites. Such costs, however, are not currently expected to be significant. The EPA is evaluating the risks associated with polycyclic aromatic hydrocarbons and naphthalene, chemical by-products of coal gas manufacturing. As a result, individual states may establish stricter standards for water quality and soil cleanup, that could require several PPL subsidiaries to take more extensive assessment and remedial actions at former coal gas manufacturing plants. The Registrants cannot reasonably estimate a range of possible losses, if any, related to these matters. (PPL and PPL Electric) PPL Electric is a potentially responsible party for a share of clean-up costs at certain sites including the Columbia Gas Plant site and the Brodhead site. Cleanup actions have been or are being undertaken at these sites as requested by governmental agencies, the costs of which have not been and are not expected to be significant to PPL Electric. As of September 30, 2023 and December 31, 2022, PPL Electric had a recorded liability of $11 million, representing its best estimate of the probable loss incurred to remediate the sites identified above. (PPL) RIE is a potentially responsible party for a share of clean-up costs at certain sites including former manufactured gas plant (MGP) facilities formerly owned by the Blackstone Valley Gas and Electric Company and the Rhode Island gas distribution assets of the New England Gas division of Southern Union Company and electric operations at certain RIE facilities. RIE is currently investigating and remediating, as necessary, those MGP sites and certain other properties under agreements with governmental agencies, the costs of which have not been and are not expected to be significant to PPL. As of September 30, 2023 and December 31, 2022, PPL had a recorded liability of $100 million, representing its best estimate of the remaining costs of RIE's environmental remediation activities. These undiscounted costs are expected to be incurred over approximately 30 years and generally to be subject to rate recovery. However, remediation costs for each site may be materially higher than estimated, depending on changing technologies and regulatory standards, selected end uses for each site, and actual environmental conditions encountered. RIE has recovered amounts from certain insurers and potentially responsible parties, and, where appropriate, may seek additional recovery from other insurers and from other potentially responsible parties, but it is uncertain whether, and to what extent, such efforts will be successful. The RIPUC has approved two settlement agreements that provide for rate recovery of qualified remediation costs of certain contaminated sites located in Rhode Island and Massachusetts. Rate-recoverable contributions for electric operations of approximately $3 million are added annually to RIE's Environmental Response Fund, established with RIPUC approval in March 2000 to address such costs, along with interest and any recoveries from insurance carriers and other third parties. In addition, RIE recovers approximately $1 million annually for gas operations under a distribution adjustment charge in which the qualified remediation costs are amortized over 10 years. See Note 6 for additional information on RIE's recorded environmental regulatory assets and liabilities. Regulatory Issues ( All Registrants) See Note 6 for information on regulatory matters related to utility rate regulation. Electricity - Reliability Standards The NERC is responsible for establishing and enforcing mandatory reliability standards (Reliability Standards) regarding the bulk electric system in North America. The FERC oversees this process and independently enforces the Reliability Standards. The Reliability Standards have the force and effect of law and apply to certain users of the bulk electric system, including electric utility companies, generators and marketers. Under the Federal Power Act, the FERC may assess civil penalties for certain violations. PPL Electric, LG&E, KU and RIE monitor their compliance with the Reliability Standards and self-report or self-log potential violations of applicable reliability requirements whenever identified, and submit accompanying mitigation plans, as required. The resolution of a small number of potential violations is pending. Penalties incurred to date have not been significant. Any Regional Reliability Entity determination concerning the resolution of violations of the Reliability Standards remains subject to the approval of the NERC and the FERC. In the course of implementing their programs to ensure compliance with the Reliability Standards by those PPL affiliates subject to the standards, certain other instances of potential non-compliance may be identified from time to time. The Registrants cannot predict the outcome of these matters, and an estimate or range of possible losses cannot be determined. Gas - Security Directives (PPL and LG&E) In May and July of 2021, the Department of Homeland Security’s (DHS) Transportation Security Administration (TSA) released two security directives applicable to certain notified owners and operators of natural gas pipeline facilities (including local distribution companies) that the TSA has determined to be critical. The TSA has determined that LG&E is within the scope of the directive, while RIE has not been notified of this distinction. The first security directive required notified owners/operators to implement cybersecurity incident reporting to the DHS, designate a cybersecurity coordinator, and perform a gap assessment of current entity cybersecurity practices against certain voluntary TSA security guidelines and report relevant results and proposed mitigation to applicable DHS agencies. The second security directive, revised in July of 2023, requires refinement of the cybersecurity implementation plan and the cybersecurity assessment plan. LG&E does not believe the security directives have had or will have a significant impact on LG&E’s operations or financial condition. Other Guarantees and Other Assurances (All Registrants) In the normal course of business, the Registrants enter into agreements that provide financial performance assurance to third parties on behalf of certain subsidiaries. Examples of such agreements include: guarantees, stand-by letters of credit issued by financial institutions and surety bonds issued by insurance companies. These agreements are entered into primarily to support or enhance the creditworthiness attributed to a subsidiary on a stand-alone basis or to facilitate the commercial activities in which these subsidiaries engage. (PPL) PPL fully and unconditionally guarantees all of the debt securities and loan obligations of PPL Capital Funding. (All Registrants) The table below details guarantees provided as of September 30, 2023. "Exposure" represents the estimated maximum potential amount of future payments that could be required to be made under the guarantee. The Registrants believe the probability of expected payment/performance under each of these guarantees is remote, except for the guarantees and indemnifications related to the sale of Safari Holdings, which PPL believes are reasonably possible but not probable of occurring. For reporting purposes, on a consolidated basis, the guarantees of PPL include the guarantees of its subsidiary Registrants. Exposure at September 30, 2023 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 $ 129 (b) 2028 PPL guarantee of Safari payment obligations under certain PPAs related to the sale of Safari Holdings 33 (c) Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings 140 (d) 2028 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (e) (a) PPL WPD Limited entered into a Tax Deed dated June 9, 2021, in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million. (b) PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million. (c) PPL guaranteed the payment obligations of Safari under certain PPAs executed by Safari. Aspen Power is expected to replace these guarantees and retain liability for any payments made by PPL or claims against PPL under any guarantee that is not replaced. (d) Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. 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 and PPAs that will be replaced by Aspen Power. (e) Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement, and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $88 million at September 30, 2023, consisting of LG&E's share of $61 million and KU's share of $27 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 14 in PPL's, LG&E's and KU's 2022 Form 10-K for additional information on the OVEC power purchase contract. The Registrants provide other miscellaneous guarantees through contracts entered into in the normal course of business. These guarantees are primarily in the form of indemnification or warranties related to services or equipment and vary in duration. The amounts of these guarantees often are not explicitly stated, and the overall maximum amount of the obligation under such guarantees cannot be reasonably estimated. Historically, no significant payments have been made with respect to these types of guarantees and the probability of payment/performance under these guarantees is generally remote. PPL, on behalf of itself and certain of its subsidiaries, maintains insurance that covers liability assumed under contract for bodily injury and property damage. The coverage provides maximum aggregate coverage of $225 million. This insurance may be applicable to obligations under certain of these contractual arrangements. Risks and Uncertainties Labor Union Agreement (PPL and LG&E) three

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 PPL Electric from PPL Services $ 52 $ 51 $ 166 $ 172 LG&E from LKS 25 34 85 114 LG&E from PPL Services 10 — 30 — KU from LKS 35 39 110 125 KU from PPL Services 11 — 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 $500 million revolving line of credit with a PPL Electric subsidiary. At September 30, 2023 and December 31, 2022, CEP Reserves had 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, 2023, LG&E's money pool unused capacity was $744 million. At September 30, 2023, LG&E had borrowings outstanding from KU and/or LKE of $ 6 million no 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, 2023, KU's money pool unused capacity was $604 million. At September 30, 2023, KU had borrowings outstanding from LG&E and/or LKE of $ 21 million no VEBA Funds Receivable (PPL Electric) In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. There was no intercompany receivable balance associated with these funds as of September 30, 2023, which would be reflected in "Accounts receivable from affiliates" on the PPL Electric Balance Sheets. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022.
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 2023 2022 2023 2022 PPL Electric from PPL Services $ 52 $ 51 $ 166 $ 172 LG&E from LKS 25 34 85 114 LG&E from PPL Services 10 — 30 — KU from LKS 35 39 110 125 KU from PPL Services 11 — 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 $500 million revolving line of credit with a PPL Electric subsidiary. At September 30, 2023 and December 31, 2022, CEP Reserves had 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, 2023, LG&E's money pool unused capacity was $744 million. At September 30, 2023, LG&E had borrowings outstanding from KU and/or LKE of $ 6 million no 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, 2023, KU's money pool unused capacity was $604 million. At September 30, 2023, KU had borrowings outstanding from LG&E and/or LKE of $ 21 million no VEBA Funds Receivable (PPL Electric) In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. There was no intercompany receivable balance associated with these funds as of September 30, 2023, which would be reflected in "Accounts receivable from affiliates" on the PPL Electric Balance Sheets. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022.
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 2023 2022 2023 2022 PPL Electric from PPL Services $ 52 $ 51 $ 166 $ 172 LG&E from LKS 25 34 85 114 LG&E from PPL Services 10 — 30 — KU from LKS 35 39 110 125 KU from PPL Services 11 — 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 $500 million revolving line of credit with a PPL Electric subsidiary. At September 30, 2023 and December 31, 2022, CEP Reserves had 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, 2023, LG&E's money pool unused capacity was $744 million. At September 30, 2023, LG&E had borrowings outstanding from KU and/or LKE of $ 6 million no 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, 2023, KU's money pool unused capacity was $604 million. At September 30, 2023, KU had borrowings outstanding from LG&E and/or LKE of $ 21 million no VEBA Funds Receivable (PPL Electric) In 2018, PPL received a favorable private letter ruling from the IRS permitting a transfer of excess funds from the PPL Bargaining Unit Retiree Health Plan VEBA to a new subaccount within the VEBA, to be used to pay medical claims of active bargaining unit employees. Based on PPL Electric's participation in PPL’s Other Postretirement Benefit plan, PPL Electric was allocated a portion of the excess funds from PPL Services. These funds have been recorded as an intercompany receivable on PPL Electric's Balance Sheets. The receivable balance decreases as PPL Electric pays incurred medical claims and is reimbursed by PPL Services. There was no intercompany receivable balance associated with these funds as of September 30, 2023, which would be reflected in "Accounts receivable from affiliates" on the PPL Electric Balance Sheets. The intercompany receivable balance associated with these funds was immaterial as of December 31, 2022.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2023
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 2022 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, 2023 December 31, 2022 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 353 $ 353 $ — $ — $ 356 $ 356 $ — $ — Restricted cash and cash equivalents (a) 1 1 — — 1 1 — — Total Cash, Cash Equivalents and Restricted Cash (b) 354 354 — — 357 357 — — Special use funds (a): Money market fund 1 1 — — 1 1 — — Commingled debt fund measured at NAV (c) 10 — — — 13 — — — Commingled equity fund measured at NAV (c) 9 — — — 11 — — — Total special use funds 20 1 — — 25 1 — — Price risk management assets (d): Gas contracts — — — — 25 — 25 — Total assets $ 374 $ 355 $ — $ — $ 407 $ 358 $ 25 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Gas contracts 34 — 23 11 66 — 10 56 Total price risk management liabilities $ 37 $ — $ 26 $ 11 $ 73 $ — $ 17 $ 56 PPL Electric Assets Cash and cash equivalents $ 56 $ 56 $ — $ — $ 25 $ 25 $ — $ — Total assets $ 56 $ 56 $ — $ — $ 25 $ 25 $ — $ — LG&E Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 93 $ 93 $ — $ — Total assets $ 8 $ 8 $ — $ — $ 93 $ 93 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 21 $ 21 $ — $ — Total assets $ 8 $ 8 $ — $ — $ 21 $ 21 $ — $ — (a) Included in "Other current 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 asset" 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 2023 Balance at beginning of period $ 56 Purchases 11 Settlements (56) Balance at end of period $ 11 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, 2023 December 31, 2022 Carrying Fair Value Carrying Fair Value PPL $ 14,575 $ 13,027 $ 13,243 $ 12,239 PPL Electric 4,656 4,185 4,486 4,259 LG&E 2,404 2,150 2,307 2,128 KU 3,004 2,594 2,920 2,616 (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, 2023
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 Senior Director-Risk Management, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program. Market Risk Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices and interest rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected. The following summarizes the market risks that affect PPL and its subsidiaries. Interest Rate Risk • PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates, when appropriate, in connection with future debt issuance. • PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated utilities due to the recovery methods in place. Commodity Price Risk PPL is exposed to commodity price risk through its subsidiaries as described below. • PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is mitigated through its PAPUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers. • LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply costs. These mechanisms generally provide for timely recovery of market price fluctuations associated with these costs. • RIE utilizes derivative instruments pursuant to its RIPUC-approved plan to manage commodity price risk associated with its natural gas purchases. RIE's commodity price risk management strategy is to reduce fluctuations in firm gas sales prices to its customers. RIE's costs associated with derivatives instruments are recoverable through its RIPUC-approved cost recovery mechanisms. RIE is required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices. Volumetric Risk Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below: • PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases. • RIE is exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates. Equity Securities Price Risk • PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place. • PPL is exposed to equity securities price risk from future stock sales and/or purchases. Credit Risk Credit risk is the potential loss that may be incurred due to a counterparty's non-performance. PPL is exposed to credit risk from "in-the-money" transactions with counterparties as well as additional credit risk through certain of its subsidiaries, as discussed below. In the event a supplier of PPL, PPL Electric, LG&E or KU defaults on its contractual obligation, those Registrants would be required to seek replacement power or replacement fuel in the market. In general, subject to regulatory review or other processes, appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, in the event that the counterparties' credit ratings fall below investment grade, their tangible net worth falls below specified percentages or their exposures exceed an established credit limit. Master Netting Arrangements (PPL, LG&E and KU) Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. PPL, LG&E and KU had no obligation to return or post cash collateral under master netting arrangements at September 30, 2023 and December 31, 2022. 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, 2023. 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, 2023 and 2022, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At September 30, 2023, 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, 2023, 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, 2023, RIE held contracts with notional volumes of 54 Bcf that range in maturity through 2025. 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, 2023 and December 31, 2022. See Note 1 in each Registrant's 2022 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, 2023 December 31, 2022 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps (a) $ — $ — $ — $ 1 Gas contracts (a) — 29 20 62 Total current — 29 20 63 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps (a) — 3 — 6 Gas contracts (a) — 5 5 4 Total noncurrent — 8 5 10 Total derivatives $ — $ 37 $ 25 $ 73 (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, 2023. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of 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 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, 2022. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of Gain (Loss) Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ — $ (2) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Nine Months Interest rate swaps Interest expense $ — $ 1 Gas contracts Energy purchases 17 26 Total $ 17 $ 27 Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 3 $ 11 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 Other Income (Expense) - net Interest Expense Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 165 $ 16 $ 494 $ 51 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, 2022. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Other Income (Expense) - net Interest Expense Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 136 $ 10 $ 361 $ 36 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 — — (2) — (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, 2023 December 31, 2022 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ — $ — $ 1 Total current — — — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 3 — 6 Total noncurrent — 3 — 6 Total derivatives $ — $ 3 $ — $ 7 The following tables present the pre-tax effect of derivatives not designated as cash flow hedges that are recognized in income or regulatory assets 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 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, 2022. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ — $ 1 Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 3 $ 11 (PPL, LG&E and KU) Offsetting Derivative Instruments PPL, LG&E and KU or certain of their subsidiaries have master netting arrangements in place and also enter into agreements pursuant to which they purchase or sell certain energy and other products. Under the agreements, upon termination of the agreement as a result of a default or other termination event, the non-defaulting party typically would have a right to set off amounts owed under the agreement against any other obligations arising between the two parties (whether under the agreement or not), whether matured or contingent and irrespective of the currency, place of payment or place of booking of the obligation. PPL, LG&E and KU have elected not to offset derivative assets and liabilities and not to offset net derivative positions against the right to reclaim cash collateral pledged (an asset) or the obligation to return cash collateral received (a liability) under derivatives agreements. The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net September 30, 2023 Derivatives PPL $ — $ — $ — $ — $ 37 $ — $ — $ 37 LG&E — — — — 3 — — 3 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7 Credit Risk-Related Contingent Features Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions. Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, amounts 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, 2023, derivative contracts in a net liability position that contain credit risk-related contingent features was $21 million. The aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $22 million.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2023
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 rule. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2022 $ 177 $ 86 $ 82 Accretion 6 3 3 New obligations incurred 2 1 1 Changes in estimated cash flow or settlement date 14 11 5 Obligations settled (26) (9) (17) Other (5) (6) — Balance at September 30, 2023 $ 168 $ 86 $ 74
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 rule. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2022 $ 177 $ 86 $ 82 Accretion 6 3 3 New obligations incurred 2 1 1 Changes in estimated cash flow or settlement date 14 11 5 Obligations settled (26) (9) (17) Other (5) (6) — Balance at September 30, 2023 $ 168 $ 86 $ 74
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 rule. LG&E also has AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E and KU, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2022 $ 177 $ 86 $ 82 Accretion 6 3 3 New obligations incurred 2 1 1 Changes in estimated cash flow or settlement date 14 11 5 Obligations settled (26) (9) (17) Other (5) (6) — Balance at September 30, 2023 $ 168 $ 86 $ 74

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	9 Months Ended
	Sep. 30, 2023
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, 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) 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) June 30, 2022 $ 2 $ 2 $ (6) $ (122) $ (124) Amounts arising during the period — — — (10) (10) Reclassifications from AOCI — — 1 3 4 Net OCI during the period — — 1 (7) (6) September 30, 2022 $ 2 $ 2 $ (5) $ (129) $ (130) December 31, 2021 $ 1 $ — $ (6) $ (152) $ (157) Amounts arising during the period — 2 (1) 11 12 Reclassifications from AOCI 1 — 2 12 15 Net OCI during the period 1 2 1 23 27 September 30, 2022 $ 2 $ 2 $ (5) $ (129) $ (130) 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 2023 2022 2023 2022 Statements of Income Qualifying derivatives Interest rate swaps $ (1) $ — $ (3) $ (2) Interest Expense Total Pre-tax (1) — (3) (2) Income Taxes — — 1 1 Total After-tax (1) — (2) (1) Defined benefit plans Prior service costs (a) — (2) (1) (3) Net actuarial loss (a) (1) (5) 1 (17) Total Pre-tax (1) (7) — (20) Income Taxes 1 3 — 6 Total After-tax — (4) — (14) Total reclassifications during the period $ (1) $ (4) $ (2) $ (15) (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, 2023
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, 2022 is derived from that Registrant's 2022 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 2022 Form 10-K. The results of operations for the three and nine months ended September 30, 2023 are not necessarily indicative of the results to be expected for the full year ending December 31, 2023 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations. (PPL ) 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). The results of Narragansett Electric are included in the consolidated results of PPL from the date of the Acquisition. Following the closing of the Acquisition,

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2023
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 2022 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 $ 353 $ 356 Restricted cash - current (a) 1 1 Total Cash, Cash Equivalents and Restricted Cash $ 354 $ 357 (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."

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Sep. 30, 2023
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	3. Revenue from Contracts with Customers (All Registrants) See Note 3 in the Registrants' 2022 Form 10-K for a discussion of the principal activities from which PPL Electric, LG&E and KU and PPL’s Pennsylvania Regulated, Rhode Island Regulated, and Kentucky Regulated segments generate their revenues. The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended September 30. 2023 Three Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 2,043 $ 737 $ 398 $ 505 Revenues derived from: Alternative revenue programs (b) 1 (2) — — Other (c) (6) (4) (1) (2) Revenues from Contracts with Customers $ 2,038 $ 731 $ 397 $ 503 2022 Three Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 2,134 $ 766 $ 436 $ 553 Revenues derived from: Alternative revenue programs (b) 51 3 3 1 Other (c) (8) (4) (1) (2) Revenues from Contracts with Customers $ 2,177 $ 765 $ 438 $ 552 2023 Nine Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 6,281 $ 2,295 $ 1,227 $ 1,439 Revenues derived from: Alternative revenue programs (b) 42 5 1 (3) Other (c) (17) (11) (3) (3) Revenues from Contracts with Customers $ 6,306 $ 2,289 $ 1,225 $ 1,433 2022 Nine Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,612 $ 2,217 $ 1,339 $ 1,569 Revenues derived from: Alternative revenue programs (b) (16) (56) 12 5 Other (c) (21) (11) (5) (3) Revenues from Contracts with Customers $ 5,575 $ 2,150 $ 1,346 $ 1,571 (a) PPL includes $413 million and $1.4 billion for the three and nine months ended September 30, 2023 and $384 million and $512 million for the three and nine months ended September 30, 2022 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information. (b) This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts. For PPL Electric, the nine months ended September 30, 2022, included $74 million related to the amortization of the regulatory liability recorded in 2021 for a reduction in the transmission formula rate return on equity that was reflected in rates in 2022. (c) Represents additional revenues outside the scope of revenues from contracts with customers, such as lease and other miscellaneous revenues. 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 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 Corp and Other — — — — — — — — Total PPL $ 866 $ 405 $ 179 $ 316 $ 6 $ 17 $ 249 $ 2,038 2022 PA Regulated $ 407 $ 135 $ 22 $ 13 $ — $ — $ 188 $ 765 KY Regulated 401 284 176 88 8 21 — 978 RI Regulated 100 34 3 251 — — 39 427 Corp and Other — — — 7 — — — 7 Total PPL $ 908 $ 453 $ 201 $ 359 $ 8 $ 21 $ 227 $ 2,177 PPL Electric 2023 $ 389 $ 113 $ 13 $ 14 $ — $ — $ 202 $ 731 2022 $ 407 $ 135 $ 22 $ 13 $ — $ — $ 188 $ 765 LG&E 2023 $ 182 $ 127 $ 49 $ 33 $ — $ 6 $ — $ 397 2022 $ 200 $ 140 $ 53 $ 39 $ — $ 6 $ — $ 438 KU 2023 $ 185 $ 133 $ 113 $ 45 $ 6 $ 21 $ — $ 503 2022 $ 201 $ 144 $ 123 $ 51 $ 8 $ 25 $ — $ 552 Nine Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 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 Corp and Other — — — — — — — — Total PPL $ 2,854 $ 1,299 $ 547 $ 831 $ 17 $ 37 $ 721 $ 6,306 2022 PA Regulated $ 1,189 $ 360 $ 67 $ 39 $ — $ — $ 495 $ 2,150 KY Regulated 1,218 805 497 264 22 66 — 2,872 RI Regulated 131 46 4 298 — — 55 534 Corp and Other — — — 19 — — — 19 Total PPL $ 2,538 $ 1,211 $ 568 $ 620 $ 22 $ 66 $ 550 $ 5,575 Nine Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL Electric 2023 $ 1,266 $ 346 $ 44 $ 40 $ — $ — $ 593 $ 2,289 2022 $ 1,189 $ 360 $ 67 $ 39 $ — $ — $ 495 $ 2,150 LG&E 2023 $ 574 $ 398 $ 145 $ 75 $ — $ 33 $ — $ 1,225 2022 $ 615 $ 410 $ 147 $ 125 $ — $ 49 $ — $ 1,346 KU 2023 $ 534 $ 373 $ 341 $ 130 $ 17 $ 38 $ — $ 1,433 2022 $ 603 $ 395 $ 350 $ 140 $ 22 $ 61 $ — $ 1,571 (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. As discussed in Note 2, PPL segments its business by geographic location. Revenues from external customers for each segment/geographic location are reconciled to revenues from contracts with customers in the footnotes to the tables above. Contract receivables from customers are primarily included in "Accounts receivable - Customer", "Unbilled revenues", and "Other noncurrent assets" on the Balance Sheets. The following table shows the accounts receivable and unbilled revenues balances that were impaired for the periods ended September 30. Three Months Nine Months 2023 2022 2023 2022 PPL $ 20 $ 21 $ 47 $ 55 PPL Electric 10 7 27 12 LG&E 2 2 3 4 KU 1 3 2 5 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, 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 Contract liabilities at December 31, 2021 $ 42 $ 25 $ 6 $ 6 Contract liabilities at September 30, 2022 35 18 6 6 Revenue recognized during the nine months ended September 30, 2022 that was included in the contract liability balance at December 31, 2021 25 12 6 6 Contract liabilities result from recording contractual billings in advance for customer attachments to the Registrants' infrastructure and payments received in excess of revenues earned to date. Advanced billings for customer attachments are generally recognized as revenue ratably over the quarterly billing period. Payments received in excess of revenues earned to date are recognized as revenue as services are delivered in subsequent periods.

Acquisitions, Development and D

Acquisitions, Development and Divestitures	9 Months Ended
	Sep. 30, 2023
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures	8. Acquisitions, Development and Divestitures (PPL) Acquisitions Acquisition of Narragansett Electric On May 25, 2022, PPL Rhode Island Holdings acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid 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 have entered into a transition services agreement (TSA), pursuant to which National Grid has agreed to provide certain transition services to Narragansett Electric to facilitate the transition of the operation of Narragansett Electric to PPL following the Acquisition, as agreed upon in the Narragansett share purchase agreement. The TSA is for an initial two-year term and is subject to extension as necessary to complete the successful transition. TSA costs of $59 million and $179 million were incurred 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 2022 Form 10-K for a complete listing of those commitments. PPL incurred the following expenses related to some of the remaining commitments for the three and nine months ended September 30, 2023: • RIE will forgo potential recovery of any and all transition costs which includes (1) the installation of certain information technology systems; (2) modification and enhancements to physical facilities in Rhode Island; and (3) incurring costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $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 $2 million and $6 million for the three and nine months ended September 30, 2023. Purchase Price Allocation The operations of Narragansett Electric are subject to the accounting for certain types of regulation as prescribed by GAAP. The carrying value of Narragansett Electric’s assets and liabilities subject to rate-setting and cost recovery provisions provide revenues derived from costs, including a return on investment of net assets and liabilities included in rate base. Therefore, the fair values of these assets and liabilities equal their carrying values. Accordingly, neither the assets acquired nor liabilities assumed reflect any adjustments related to these amounts. During the nine months ended September 30, 2023, the allocation of the purchase price to the assets acquired and liabilities assumed recorded in PPL's Consolidated Balance Sheet was adjusted, resulting in a net decrease to goodwill of $1 million. The one-year measurement period and the allocation of the purchase price was completed during the second quarter of 2023. Total goodwill resulting from the acquisition was $1,585 million. PPL has elected to not reflect the effects of purchase accounting in the separate financial statements of RIE or PPL's Rhode Island Regulated segment. Accordingly, the Rhode Island Regulated segment includes $725 million of acquired legacy goodwill. The remaining excess purchase price of $860 million is included in PPL's Corporate and Other category for segment reporting purposes. See Note 9 in the PPL's 2022 Form 10-K for additional information regarding the purchase price allocation of Narragansett Electric. Divestitures Sale of Safari Holdings On September 29, 2022, PPL signed a definitive agreement to sell all of Safari Holdings membership interests to Aspen Power Services, LLC (Aspen Power). On November 1, 2022, PPL completed the sale of Safari Holdings (the Transaction). Final closing adjustments were substantially completed in the first quarter of 2023, resulting in an increase to the loss on sale of $6 million ($5 million net of tax), which was recorded in "Other operation and maintenance" on the Statements of Income for the nine months ended September 30, 2023. An impairment charge of $67 million ($50 million net of tax benefit) was recorded in "Other operation and maintenance" on the Statements of Income for the three and nine months ended September 30, 2022. In connection with the closing of the Transaction, PPL provided certain guarantees and other assurances. See Note 10 for additional information.

Other Income (Expense) - net

Other Income (Expense) - net	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 Defined benefit plans - non-service credits (Note 9) $ 13 $ 7 $ 30 $ 27 Interest income (expense) 4 — 22 (2) AFUDC - equity component 7 8 21 17 Charitable contributions (1) (1) (3) (2) Miscellaneous (a) (7) (4) (19) (4) Other Income (Expense) - net $ 16 $ 10 $ 51 $ 36 (a) Includes legal expenses incurred and insurance reimbursements received related to litigation with a former affiliate, Talen Montana. See Note 10 for additional information. (PPL Electric) The details of "Other Income (Expense) - net" for the periods ended September 30, were: Three Months Nine Months 2023 2022 2023 2022 Defined benefit plans - non-service credits (Note 9) $ 5 $ 4 $ 15 $ 12 Interest income 1 1 6 1 AFUDC - equity component 4 4 12 12 Charitable contributions — — (2) (2) Miscellaneous (2) (3) (2) (4) Other Income (Expense) - net $ 8 $ 6 $ 29 $ 19

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Policies)	9 Months Ended
	Sep. 30, 2023
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, 2023
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 $ 353 $ 356 Restricted cash - current (a) 1 1 Total Cash, Cash Equivalents and Restricted Cash $ 354 $ 357 (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, 2023
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 2023 2022 2023 2022 Operating Revenues from external customers Kentucky Regulated $ 893 $ 977 $ 2,631 $ 2,864 Pennsylvania Regulated 737 766 2,295 2,217 Rhode Island Regulated 413 384 1,355 512 Corporate and Other — 7 — 19 Total $ 2,043 $ 2,134 $ 6,281 $ 5,612 Net Income (Loss) Kentucky Regulated $ 175 $ 164 $ 432 $ 465 Pennsylvania Regulated 136 143 384 410 Rhode Island Regulated 6 (26) 70 (55) Corporate and Other (87) (107) (259) (254) Total $ 230 $ 174 $ 627 $ 566 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 $ 16,867 $ 16,904 Pennsylvania Regulated 14,069 13,565 Rhode Island Regulated 6,393 6,081 Corporate and Other (a) 1,300 1,287 Total $ 38,629 $ 37,837 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	9 Months Ended
	Sep. 30, 2023
Revenue from Contracts with Customers [Line Items]
Reconciliation of Revenue from Contracts with Customers [Table Text Block]	The following tables reconcile "Operating Revenues" included in each Registrant's Statement of Income with revenues generated from contracts with customers for the periods ended September 30. 2023 Three Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 2,043 $ 737 $ 398 $ 505 Revenues derived from: Alternative revenue programs (b) 1 (2) — — Other (c) (6) (4) (1) (2) Revenues from Contracts with Customers $ 2,038 $ 731 $ 397 $ 503 2022 Three Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 2,134 $ 766 $ 436 $ 553 Revenues derived from: Alternative revenue programs (b) 51 3 3 1 Other (c) (8) (4) (1) (2) Revenues from Contracts with Customers $ 2,177 $ 765 $ 438 $ 552 2023 Nine Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 6,281 $ 2,295 $ 1,227 $ 1,439 Revenues derived from: Alternative revenue programs (b) 42 5 1 (3) Other (c) (17) (11) (3) (3) Revenues from Contracts with Customers $ 6,306 $ 2,289 $ 1,225 $ 1,433 2022 Nine Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 5,612 $ 2,217 $ 1,339 $ 1,569 Revenues derived from: Alternative revenue programs (b) (16) (56) 12 5 Other (c) (21) (11) (5) (3) Revenues from Contracts with Customers $ 5,575 $ 2,150 $ 1,346 $ 1,571 (a) PPL includes $413 million and $1.4 billion for the three and nine months ended September 30, 2023 and $384 million and $512 million for the three and nine months ended September 30, 2022 of revenues from external customers reported by the Rhode Island Regulated segment. PPL Electric represents revenues from external customers reported by the Pennsylvania Regulated segment and LG&E and KU, net of intercompany power sales and transmission revenues, represent revenues from external customers reported by the Kentucky Regulated segment. See Note 2 for additional information. (b) This line item shows the over/under collection of rate mechanisms deemed alternative revenue programs with over-collections of revenue shown as positive amounts in the table above and under-collections shown as negative amounts. For PPL Electric, the nine months ended September 30, 2022, included $74 million related to the amortization of the regulatory liability recorded in 2021 for a reduction in the transmission formula rate return on equity that was reflected in rates in 2022. (c) Represents additional revenues outside the scope of revenues from contracts with customers, such as lease and other miscellaneous revenues.
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 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 Corp and Other — — — — — — — — Total PPL $ 866 $ 405 $ 179 $ 316 $ 6 $ 17 $ 249 $ 2,038 2022 PA Regulated $ 407 $ 135 $ 22 $ 13 $ — $ — $ 188 $ 765 KY Regulated 401 284 176 88 8 21 — 978 RI Regulated 100 34 3 251 — — 39 427 Corp and Other — — — 7 — — — 7 Total PPL $ 908 $ 453 $ 201 $ 359 $ 8 $ 21 $ 227 $ 2,177 PPL Electric 2023 $ 389 $ 113 $ 13 $ 14 $ — $ — $ 202 $ 731 2022 $ 407 $ 135 $ 22 $ 13 $ — $ — $ 188 $ 765 LG&E 2023 $ 182 $ 127 $ 49 $ 33 $ — $ 6 $ — $ 397 2022 $ 200 $ 140 $ 53 $ 39 $ — $ 6 $ — $ 438 KU 2023 $ 185 $ 133 $ 113 $ 45 $ 6 $ 21 $ — $ 503 2022 $ 201 $ 144 $ 123 $ 51 $ 8 $ 25 $ — $ 552 Nine Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 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 Corp and Other — — — — — — — — Total PPL $ 2,854 $ 1,299 $ 547 $ 831 $ 17 $ 37 $ 721 $ 6,306 2022 PA Regulated $ 1,189 $ 360 $ 67 $ 39 $ — $ — $ 495 $ 2,150 KY Regulated 1,218 805 497 264 22 66 — 2,872 RI Regulated 131 46 4 298 — — 55 534 Corp and Other — — — 19 — — — 19 Total PPL $ 2,538 $ 1,211 $ 568 $ 620 $ 22 $ 66 $ 550 $ 5,575 Nine Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL Electric 2023 $ 1,266 $ 346 $ 44 $ 40 $ — $ — $ 593 $ 2,289 2022 $ 1,189 $ 360 $ 67 $ 39 $ — $ — $ 495 $ 2,150 LG&E 2023 $ 574 $ 398 $ 145 $ 75 $ — $ 33 $ — $ 1,225 2022 $ 615 $ 410 $ 147 $ 125 $ — $ 49 $ — $ 1,346 KU 2023 $ 534 $ 373 $ 341 $ 130 $ 17 $ 38 $ — $ 1,433 2022 $ 603 $ 395 $ 350 $ 140 $ 22 $ 61 $ — $ 1,571 (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 2023 2022 2023 2022 PPL $ 20 $ 21 $ 47 $ 55 PPL Electric 10 7 27 12 LG&E 2 2 3 4 KU 1 3 2 5
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, 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 Contract liabilities at December 31, 2021 $ 42 $ 25 $ 6 $ 6 Contract liabilities at September 30, 2022 35 18 6 6 Revenue recognized during the nine months ended September 30, 2022 that was included in the contract liability balance at December 31, 2021 25 12 6 6

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 Income (Numerator) Net income attributable to PPL $ 230 $ 174 $ 627 $ 566 Less amounts allocated to participating securities — — 1 — Net income available to PPL common shareowners - Basic and Diluted $ 230 $ 174 $ 626 $ 566 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,107 736,247 737,005 735,912 Add: Dilutive share-based payment awards 1,077 827 1,016 767 Weighted-average shares - Diluted EPS 738,184 737,074 738,021 736,679 Basic and Diluted EPS Net Income available to PPL common shareowners $ 0.31 $ 0.24 $ 0.85 $ 0.77
Common Stock Issuances	For the periods ended September 30, PPL issued shares of common stock related to stock-based compensation plans as follows (in thousands): Three Months Nine Months 2023 2022 2023 2022 Stock-based compensation plans — — — 124
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 2023 2022 2023 2022 Stock-based compensation awards 179 17 324 79

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 60 $ 45 $ 167 $ 150 Increase (decrease) due to: State income taxes, net of federal income tax benefit 16 8 49 56 Valuation allowance adjustments 1 (1) 6 9 Income tax credits (a) (9) (1) (11) (3) Amortization of investment tax credit including deferred taxes on basis adjustment (1) — (2) (7) Depreciation and other items not normalized (2) — (9) (8) Amortization of excess deferred federal and state income taxes (13) (7) (33) (47) Federal and state income tax return adjustments 3 — (2) (1) State income tax rate change (b) 1 (5) — (5) Other 2 2 5 3 Total increase (decrease) (2) (4) 3 (3) Total income tax expense (benefit) $ 58 $ 41 $ 170 $ 147 (a) The three and nine month periods ended September 30, 2023 primarily include a deferred tax benefit from renewable tax credits that will be acquired at a discount. (b) The three and nine months ended September 30, 2022 include a deferred tax benefit of $5 million, due to the corporate net income tax rate reduction. See "Pennsylvania State Tax Reform" below for additional information.
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 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 38 $ 38 $ 107 $ 114 Increase (decrease) due to: State income taxes, net of federal income tax benefit 13 14 36 43 Depreciation and other items not normalized (1) (1) (8) (7) Amortization of excess deferred federal and state income taxes (4) (4) (8) (9) State income tax rate change (a) — (9) (1) (9) Other (3) (1) — (1) Total increase (decrease) 5 (1) 19 17 Total income tax expense (benefit) $ 43 $ 37 $ 126 $ 131
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 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 21 $ 21 $ 56 $ 57 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 4 10 11 Amortization of excess deferred federal and state income taxes (3) (3) (9) (17) Other (1) (1) (2) (2) Total increase (decrease) — — (1) (8) Total income tax expense (benefit) $ 21 $ 21 $ 55 $ 49
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 2023 2022 2023 2022 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 26 $ 25 $ 63 $ 70 Increase (decrease) due to: State income taxes, net of federal income tax benefit 5 5 12 13 Amortization of excess deferred federal and state income taxes (5) (4) (13) (16) Other (2) (2) (3) (4) Total increase (decrease) (2) (1) (4) (7) Total income tax expense (benefit) $ 24 $ 24 $ 59 $ 63

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	9 Months Ended
	Sep. 30, 2023
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: Gas supply clause $ — $ 41 $ — $ — $ — $ 13 $ — $ — Rate adjustment mechanisms 210 96 — — — — — — Renewable energy certificates 13 14 — — — — — — Derivative instruments 29 41 — — — — — — Smart meter rider 5 5 5 5 — — — — Storm damage costs 5 — 5 — — — — — Universal service rider 10 3 10 3 — — — — Fuel adjustment clause 8 38 — — 3 9 5 29 Transmission service charge 24 — 24 — — — — — Distribution system improvement charge 8 5 8 5 — — — — Other 3 15 — — 2 1 2 3 Total current regulatory assets $ 315 $ 258 $ 52 $ 13 $ 5 $ 23 $ 7 $ 32 Noncurrent Regulatory Assets: Defined benefit plans $ 795 $ 778 $ 371 $ 353 $ 204 $ 209 $ 137 $ 140 Plant outage costs 40 46 — — 10 12 30 34 Net metering 98 61 — — — — — — Environmental cost recovery 100 102 — — — — — — Taxes recoverable through future rates — 47 — — — — — — Storm costs 97 118 — — 15 7 14 3 Unamortized loss on debt 24 21 4 3 11 11 7 7 Interest rate swaps 3 7 — — 3 7 — — Terminated interest rate swaps 59 63 — — 35 37 24 26 Accumulated cost of removal of utility plant 186 212 186 212 — — — — AROs 290 295 — — 76 76 214 219 Derivatives instruments 5 — — — — — — — Other 90 69 — — 26 14 16 13 Total noncurrent regulatory assets $ 1,787 $ 1,819 $ 561 $ 568 $ 380 $ 373 $ 442 $ 442 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 $ 41 $ 37 $ 41 $ 37 $ — $ — $ — $ — Transmission service charge — 14 — 7 — — — — TCJA customer refund 7 15 7 15 — — — — Act 129 compliance rider 17 14 17 14 — — — — Transmission formula rate 18 12 18 12 — — — — Rate adjustment mechanism 147 96 — — — — — — Energy efficiency 23 23 — — — — — — Gas supply clause 18 — — — 18 — — — Other 9 27 — — 5 7 11 6 Total current regulatory liabilities $ 280 $ 238 $ 83 $ 85 $ 23 $ 7 $ 11 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 991 $ 950 $ — $ — $ 301 $ 287 $ 400 $ 389 Power purchase agreement - OVEC 20 26 — — 14 18 6 8 Net deferred taxes 1,999 2,094 772 775 465 477 528 546 Defined benefit plans 240 187 66 45 21 21 57 56 Terminated interest rate swaps 58 60 — — 29 30 29 30 Energy efficiency 39 32 — — — — — — Other 37 63 — — — — 2 — Total noncurrent regulatory liabilities $ 3,384 $ 3,412 $ 838 $ 820 $ 830 $ 833 $ 1,022 $ 1,029

Financing Activities (Tables)

Financing Activities (Tables)	9 Months Ended
	Sep. 30, 2023
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The following credit facilities were in place at: September 30, 2023 December 31, 2022 Expiration Capacity Borrowed Letters of Unused Borrowed Letters of PPL PPL Capital Funding (a) Syndicated Credit Facility (b) Dec. 2027 $ 1,250 $ — $ 75 $ 1,175 $ — $ 561 Bilateral Credit Facility Mar. 2024 100 — — 100 — — Bilateral Credit Facility Mar. 2024 100 — 13 87 — 58 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 88 $ 1,362 $ — $ 619 PPL Electric Syndicated Credit Facility Dec. 2027 $ 650 $ — $ 188 $ 462 $ — $ 146 Term Loan Credit Facility Mar. 2024 — — — — 250 — Total PPL Electric Credit Facilities $ 650 $ — $ 188 $ 462 $ 250 $ 146 LG&E Syndicated Credit Facility Dec. 2027 $ 500 $ — $ — $ 500 $ — $ 180 Term Loan Credit Facility Jul. 2024 — — — — 300 — Total LG&E Credit Facilities $ 500 $ — $ — $ 500 $ 300 $ 180 KU Syndicated Credit Facility Dec. 2027 $ 400 $ — $ 25 $ 375 $ — $ 101 Term Loan Credit Facility Jul. 2024 — — — — 300 — Total KU Credit Facilities $ 400 $ — $ 25 $ 375 $ 300 $ 101 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) Includes a $250 million borrowing sublimit for RIE and a $1 billion sublimit for PPL Capital Funding. At September 30, 2023, PPL Capital Funding had no commercial paper outstanding and RIE had $75 million of 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, 2023 December 31, 2022 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) (b) $ 1,350 $ — $ 1,350 4.84% $ 561 RIE (b) 5.49% 400 75 325 — PPL Electric 5.47% 650 187 463 4.74% 145 LG&E 500 — 500 4.94% 180 KU 5.45% 400 25 375 4.90% 101 Total $ 3,300 $ 287 $ 3,013 $ 987 (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 and under which they are both borrowers. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. The PPL Capital Funding syndicated credit facility includes a borrowing sublimit for RIE, which is currently set at $250 million with the remaining $1 billion allocated to PPL Capital Funding. RIE's obligations under the facility are not guaranteed by PPL. The sublimits of each borrower may be decreased or increased at the borrowers’ option up to a prescribed amount such that all borrowings under the syndicated credit facility cannot exceed the size of the credit facility of $1.25 billion. (c) Commercial paper issued reflects the undiscounted face value of the issuance.

Defined Benefits (Tables)

Defined Benefits (Tables)	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 PPL Service cost $ 8 $ 11 $ 25 $ 36 Interest cost 47 33 141 95 Expected return on plan assets (77) (62) (232) (189) Amortization of: Prior service cost 2 2 5 6 Actuarial loss 1 11 2 40 Net periodic defined benefit costs (credits) before settlements (19) (5) (59) (12) Settlements (a) — 7 — 19 Net periodic defined benefit costs (credits) $ (19) $ 2 $ (59) $ 7 (a) Due to the amount of lump sum payment distributions from the LKE qualified pension plan, settlement charges were incurred during the three and nine months ended, September 30, 2022. In accordance with existing regulatory accounting treatment, LG&E and KU have primarily maintained the settlement charge in regulatory assets to be amortized over 15 years. Other Postretirement Benefits Three Months Nine Months 2023 2022 2023 2022 PPL Service cost $ 1 $ 1 $ 4 $ 4 Interest cost 8 3 23 11 Expected return on plan assets (7) (5) (22) (17) Amortization of: Prior service cost — — 1 1 Actuarial loss (1) — (4) (2) Net periodic defined benefit costs (credits) $ 1 $ (1) $ 2 $ (3)

Commitments and Contingencies (

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2023
Commitments and Contingencies Disclosure [Abstract]
Guarantees	The table below details guarantees provided as of September 30, 2023. Exposure at September 30, 2023 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 $ 129 (b) 2028 PPL guarantee of Safari payment obligations under certain PPAs related to the sale of Safari Holdings 33 (c) Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings 140 (d) 2028 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (e) (a) PPL WPD Limited entered into a Tax Deed dated June 9, 2021, in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million. (b) PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million. (c) PPL guaranteed the payment obligations of Safari under certain PPAs executed by Safari. Aspen Power is expected to replace these guarantees and retain liability for any payments made by PPL or claims against PPL under any guarantee that is not replaced. (d) Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. 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 and PPAs that will be replaced by Aspen Power.

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 PPL Electric from PPL Services $ 52 $ 51 $ 166 $ 172 LG&E from LKS 25 34 85 114 LG&E from PPL Services 10 — 30 — KU from LKS 35 39 110 125 KU from PPL Services 11 — 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 2023 2022 2023 2022 PPL Electric from PPL Services $ 52 $ 51 $ 166 $ 172 LG&E from LKS 25 34 85 114 LG&E from PPL Services 10 — 30 — KU from LKS 35 39 110 125 KU from PPL Services 11 — 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 2023 2022 2023 2022 PPL Electric from PPL Services $ 52 $ 51 $ 166 $ 172 LG&E from LKS 25 34 85 114 LG&E from PPL Services 10 — 30 — KU from LKS 35 39 110 125 KU from PPL Services 11 — 33 —

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	9 Months Ended
	Sep. 30, 2023
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 2023 2022 2023 2022 Defined benefit plans - non-service credits (Note 9) $ 13 $ 7 $ 30 $ 27 Interest income (expense) 4 — 22 (2) AFUDC - equity component 7 8 21 17 Charitable contributions (1) (1) (3) (2) Miscellaneous (a) (7) (4) (19) (4) Other Income (Expense) - net $ 16 $ 10 $ 51 $ 36 (a) Includes legal expenses incurred and insurance reimbursements received related to litigation with a former affiliate, Talen Montana. See Note 10 for additional information.
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 2023 2022 2023 2022 Defined benefit plans - non-service credits (Note 9) $ 5 $ 4 $ 15 $ 12 Interest income 1 1 6 1 AFUDC - equity component 4 4 12 12 Charitable contributions — — (2) (2) Miscellaneous (2) (3) (2) (4) Other Income (Expense) - net $ 8 $ 6 $ 29 $ 19

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2023
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, 2023 December 31, 2022 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 353 $ 353 $ — $ — $ 356 $ 356 $ — $ — Restricted cash and cash equivalents (a) 1 1 — — 1 1 — — Total Cash, Cash Equivalents and Restricted Cash (b) 354 354 — — 357 357 — — Special use funds (a): Money market fund 1 1 — — 1 1 — — Commingled debt fund measured at NAV (c) 10 — — — 13 — — — Commingled equity fund measured at NAV (c) 9 — — — 11 — — — Total special use funds 20 1 — — 25 1 — — Price risk management assets (d): Gas contracts — — — — 25 — 25 — Total assets $ 374 $ 355 $ — $ — $ 407 $ 358 $ 25 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Gas contracts 34 — 23 11 66 — 10 56 Total price risk management liabilities $ 37 $ — $ 26 $ 11 $ 73 $ — $ 17 $ 56 PPL Electric Assets Cash and cash equivalents $ 56 $ 56 $ — $ — $ 25 $ 25 $ — $ — Total assets $ 56 $ 56 $ — $ — $ 25 $ 25 $ — $ — LG&E Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 93 $ 93 $ — $ — Total assets $ 8 $ 8 $ — $ — $ 93 $ 93 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 3 $ — $ 3 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 21 $ 21 $ — $ — Total assets $ 8 $ 8 $ — $ — $ 21 $ 21 $ — $ — (a) Included in "Other current 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 asset" 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 2023 Balance at beginning of period $ 56 Purchases 11 Settlements (56) Balance at end of period $ 11
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, 2023 December 31, 2022 Carrying Fair Value Carrying Fair Value PPL $ 14,575 $ 13,027 $ 13,243 $ 12,239 PPL Electric 4,656 4,185 4,486 4,259 LG&E 2,404 2,150 2,307 2,128 KU 3,004 2,594 2,920 2,616 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022
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, 2023 December 31, 2022 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps (a) $ — $ — $ — $ 1 Gas contracts (a) — 29 20 62 Total current — 29 20 63 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps (a) — 3 — 6 Gas contracts (a) — 5 5 4 Total noncurrent — 8 5 10 Total derivatives $ — $ 37 $ 25 $ 73 (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, 2023. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Other Income (Expense) - net Interest Expense Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 165 $ 16 $ 494 $ 51 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, 2022. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Nine Months Interest Expense Other Income (Expense) - net Interest Expense Other Income (Expense) - net Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 136 $ 10 $ 361 $ 36 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 — — (2) —
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net September 30, 2023 Derivatives PPL $ — $ — $ — $ — $ 37 $ — $ — $ 37 LG&E — — — — 3 — — 3 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7
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, 2023. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of 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 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, 2022. Three Months Nine Months Three Months Nine Months Derivative Derivative Gain Derivative Gain Location of Gain (Loss) Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — $ — Interest expense $ — $ (2) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Nine Months Interest rate swaps Interest expense $ — $ 1 Gas contracts Energy purchases 17 26 Total $ 17 $ 27 Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 3 $ 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, 2023 December 31, 2022 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ — $ — $ 1 Total current — — — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 3 — 6 Total noncurrent — 3 — 6 Total derivatives $ — $ 3 $ — $ 7
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, 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	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, 2022. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Nine Months Interest rate swaps Interest expense $ — $ 1 Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Nine Months Interest rate swaps Regulatory assets - noncurrent $ 3 $ 11
Derivative Positions Eligible for Offset with Related Cash Collateral	The table below summarizes the derivative positions presented in the balance sheets where a right of setoff exists under these arrangements and related cash collateral received or pledged. Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net September 30, 2023 Derivatives PPL $ — $ — $ — $ — $ 37 $ — $ — $ 37 LG&E — — — — 3 — — 3 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2022 Derivatives PPL $ 25 $ 20 $ — $ 5 $ 73 $ 62 $ — $ 11 LG&E — — — — 7 — — 7

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2023
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, 2022 $ 177 $ 86 $ 82 Accretion 6 3 3 New obligations incurred 2 1 1 Changes in estimated cash flow or settlement date 14 11 5 Obligations settled (26) (9) (17) Other (5) (6) — Balance at September 30, 2023 $ 168 $ 86 $ 74
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, 2022 $ 177 $ 86 $ 82 Accretion 6 3 3 New obligations incurred 2 1 1 Changes in estimated cash flow or settlement date 14 11 5 Obligations settled (26) (9) (17) Other (5) (6) — Balance at September 30, 2023 $ 168 $ 86 $ 74
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, 2022 $ 177 $ 86 $ 82 Accretion 6 3 3 New obligations incurred 2 1 1 Changes in estimated cash flow or settlement date 14 11 5 Obligations settled (26) (9) (17) Other (5) (6) — Balance at September 30, 2023 $ 168 $ 86 $ 74

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	9 Months Ended
	Sep. 30, 2023
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, 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) 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) June 30, 2022 $ 2 $ 2 $ (6) $ (122) $ (124) Amounts arising during the period — — — (10) (10) Reclassifications from AOCI — — 1 3 4 Net OCI during the period — — 1 (7) (6) September 30, 2022 $ 2 $ 2 $ (5) $ (129) $ (130) December 31, 2021 $ 1 $ — $ (6) $ (152) $ (157) Amounts arising during the period — 2 (1) 11 12 Reclassifications from AOCI 1 — 2 12 15 Net OCI during the period 1 2 1 23 27 September 30, 2022 $ 2 $ 2 $ (5) $ (129) $ (130)
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 2023 2022 2023 2022 Statements of Income Qualifying derivatives Interest rate swaps $ (1) $ — $ (3) $ (2) Interest Expense Total Pre-tax (1) — (3) (2) Income Taxes — — 1 1 Total After-tax (1) — (2) (1) Defined benefit plans Prior service costs (a) — (2) (1) (3) Net actuarial loss (a) (1) (5) 1 (17) Total Pre-tax (1) (7) — (20) Income Taxes 1 3 — 6 Total After-tax — (4) — (14) Total reclassifications during the period $ (1) $ (4) $ (2) $ (15) (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, 2023	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021
Summary Of Significant Accounting Policies [Line Items]
Goodwill	$ 2,247	$ 2,248
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	353	356
Restricted Cash, Current	1	1
Cash, Cash Equivalents and Restricted Cash	354	357
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	56	25
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	8	93	$ 25	$ 9
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	$ 8	$ 21	$ 25	$ 13

Segment and Related Informati_3

Segment and Related Information (Details) $ in Millions		3 Months Ended				9 Months Ended
		Sep. 30, 2023 USD ($)		Sep. 30, 2022 USD ($)		Sep. 30, 2023 USD ($) Integer		Sep. 30, 2022 USD ($)	Jun. 30, 2023 USD ($)	Dec. 31, 2022 USD ($)
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 2,043		$ 2,134		$ 6,281		$ 5,612
Net income (loss)		230		174		627		566
Balance Sheet Data [Abstract]
Assets		38,629				38,629				$ 37,837
Segment (Numeric) [Abstract]
Goodwill		2,247				$ 2,247				2,248
Number of Reportable Segments | Integer						3
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		893		977		$ 2,631		2,864
Net income (loss)		175		164		432		465
Balance Sheet Data [Abstract]
Assets		16,867				16,867				16,904
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		737		766		2,295		2,217
Net income (loss)		136		143		384		410
Balance Sheet Data [Abstract]
Assets		14,069				14,069				13,565
Corporate and Other [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		0		7		0		19
Net income (loss)		(87)		(107)		(259)		(254)
Balance Sheet Data [Abstract]
Assets		1,300				1,300				1,287
Rhode Island Regulated
Income Statement Data [Abstract]
Operating Revenues from external customers		413		384		1,355		512
Net income (loss)		6		(26)		70		(55)
Balance Sheet Data [Abstract]
Assets		6,393				6,393				6,081
Segment (Numeric) [Abstract]
Goodwill									$ 725
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		737		766		2,295		2,217
Net income (loss)	[1]	136		143		384		410
Balance Sheet Data [Abstract]
Assets		14,069				$ 14,069				13,565
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		398		436		$ 1,227		1,339
Net income (loss)		79	[2]	77	[2]	210	[2]	224
Balance Sheet Data [Abstract]
Assets		7,660				7,660				7,810
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		505		553		$ 1,439		1,569
Net income (loss)	[3]	101		$ 95		240		$ 268
Balance Sheet Data [Abstract]
Assets		9,635				9,635				9,542
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.[2]Net income equals comprehensive income.[3]Net income equals comprehensive income.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022	Dec. 31, 2021
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	$ 2,043	$ 2,134	$ 6,281	$ 5,612
Alternative Revenue Programs	1	51	42	(16)
Other Revenue	(6)	(8)	(17)	(21)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	2,038	2,177	6,306	5,575
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	20	21	47	55
Contract with Customer, Liability	33	35	33	35	$ 34	$ 42
Contract with Customer, Liability, Revenue Recognized			21	25
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	866	908	2,854	2,538
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	405	453	1,299	1,211
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	179	201	547	568
Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	316	359	831	620
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	8	17	22
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	17	21	37	66
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	249	227	721	550
Pennsylvania Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	737	766	2,295	2,217
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	731	765	2,289	2,150
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	389	407	1,266	1,189
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	113	135	346	360
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	13	22	44	67
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	14	13	40	39
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	202	188	593	495
Kentucky Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	893	977	2,631	2,864
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	891	978	2,624	2,872
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	367	401	1,108	1,218
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	260	284	771	805
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	162	176	486	497
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	79	88	205	264
Kentucky Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	8	17	22
Kentucky Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	17	21	37	66
Kentucky Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Corporate and Other [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	0	7	0	19
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	7	0	19
Corporate and Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Corporate and Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Corporate and Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Corporate and Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	7	0	19
Corporate and Other [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Corporate and Other [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Corporate and Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Rhode Island Regulated
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	413	384	1,355	512
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	416	427	1,393	534
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	110	100	480	131
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	32	34	182	46
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	4	3	17	4
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	223	251	586	298
Rhode Island Regulated | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Rhode Island Regulated | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0	0	0
Rhode Island Regulated | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	47	39	128	55
PPL Electric [Member]
Contract with Customer, Asset and Liability [Abstract]
Amortization of Revenue Reserve for ROE Challenge			74
PPL Electric Utilities Corp [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	737	766	2,295	2,217
Alternative Revenue Programs	(2)	3	5	(56)
Other Revenue	(4)	(4)	(11)	(11)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	731	765	2,289	2,150
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	10	7	27	12
Contract with Customer, Liability	21	18	21	18	23	25
Contract with Customer, Liability, Revenue Recognized			10	12
Amortization of Revenue Reserve for ROE Challenge			74
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	389	407	1,266	1,189
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	113	135	346	360
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	13	22	44	67
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	14	13	40	39
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	202	188	593	495
Louisville Gas And Electric Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	398	436	1,227	1,339
Alternative Revenue Programs	0	3	1	12
Other Revenue	(1)	(1)	(3)	(5)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	397	438	1,225	1,346
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	2	2	3	4
Contract with Customer, Liability	5	6	5	6	5	6
Contract with Customer, Liability, Revenue Recognized			5	6
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	182	200	574	615
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	127	140	398	410
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	49	53	145	147
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	33	39	75	125
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	33	49
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	505	553	1,439	1,569
Alternative Revenue Programs	0	1	(3)	5
Other Revenue	(2)	(2)	(3)	(3)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	503	552	1,433	1,571
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	3	2	5
Contract with Customer, Liability	6	6	6	6	$ 6	$ 6
Contract with Customer, Liability, Revenue Recognized			6	6
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	185	201	534	603
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	133	144	373	395
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	113	123	341	350
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	45	51	130	140
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	8	17	22
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	21	25	38	61
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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Income (Numerator) [Abstract]
Net income (loss)	$ 230	$ 174	$ 627	$ 566
Less amounts allocated to participating securities	0	0	1	0
Net income (loss) available to PPL common shareowners - Basic	230	174	626	566
Net income (loss) available to PPL common shareowners - Diluted	$ 230	$ 174	$ 626	$ 566
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	737,107	736,247	737,005	735,912
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	1,077	827	1,016	767
Weighted-average shares - Diluted EPS (in shares)	738,184	737,074	738,021	736,679
Income (Loss) from Continuing Operations after income taxes, Diluted	$ 0.31	$ 0.24	$ 0.85	$ 0.77
Income (Loss) from Continuing Operations After Income Taxes, Basic	0.31	0.24	0.85	0.77
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	0.31	0.24	0.85	0.77
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.31	$ 0.24	$ 0.85	$ 0.77
Shares Issued (Numeric) [Abstract]
Common stock issued under stock-based compensation plans (in shares)	0	0	0	124
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	179	17	324	79

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 60	$ 45	$ 167	$ 150
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	16	8	49	56
Depreciation and other items not normalized	(2)	0	(9)	(8)
Valuation allowance adjustments	1	(1)	6	9
Effective Income Tax Rate Reconciliation, Tax Credit, Amount	(9)	(1)	(11)	(3)
Amortization of excess deferred income taxes	(13)	(7)	(33)	(47)
State income tax rate change	(1)	5	0	5
Effective Income Tax Rate Reconciliation, Prior Year Income Taxes, Amount	3	0	(2)	(1)
Other	2	2	5	3
Total increase (decrease)	(2)	(4)	3	(3)
Total income tax expense (benefit)	58	41	170	147
Amortization of investment tax credit including deferred taxes on basis adjustment	(1)	0	(2)	(7)
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	38	38	107	114
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	13	14	36	43
Depreciation and other items not normalized	(1)	(1)	(8)	(7)
Amortization of excess deferred income taxes	(4)	(4)	(8)	(9)
State income tax rate change	0	9	1	9
Other	(3)	(1)	0	(1)
Total increase (decrease)	5	(1)	19	17
Total income tax expense (benefit)	43	37	126	131
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	21	21	56	57
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	4	4	10	11
Amortization of excess deferred income taxes	(3)	(3)	(9)	(17)
Other	(1)	(1)	(2)	(2)
Total increase (decrease)	0	0	(1)	(8)
Total income tax expense (benefit)	21	21	55	49
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	26	25	63	70
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	5	5	12	13
Amortization of excess deferred income taxes	(5)	(4)	(13)	(16)
Other	(2)	(2)	(3)	(4)
Total increase (decrease)	(2)	(1)	(4)	(7)
Total income tax expense (benefit)	$ 24	$ 24	$ 59	$ 63

Utility Rate Regulation - Regul

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Regulatory Assets [Line Items]
Current regulatory assets	$ 315	$ 258
Noncurrent regulatory assets	1,787	1,819
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	40	46
Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	41
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	5
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	24	0
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	795	778
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	97	118
Storm Costs [Member] | LGE [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	8
Storm Costs [Member] | KU [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	11
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	24	21
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	7
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	59	63
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	186	212
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	290	295
Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	3	15
Noncurrent regulatory assets	90	69
Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	0
Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	8	38
Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	98	61
Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	210	96
Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	100	102
Taxs recoverable through future rates
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	47
Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	29	41
Noncurrent regulatory assets	5	0
Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	13	14
Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	3
Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	5
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	52	13
Noncurrent regulatory assets	561	568
PPL Electric Utilities Corp [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	5
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	24	0
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	371	353
PPL Electric Utilities Corp [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	4	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	186	212
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	0
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Taxs recoverable through future rates
Regulatory Assets [Line Items]
Noncurrent 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] | Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	10	3
PPL Electric Utilities Corp [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	5
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	5	23
Noncurrent regulatory assets	380	373
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	10	12
Louisville Gas And Electric Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	13
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 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	204	209
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	15	7
Louisville Gas And Electric Co [Member] | Storm Costs [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	8
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	11	11
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	3	7
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	35	37
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	76	76
Louisville Gas And Electric Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	2	1
Noncurrent regulatory assets	26	14
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	3	9
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] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Taxs recoverable through future rates
Regulatory Assets [Line Items]
Noncurrent 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] | Renewable energy certificates
Regulatory Assets [Line Items]
Current 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
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	32
Noncurrent regulatory assets	442	442
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	30	34
Kentucky Utilities Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Smart Meter Rider [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	137	140
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	14	3
Kentucky Utilities Co [Member] | Storm Costs [Member] | Kentucky Public Service Commission [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	11
Kentucky Utilities Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	7	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	24	26
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	214	219
Kentucky Utilities Co [Member] | Other Regulatory Assets [Member]
Regulatory Assets [Line Items]
Current regulatory assets	2	3
Noncurrent regulatory assets	16	13
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	5	29
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] | Environmental Cost Recovery [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Taxs recoverable through future rates
Regulatory Assets [Line Items]
Noncurrent 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] | Renewable energy certificates
Regulatory Assets [Line Items]
Current 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

Utility Rate Regulation - Reg_2

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2023	Dec. 31, 2022
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 280	$ 238
Noncurrent regulatory liabilities	$ 3,384	3,412
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: Gas supply clause $ — $ 41 $ — $ — $ — $ 13 $ — $ — Rate adjustment mechanisms 210 96 — — — — — — Renewable energy certificates 13 14 — — — — — — Derivative instruments 29 41 — — — — — — Smart meter rider 5 5 5 5 — — — — Storm damage costs 5 — 5 — — — — — Universal service rider 10 3 10 3 — — — — Fuel adjustment clause 8 38 — — 3 9 5 29 Transmission service charge 24 — 24 — — — — — Distribution system improvement charge 8 5 8 5 — — — — Other 3 15 — — 2 1 2 3 Total current regulatory assets $ 315 $ 258 $ 52 $ 13 $ 5 $ 23 $ 7 $ 32 Noncurrent Regulatory Assets: Defined benefit plans $ 795 $ 778 $ 371 $ 353 $ 204 $ 209 $ 137 $ 140 Plant outage costs 40 46 — — 10 12 30 34 Net metering 98 61 — — — — — — Environmental cost recovery 100 102 — — — — — — Taxes recoverable through future rates — 47 — — — — — — Storm costs 97 118 — — 15 7 14 3 Unamortized loss on debt 24 21 4 3 11 11 7 7 Interest rate swaps 3 7 — — 3 7 — — Terminated interest rate swaps 59 63 — — 35 37 24 26 Accumulated cost of removal of utility plant 186 212 186 212 — — — — AROs 290 295 — — 76 76 214 219 Derivatives instruments 5 — — — — — — — Other 90 69 — — 26 14 16 13 Total noncurrent regulatory assets $ 1,787 $ 1,819 $ 561 $ 568 $ 380 $ 373 $ 442 $ 442 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 $ 41 $ 37 $ 41 $ 37 $ — $ — $ — $ — Transmission service charge — 14 — 7 — — — — TCJA customer refund 7 15 7 15 — — — — Act 129 compliance rider 17 14 17 14 — — — — Transmission formula rate 18 12 18 12 — — — — Rate adjustment mechanism 147 96 — — — — — — Energy efficiency 23 23 — — — — — — Gas supply clause 18 — — — 18 — — — Other 9 27 — — 5 7 11 6 Total current regulatory liabilities $ 280 $ 238 $ 83 $ 85 $ 23 $ 7 $ 11 $ 6 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 991 $ 950 $ — $ — $ 301 $ 287 $ 400 $ 389 Power purchase agreement - OVEC 20 26 — — 14 18 6 8 Net deferred taxes 1,999 2,094 772 775 465 477 528 546 Defined benefit plans 240 187 66 45 21 21 57 56 Terminated interest rate swaps 58 60 — — 29 30 29 30 Energy efficiency 39 32 — — — — — — Other 37 63 — — — — 2 — Total noncurrent regulatory liabilities $ 3,384 $ 3,412 $ 838 $ 820 $ 830 $ 833 $ 1,022 $ 1,029 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 (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 five 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 May 25, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under 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 on track for timely completion, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is now 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 has 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, and which, among other things, sought approval to deploy smart meters throughout the service territory. In 2021, the RIPUC stayed the AMF and GMP proceedings pending further consideration following the issuance of a final Order by the Rhode Island Division of Public Utilities and Carriers on the acquisition of RIE. RIE filed notice of withdrawal of the original Updated AMF Business Case and GMP with the RIPUC, and in November 2022 filed a new AMF Business Case with the RIPUC. The new AMF Business Case filing consists of a detailed proposal for full-scale deployment of AMF across its electric service territory. The proposal will enable significant customer and grid benefits in line with the state’s climate mandates. In its filing, RIE estimated that the proposed program would cost $188 million on a net present value (NPV) basis and provide benefits of $729 million NPV over the 20-year project life, yielding a benefit-cost ratio of 3.9x. RIE believes AMF is a foundational technology that is a necessary first step to transforming Rhode Island’s electric distribution system. 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 is required to file with the RIPUC (i) by December 27, 2023, an updated electric Service Quality Plan for RIPUC review and approval, and (ii) additional tariff provisions regarding recovery and plans that address certain programs related to AMF. 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 issue 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 how it would impact future electric ISR plans. COVID-19 Deferral Filing On April 30, 2021, RIE filed a petition for approval to recognize regulatory assets related to COVID-19 impacts (RIPUC Docket No. 5154). In its petition, RIE sought the RIPUC's authorization to create regulatory assets and consideration of future cost recovery for the following COVID-19 costs: (i) the increased cost of customer accounts receivable that RIE will be unable to collect as a result of the COVID-19 pandemic, and the executive orders and RIPUC orders restricting RIE's collection activities as a result of the pandemic, which will result in increased net charge-offs; (ii) lost revenue from unassessed late payment charges; and (iii) charges to RIE for other fees that RIE has waived pursuant to the RIPUC's orders in RIPUC Docket No. 5022. RIE is evaluating its request to create a regulatory asset for COVID-19-related bad debt expense to consider the impact, if any, of the proposed arrearage forgiveness sought in RIE’s Petition to Forgive Certain Arrearage Balances for Low-Income and Protected Customers in Docket No. 22-08-GE, which RIE filed with the RIPUC to fulfill its obligations under PPL's settlement with the Rhode Island Attorney General. 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. The RIPUC held an Open Meeting on September 13, 2022, and issued its Order on November 18, 2022 regarding the Proactive Main Replacement Program and made the following rulings: (i) commencing with the Gas ISR plan to be filed in this calendar year 2022 (prospectively), new main constructed to replace leak prone pipe will not be considered used and useful, and therefore not eligible for rate base treatment, until the related old main is abandoned; and (ii) approved the proactive main replacement revenue requirement set forth in the FY 2023 Gas ISR plan. Also, the RIPUC directed RIE to submit prefiled testimony on the issue of its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and to address three issues, specifically: (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. RIE filed this testimony with the RIPUC on May 16, 2022, the RIPUC has not taken any action to date on this issue. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan process. A new docket has been opened to address this matter with the goal of implementing changes for the FY 2025 ISR Plan. RIE cannot predict the outcome of these matters. The RIPUC held an evidentiary hearing on October 18, 2023, regarding RIE’s FY 2023 Gas ISR reconciliation, which is part of the distribution adjustment clause rates for effect November 1, 2023. During the hearing, a draft framework with conceptual parameters and principles for future gas ISR plans was introduced, which will be further discussed on November 7, 2023. FY 2024 Gas ISR Plan On December 23, 2022, RIE filed its FY 2024 Gas ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget that was filed with the RIPUC on January 27, 2023 includes $187 million of capital investment spend. The supplemental rate schedules were filed on February 3, 2023. RIE and the Rhode Island Division of Public Utilities and Carrier s reached an agreement on an approximately $171 million capital investment spending plan, and RIE filed a second supplemental budget on March 13, 2023. The RIPUC held a hearing on the plan on March 14, 2023. At an Open Meeting on March 29, 2023, the RIPUC approved the 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. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan review and approval process starting with the FY 2025 ISR Plan. A new docket will be opened to address this matter with the goal of implementing changes for the FY 2025 ISR Plan. RIE cannot predict the outcome of these matters. FY 2024 Electric ISR Plan On December 23, 2022, RIE filed its FY 2024 Electric ISR Plan with the RIPUC. At its January 20, 2023 Open Meeting, the RIPUC directed RIE to file supplemental budget and rate schedules to reflect an April 1 to March 31 fiscal year. The supplemental budget filed with the RIPUC on January 27, 2023 includes $176 million of capital investment spend, $14 million of vegetation operations and management (O&M) spend and $3 million of Other O&M spend. The supplemental rate schedules were filed on February 3, 2023. RIE filed second supplemental budget schedules on March 21, 2023, which includes $166 million of capital investment spend, $14 million of vegetation management O&M spend and $1 million of Other O&M spend. The RIPUC held hearings in March 2023, and on March 29, 2023, approved the plan 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 March 30, 2023 compliance filing for rates effective April 1, 2023. The RIPUC continues to consider the appropriate rate recovery treatment of projects not covered by an ISR plan for the applicable fiscal year, and additional definitions and procedures that may be implemented related to the ISR plan review and approval process. A new docket has been opened to address this matter with the goal of implementing changes for the FY 2025 ISR Plan. RIE cannot predict the outcome of these matters. Kentucky Activities (PPL, LG&E and KU) CPCN and SB 4 Application On December 15, 2022, LG&E and KU filed an application with the KPSC for a CPCN for the construction of two 621 MW net summer rating NGCC combustion turbine facilities, one at LG&E's Mill Creek Generating Station in Jefferson County, Kentucky and the other at KU's E.W. Brown Generating Station in Mercer County, Kentucky, including on-site natural gas and electric transmission construction associated with those facilities and site compatibility certificates. LG&E and KU also applied for a CPCN to construct a 120 MWac solar photovoltaic electric generating facility in Mercer County, Kentucky, and for a CPCN to acquire a 120 MWac solar facility to be built by a third-party solar developer in Marion County, Kentucky. LG&E and KU further applied for a CPCN to construct a 125 MW, 4-hour battery energy storage system facility at KU's E.W. Brown Generating Station and for approval of their proposed 2024-2030 DSM programs. The plan includes adding 14 new, adjusted or expanded energy efficiency programs, which would reduce LG&E's and KU's overall need by approximately 100 MW each. Finally, LG&E and KU requested a declaratory order to confirm that their entry into non-firm energy-only power-purchase agreements for the output of four solar photovoltaic facilities with a combined capacity of 637 MW does not require KPSC approval and that LG&E and KU may recover the costs of the solar PPAs through their fuel adjustment clause mechanisms as previously approved for a prior solar PPA. LG&E and KU plan to accrue AFUDC on the constructed NGCC facilities, the solar facility in Mercer County, Kentucky and the battery energy storage system facility and have requested regulatory asset treatment to recover the financing costs of these projects. The new NGCC facilities would be jointly owned by LG&E (31%) and KU (69%) and the solar units would be jointly owned by LG&E (37%) and KU (63%), the battery storage unit would be owned by LG&E, and the proposed PPA transactions and DSM programs would be entered into or conducted jointly by LG&E and KU, consistent with LG&E and KU's shared dispatch, cost allocation, tariff or other frameworks. The filing also notes planned retirement dates for certain existing coal-fired generation units, including Mill Creek 1 (300 MW) in 2024 and E.W. Brown 3 (412 MW) in 2028 , and updates and advances the planned retirement dates for Mill Creek 2 (297 MW) to 2027 and Ghent 2 (486 MW) to 2028 . LG&E and KU anticipate the recovery of associated retirement costs, including the remaining net book value, for these coal-fired generating units through the RAR or other rate mechanisms. The KPSC accepted the CPCN filing as of January 6, 2023. On March 24, 2023, Kentucky Senate Bill 4 (SB 4) went into effect, which requires KPSC approval of fossil fuel-fired electric generating unit retirements in the state. On May 10, 2023, LG&E and KU filed an application with the KPSC seeking approval of the retirement of seven fossil fuel-fired generating units as required by the recently enacted SB 4. On May 16, 2023, the KPSC entered an Order consolidating the SB 4 filing proceeding into the CPCN case. On August 29, 2023, a hearing with the KPSC and all parties concluded, and all post-hearing briefs have been filed. The KPSC has indicated its intention to issue an order on all issues by November 6, 2023. PPL, LG&E and KU cannot predict the outcome of these matters. Kentucky March 2023 Storm On March 3, 2023, 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 costs incurred through September 30, 2023 of $75 million ($33 million at LG&E and $42 million at KU). On March 17, 2023, 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 windstorm. On April 5, 2023, the KPSC issued an order approving the request for accounting purposes, noting that approval for recovery would be determined in LG&E’s and KU’s next base rate cases. As of September 30, 2023, LG&E and KU recorded regulatory assets related to the storm of $8 million and $11 million. 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 25, 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 has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric has submitted its responses to the information request and is cooperating fully with the investigation. PPL Electric cannot predict the outcome of this matter. 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 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 requested and received an extension of time to process refunds until December 2023. LG&E and KU filed a request for rehearing of the May 18, 2023 order, which was denied by operation of law on July 17, 2023. LG&E and KU filed petition for review of FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals on July 28, 2023. The FERC has indicated in its filings before the D.C. Circuit Court of Appeals that it intends to issue a substantive order on rehearing before November 13, 2023. The D.C. Circuit Court of Appeals will likely set the procedural schedule soon after FERC files the certified index to the record in mid-November 2023. LG&E and KU recorded regulatory liabilities of $3 million and $9 million related to potential refunds resulting from the FERC’s May 18, 2023 order. 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 provided primarily through base rates with increases associated with the FERC's May 18, 2023 order expected to be primarily subject to base rate recovery in 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'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 New England Transmission Owners 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. Those determinations in other jurisdictions have recently been vacated and remanded back to the FERC for further proceedings by the D.C. Circuit Court of Appeals. 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 and nine months ended September 30, 2023, PPL Electric purchased $391 million and $1 billion of accounts receivable from alternative suppliers. During the three and nine months ended September 30, 2022, PPL Electric purchased $352 million and $974 million of receivables. (PPL)
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 41	37
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	15
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	14
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	991	950
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	20	26
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,999	2,094
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	240	187
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	58	60
Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	9	27
Noncurrent regulatory liabilities	37	63
Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	14
Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	23	23
Noncurrent regulatory liabilities	39	32
Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	147	96
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	18	12
Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	18	0
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	83	85
Noncurrent regulatory liabilities	838	820
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	41	37
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	7	15
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	14
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	772	775
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	66	45
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	7
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	18	12
PPL Electric Utilities Corp [Member] | Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	23	7
Noncurrent regulatory liabilities	830	833
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] | 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	301	287
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	14	18
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	465	477
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	21	21
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	29	30
Louisville Gas And Electric Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	5	7
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
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	18	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	6
Noncurrent regulatory liabilities	1,022	1,029
Kentucky Utilities Co [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	400	389
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	6	8
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	528	546
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	57	56
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	29	30
Kentucky Utilities Co [Member] | Other Regulatory Liabilities [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	11	6
Noncurrent regulatory liabilities	2	0
Kentucky Utilities Co [Member] | Transmission Service Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
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

Utility Rate Regulation - Reg_3

Utility Rate Regulation - Regulatory Matters (Details) $ in Millions									1 Months Ended	3 Months Ended			9 Months Ended
	Sep. 27, 2023 USD ($)	Mar. 29, 2023 USD ($)	Mar. 21, 2023 USD ($)	Feb. 03, 2023 USD ($)	Jan. 27, 2023 USD ($)	Dec. 15, 2022 MW	Oct. 16, 2018	Aug. 24, 2018	Nov. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) MW	Sep. 30, 2022 USD ($)	Sep. 30, 2015	Sep. 30, 2023 USD ($) MW	Sep. 30, 2022 USD ($)
March 2023 Kentucky Wind Storms
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved | $										$ 75			$ 75
PPL Electric [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amortization of Revenue Reserve for ROE Challenge | $													74
PPL Electric [Member] | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase | $										$ 391	$ 352		$ 1,000	$ 974
LGE [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power						621
CPCN Solar Photovoltaic Facility to be constructed, Power						120
CPCN Solar Photovoltaic Facility to be acquired, Power						120
CPCN 4-Hour Energy Storage Facility to be Constructed, Power						125
CPCN New and Adjusted Energy Efficiency Programs, Overall Power Need Reduction						100
Total Capacity of Power Purchase Agreements Not Subject to KPSC Approval, Power						637
New NGCC LG&E Planned Ownership Percentage													31%
New Solar Units LG&E Planned Ownership Percentage													37%
Mill Creek 1 Unit, Generation Capacity, Power										300			300
E. W. Brown 3 Unit, Generation Capacity, Power										412			412
Mill Creek 2 Unit, Generation Capacity, Power										297			297
Ghent 2 Unit, Generation Capacity, Power										486			486
LGE [Member] | March 2023 Kentucky Wind Storms
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved | $										$ 33			$ 33
LGE [Member] | Federal Energy Regulatory Commsion [Member] | Other Regulatory Assets [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Increase (Decrease) in Regulatory Liabilities | $										$ 3
KU [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power						621
CPCN Solar Photovoltaic Facility to be constructed, Power						120
CPCN Solar Photovoltaic Facility to be acquired, Power						120
CPCN 4-Hour Energy Storage Facility to be Constructed, Power						125
CPCN New and Adjusted Energy Efficiency Programs, Overall Power Need Reduction						100
Total Capacity of Power Purchase Agreements Not Subject to KPSC Approval, Power						637
New NGCC KU Planned Ownership Percentage													69%
New Solar units LG&E Planned Ownership Percentage													63%
Mill Creek 1 Unit, Generation Capacity, Power										300			300
E. W. Brown 3 Unit, Generation Capacity, Power										412			412
Mill Creek 2 Unit, Generation Capacity, Power										297			297
Ghent 2 Unit, Generation Capacity, Power										486			486
KU [Member] | March 2023 Kentucky Wind Storms
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved | $										$ 42			$ 42
KU [Member] | Federal Energy Regulatory Commsion [Member] | Other Regulatory Assets [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Increase (Decrease) in Regulatory Liabilities | $										9
Rhode Island Energy | Rhode Island Public Uitilty Commsion
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Public Utilities, Approved Return on Equity, Percentage								9.275%
Supplemental Capital Investment to spend on the FY 2024 Gas ISR Plan | $					$ 187
Supplemental Capital Investment Spend amount agreed to between RIE and RIPUC | $				$ 171
Supplemental Capital Investment to spend on the FY 2024 Electric ISR Plan | $					176
2nd Supplemental Capita Investment to spend on the FY 2024 Electrical ISR Plan | $			$ 166
RIPUC Approved FY 2024 Gas ISR Plan for capital investment spend | $		$ 163
RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend | $		112
Estimated net present value costs of AMF program | $									$ 188
Benefit - cost ratio yield of the AMF program									3.9
NPV to be obtained through AMF program over 20 years | $									$ 729
AMF Program Project Life, Years									20 years
Recovery Cap on Capital Investment Related to AMF Program | $	$ 153
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Vegetation management
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Supplemental Capital Investment to spend on the FY 2024 Electric ISR Plan | $					14
2nd Supplemental Capita Investment to spend on the FY 2024 Electrical ISR Plan | $			14
RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend | $		14
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Other O&M
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Supplemental Capital Investment to spend on the FY 2024 Electric ISR Plan | $					$ 3
2nd Supplemental Capita Investment to spend on the FY 2024 Electrical ISR Plan | $			$ 1
RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend | $		$ 1
Rhode Island Energy | Rhode Island Public Uitilty Commsion | Common equity percentage related to approved rate
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Percentage of common equity used on allowed ROE								51%
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%
PPL Electric Utilities Corp [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amortization of Revenue Reserve for ROE Challenge | $													$ 74
PPL Electric Utilities Corp [Member] | Unaffiliated Third Party Entity [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Accounts Receivable, Purchase | $										$ 391	$ 352		$ 1,000	$ 974
Louisville Gas And Electric Co [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power						621
CPCN Solar Photovoltaic Facility to be constructed, Power						120
CPCN Solar Photovoltaic Facility to be acquired, Power						120
CPCN 4-Hour Energy Storage Facility to be Constructed, Power						125
CPCN New and Adjusted Energy Efficiency Programs, Overall Power Need Reduction						100
Total Capacity of Power Purchase Agreements Not Subject to KPSC Approval, Power						637
New NGCC LG&E Planned Ownership Percentage													31%
New Solar Units LG&E Planned Ownership Percentage													37%
Mill Creek 1 Unit, Generation Capacity, Power										300			300
E. W. Brown 3 Unit, Generation Capacity, Power										412			412
Mill Creek 2 Unit, Generation Capacity, Power										297			297
Ghent 2 Unit, Generation Capacity, Power										486			486
Louisville Gas And Electric Co [Member] | March 2023 Kentucky Wind Storms
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved | $										$ 33			$ 33
Louisville Gas And Electric Co [Member] | Federal Energy Regulatory Commsion [Member] | Other Regulatory Assets [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Increase (Decrease) in Regulatory Liabilities | $										$ 3
Kentucky Utilities Co [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
CPCN NGCC Combustion Turbine Facilities Power						621
CPCN Solar Photovoltaic Facility to be constructed, Power						120
CPCN Solar Photovoltaic Facility to be acquired, Power						120
CPCN 4-Hour Energy Storage Facility to be Constructed, Power						125
CPCN New and Adjusted Energy Efficiency Programs, Overall Power Need Reduction						100
Total Capacity of Power Purchase Agreements Not Subject to KPSC Approval, Power						637
New NGCC KU Planned Ownership Percentage													69%
New Solar units LG&E Planned Ownership Percentage													63%
Mill Creek 1 Unit, Generation Capacity, Power										300			300
E. W. Brown 3 Unit, Generation Capacity, Power										412			412
Mill Creek 2 Unit, Generation Capacity, Power										297			297
Ghent 2 Unit, Generation Capacity, Power										486			486
Kentucky Utilities Co [Member] | March 2023 Kentucky Wind Storms
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Amount of Regulatory Costs Not yet Approved | $										$ 42			$ 42
Kentucky Utilities Co [Member] | Federal Energy Regulatory Commsion [Member] | Other Regulatory Assets [Member]
Regulatory Matters - Rate Case Proceedings (Numeric) [Abstract]
Increase (Decrease) in Regulatory Liabilities | $										$ 9

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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 391	$ 352	$ 1,000	$ 974
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 391	$ 352	$ 1,000	$ 974

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	$ 287	$ 987
PPL Capital Funding [Member]
Line of Credit Facility [Line Items]
Capacity	1,450
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	88	619
Unused Capacity	1,362
PPL Capital Funding [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	561
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)	75	561
Unused Capacity	1,175
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
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)	13	58
Unused Capacity	87
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	250
Letters of Credit and Commercial Paper Issued (c)	188	146
Unused Capacity	462
PPL Electric [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	187	145
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)	188	146
Unused Capacity	462
PPL Electric [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Capacity	0
Borrowed	0	250
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	0
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	0	180
Unused Capacity	500
LGE [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	180
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	180
Unused Capacity	500
LGE [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Capacity	0
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	0
KU [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	25	101
Unused Capacity	375
KU [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	25	101
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)	25	101
Unused Capacity	375
KU [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Capacity	0
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	0
Rhode Island Energy | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	75	0
Rhode Island Energy | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Borrowing Capacity Sublimit	250
Rhode Island Energy | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	75
PPL Electric Utilities Corp [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	250
Letters of Credit and Commercial Paper Issued (c)	188	146
Unused Capacity	462
PPL Electric Utilities Corp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	187	145
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)	188	146
Unused Capacity	462
PPL Electric Utilities Corp [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Capacity	0
Borrowed	0	250
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	0
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	0	180
Unused Capacity	500
Louisville Gas And Electric Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	180
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	180
Unused Capacity	500
Louisville Gas And Electric Co [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Capacity	0
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	0	0
Unused Capacity	0
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	25	101
Unused Capacity	375
Kentucky Utilities Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	25	101
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)	25	101
Unused Capacity	375
Kentucky Utilities Co [Member] | Term Loan Facility [Member]
Line of Credit Facility [Line Items]
Capacity	0
Borrowed	0	300
Letters of Credit and Commercial Paper Issued (c)	0	$ 0
Unused Capacity	$ 0

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Sep. 30, 2023	Jun. 30, 2023	Dec. 31, 2022
Short-term Debt [Line Items]
Capacity	$ 3,300
Commercial Paper Issuances (c)	287		$ 987
Unused Capacity	3,013
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate			4.84%
Capacity	1,350
Commercial Paper Issuances (c)	0		$ 561
Unused Capacity	$ 1,350
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.47%		4.74%
Capacity	$ 650
Commercial Paper Issuances (c)	187		$ 145
Unused Capacity	463
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate			4.94%
Capacity	500
Commercial Paper Issuances (c)	0		$ 180
Unused Capacity	$ 500
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.45%		4.90%
Capacity	$ 400
Commercial Paper Issuances (c)	25		$ 101
Unused Capacity	$ 375
Rhode Island Energy
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%
Capacity	$ 400	$ 400
Commercial Paper Issuances (c)	75		$ 0
Unused Capacity	$ 325
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.47%		4.74%
Capacity	$ 650
Commercial Paper Issuances (c)	187		$ 145
Unused Capacity	463
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate			4.94%
Capacity	500
Commercial Paper Issuances (c)	0		$ 180
Unused Capacity	$ 500
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.45%		4.90%
Capacity	$ 400
Commercial Paper Issuances (c)	25		$ 101
Unused Capacity	$ 375

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended
	Mar. 31, 2023	Feb. 28, 2023	Sep. 30, 2023	Dec. 31, 2022
Long-term Debt (Numeric) [Abstract]
Long-term debt due within one year			$ 91	$ 354
Long-term Debt, Excluding Current Maturities			14,484	12,889
Exchangeable Senior Unsecured Notes | Exchangeable Senior Notes Due 2028
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 1,000
Stated interest rate		2.875%
Exchangeable Senior Notes Initial Exchange Rate, Shares per $1000 Principal Amount		29.3432
Exchangeable Senior Notes Initial Exchange Rate, Dollars per Share		$ 34.08
Proceeds from Convertible Debt		$ 980
PPL Electric [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			650
Borrowed			0	250
PPL Electric [Member] | Term Loan Facility [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			0
Borrowed			0	250
PPL Electric [Member] | Term Loan Facility [Member] | Repayment
Long-term Debt (Numeric) [Abstract]
Capacity	$ 250
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds, Floating Rate Series due 2023 [Member] | Bond Redemption [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	250
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds, Floating Rate Series due 2024 | Bond Redemption [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	650
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 600
Stated interest rate	5%
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2053
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 750
Stated interest rate	5.25%
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033 and 2053
Long-term Debt (Numeric) [Abstract]
Proceeds from Issuance of First Mortgage Bond	$ 1,320
PPL Capital Funding [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			1,450
Borrowed			0	0
LGE [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			500
Borrowed			0	300
LGE [Member] | Term Loan Facility [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			0
Borrowed			0	300
LGE [Member] | Term Loan Facility [Member] | Repayment
Long-term Debt (Numeric) [Abstract]
Capacity	300
LGE [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 400
Stated interest rate	5.45%
Proceeds from Issuance of First Mortgage Bond	$ 396
KU [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			400
Borrowed			0	300
KU [Member] | Term Loan Facility [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			0
Borrowed			0	300
KU [Member] | Term Loan Facility [Member] | Repayment
Long-term Debt (Numeric) [Abstract]
Capacity	300
KU [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 400
Stated interest rate	5.45%
Proceeds from Issuance of First Mortgage Bond	$ 396
PPL Electric Utilities Corp [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			650
Borrowed			0	250
Long-term debt due within one year			90	340
Long-term Debt, Excluding Current Maturities			4,566	4,146
PPL Electric Utilities Corp [Member] | Term Loan Facility [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			0
Borrowed			0	250
PPL Electric Utilities Corp [Member] | Term Loan Facility [Member] | Repayment
Long-term Debt (Numeric) [Abstract]
Capacity	250
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds, Floating Rate Series due 2023 [Member] | Bond Redemption [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	250
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds, Floating Rate Series due 2024 | Bond Redemption [Member]
Long-term Debt (Numeric) [Abstract]
Principal amount	650
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 600
Stated interest rate	5%
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2053
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 750
Stated interest rate	5.25%
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033 and 2053
Long-term Debt (Numeric) [Abstract]
Proceeds from Issuance of First Mortgage Bond	$ 1,320
Louisville Gas And Electric Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			500
Borrowed			0	300
Long-term Debt, Excluding Current Maturities			2,404	2,307
Louisville Gas And Electric Co [Member] | Term Loan Facility [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			0
Borrowed			0	300
Louisville Gas And Electric Co [Member] | Term Loan Facility [Member] | Repayment
Long-term Debt (Numeric) [Abstract]
Capacity	300
Louisville Gas And Electric Co [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 400
Stated interest rate	5.45%
Proceeds from Issuance of First Mortgage Bond	$ 396
Kentucky Utilities Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			400
Borrowed			0	300
Long-term debt due within one year			0	13
Long-term Debt, Excluding Current Maturities			3,004	2,907
Kentucky Utilities Co [Member] | Term Loan Facility [Member]
Long-term Debt (Numeric) [Abstract]
Capacity			0
Borrowed			$ 0	$ 300
Kentucky Utilities Co [Member] | Term Loan Facility [Member] | Repayment
Long-term Debt (Numeric) [Abstract]
Capacity	300
Kentucky Utilities Co [Member] | First Mortgage Bond [Member] | First Mortgage Bonds Due 2033
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 400
Stated interest rate	5.45%
Proceeds from Issuance of First Mortgage Bond	$ 396

Financing Activities - Equity S

Financing Activities - Equity Securities (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended		3 Months Ended
	Jun. 30, 2023	Jun. 30, 2022	Sep. 30, 2023	Jun. 01, 2023
Securities Financing Transaction [Line Items]
Annualized current quarterly common stock dividend (in dollars per share)		$ 96
Preferred Stock, Par or Stated Value Per Share				$ 50
Payments for Repurchase of Redeemable Noncontrolling Interest	$ 3
Preferred Stock, Shares Outstanding				49,089
Preferred Stock Redeemed, Prorated Dividend, Per Share	$ 0.1875
Preferred Stock Redemption, Premium, Per Share	$ 5
Treasury Stock, Common
Securities Financing Transaction [Line Items]
Treasury stock acquired			38,000

Financing Activities - Distribu

Financing Activities - Distributions (Details) - $ / shares	1 Months Ended	3 Months Ended		9 Months Ended
	Jun. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Distributions (Numeric) [Abstract]
Current quarterly common stock dividend (in dollars per share)	$ 0.240	$ 0.240	$ 0.225	$ 0.720	$ 0.650
Annualized current quarterly common stock dividend (in dollars per share)	$ 96

Acquisitions, Development and_2

Acquisitions, Development and Divestitures - Discontinued Operations (Details) - Disposal Group, Held-for-Sale, Not Discontinued Operations [Member] - Safari Holdings LLC, Consolidated - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Discontinued Operation, Income (Loss) from Discontinued Operation Disclosures [Abstract]
Loss on Sale	$ 67	$ 6	$ 67
gain (loss) on disposition of business, net of tax	50	5	50
Disposal Group, Including Discontinued Operation, Income Statement Disclosures [Abstract]
Gain (Loss) on Sale	67	6	67
Disposal Group, Including Discontinued Operation, Balance Sheet Disclosures [Abstract]
Gain (Loss) on Sale	$ 67	$ 6	$ 67

Acquisitions, Development and_3

Acquisitions, Development and Divestitures - Development (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Jun. 30, 2023	Jun. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Business Acquisition [Line Items]
Goodwill, Acquired During Period						$ 1,585
Transition Service Agreement Cost	$ 59				$ 179
Goodwill	2,247				2,247		$ 2,248
Operating Revenues from external customers	2,043	$ 2,134			6,281	5,612
Net income (loss)	230	174			627	566
Indemnification for Safari sale/leaseback					25
Narragansett Electric
Business Acquisition [Line Items]
Total cash consideration				$ 3,800
Disposal Group, Held-for-Sale, Not Discontinued Operations [Member] | Safari Holdings LLC, Consolidated
Business Acquisition [Line Items]
Gain (Loss) on Disposition of Business		(67)			(6)	(67)
gain (loss) on disposition of business, net of tax		(50)			(5)	(50)
Rhode Island Regulated
Business Acquisition [Line Items]
Goodwill			$ 725
Operating Revenues from external customers	413	384			1,355	512
Net income (loss)	6	(26)			70	(55)
Corporate and Other [Member]
Business Acquisition [Line Items]
Goodwill, Acquired During Period			860
Goodwill, Purchase Accounting Adjustments			$ 1
Operating Revenues from external customers	0	7			0	19
Net income (loss)	(87)	$ (107)			(259)	$ (254)
Rhode Island Energy | Rhode Island Energy TSA
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense	69				193
Rhode Island Energy | Accrual for TSA Markup
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense	$ 2				$ 6

Defined Benefits (Details)

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			$ 14	$ 8
Pension Plan [Member] | U.S.
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	$ 8	$ 11	25	36
Interest cost	47	33	141	95
Expected return on plan assets	(77)	(62)	(232)	(189)
Amortization of: [Abstract]
Prior service cost	2	2	5	6
Actuarial loss	1	11	2	40
Net Periodic Defined Benefit Costs (Credits) Prior To Settlements	(19)	(5)	(59)	(12)
Settlements	0	7	0	19
Net periodic defined benefit costs (credits)	(19)	2	(59)	7
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	1	1	4	4
Interest cost	8	3	23	11
Expected return on plan assets	(7)	(5)	(22)	(17)
Amortization of: [Abstract]
Prior service cost	0	0	1	1
Actuarial loss	(1)	0	(4)	(2)
Net periodic defined benefit costs (credits)	$ 1	$ (1)	2	(3)
PPL Electric Utilities Corp [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			5	0
Louisville Gas And Electric Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding			1	2
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
	Nov. 18, 2014	Sep. 30, 2023	Dec. 31, 2022	Jun. 01, 2015
Claim By Former Affiliate [Abstract]
Percent of ownership of Talen Energy by Riverstone				35%
Period Over Which Distribution Adjustment Charge-related Costs Are amortized		10 years
Proceeds from Divestiture of Businesses and Interests in Affiliates	$ 900
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		100	$ 100
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross		11	11
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross		$ 11	$ 11

Commitments and Contingencies_2

Commitments and Contingencies - Environmental Matters and Other (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($) employee	Sep. 30, 2022 USD ($)	Dec. 31, 2022 USD ($)
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (13)	$ (7)	$ (33)	$ (47)
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	$ 100		$ 100		$ 100
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	11		$ 11		11
LGE [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term			3 years
Concentration Risk Number Of Union Employees | employee			600
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(4)	(4)	$ (8)	(9)
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	11		$ 11		$ 11
Louisville Gas And Electric Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Collective Bargaining Agreement Term			3 years
Concentration Risk Number Of Union Employees | employee			600
Amortization of excess deferred income taxes	(3)	(3)	$ (9)	(17)
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (5)	$ (4)	$ (13)	$ (16)

Commitments and Contingencies_3

Commitments and Contingencies - Guarantees and Other Assurances (Details) - 9 months ended Sep. 30, 2023 £ in Millions, $ in Millions	USD ($) employee	GBP (£)	USD ($)
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage			$ 225
Indemnification Cap, Surrenders of Tax Losses | £		£ 50
Indemnification for Safari sale/leaseback	$ 25
LGE [Member]
Other Guarantee (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Concentration Risk Number Of Union Employees | employee	600
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | LGE [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			61
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | KU [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			27
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			129
PPL Guarantee [Member] | Indemnification Guarantee [Member] | Guarantee of payment obligations under certain power purchase agreements related to the sale of Safari Holdings
Other Guarantee (Numeric) [Abstract]
Maximum exposure			33
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			88
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]
Other Guarantee (Numeric) [Abstract]
Collective Bargaining Agreement Term	3 years
Concentration Risk Number Of Union Employees | employee	600
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			61
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			$ 27
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable

Commitments and Contingencies_4

Commitments and Contingencies - Energy Purchase Commitments (Details - MW	Mar. 17, 2023	Jul. 01, 2022
Legal Matters [Line Items]
ACES Offshore wind proposal	884
Minimum [Member]
Legal Matters [Line Items]
ACES Renewable Energy Contracting Capacity Requirement		600
Maximum [Member]
Legal Matters [Line Items]
ACES Renewable Energy Contracting Capacity Requirement		1,000

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable from affiliates	$ 0		$ 0		$ 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	$ 52	$ 51	$ 166	$ 172
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	500		500
PPL Electric Utilities Corp [Member] | Accounts receivable from affiliates [Member] | PPL Services [Member]
Intercompany Borrowings (Numeric) [Abstract]
VEBA Funds Receivable	0		0
Louisville Gas And Electric Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 6		$ 6		$ 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	$ 10	0	$ 30	0
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	744		744
Louisville Gas And Electric Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	25	34	85	114
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 21		$ 21		$ 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	$ 11	0	$ 33	0
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	604		604
Kentucky Utilities Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 35	$ 39	$ 110	$ 125

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Other Income
Defined benefit plans - non-service credits	$ 13	$ 7	$ 30	$ 27
AFUDC - equity component	7	8	21	17
Miscellaneous	(7)	(4)	(19)	(4)
Other Expense
Charitable Contributions	(1)	(1)	(3)	(2)
Other Income (Expense) - net	16	10	51	36
Interest Income (Expense), Nonoperating, Net	4	0	22	(2)
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	5	4	15	12
AFUDC - equity component	4	4	12	12
Miscellaneous	(2)	(3)	(2)	(4)
Other Expense
Charitable Contributions	0	0	(2)	(2)
Other Income (Expense) - net	8	6	29	19
Interest Income (Expense), Nonoperating, Net	$ 1	$ 1	$ 6	$ 1

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, 2023	Dec. 31, 2022
Assets
Cash and cash equivalents	$ 353	$ 356
Restricted cash and cash equivalents	1	1
Total Cash, Cash Equivalents and Restricted Cash	354	357
Special Use Funds [Abstract]
Money market fund	1	1
Commingled debt fund measured at NAV	10	13
Commingled equity fund measured at NAV	9	11
Total special use funds	20	25
Gas Contracts	0	25
Price risk management assets:
Total Assets	374	407
Price risk management liabilities:
Interest rate swaps	3	7
Gas Contracts	34	66
Total price risk management liabilities	37	73
Level 1 [Member]
Assets
Cash and cash equivalents	353	356
Restricted cash and cash equivalents	1	1
Total Cash, Cash Equivalents and Restricted Cash	354	357
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	355	358
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	0	25
Price risk management assets:
Total Assets	0	25
Price risk management liabilities:
Interest rate swaps	3	7
Gas Contracts	23	10
Total price risk management liabilities	26	17
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	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	11	56
Gas Contracts, Liability, Purchases	11
Gas Contracts, Liability, Settlements	(56)
Total price risk management liabilities	11	56
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	56	25
Price risk management assets:
Total Assets	56	25
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	56	25
Price risk management assets:
Total Assets	56	25
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	8	93
Price risk management assets:
Total Assets	8	93
Price risk management liabilities:
Interest rate swaps	3	7
Total price risk management liabilities	3	7
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	8	93
Price risk management assets:
Total Assets	8	93
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
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	3	7
Total price risk management liabilities	3	7
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	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	8	21
Price risk management assets:
Total Assets	8	21
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	8	21
Price risk management assets:
Total Assets	8	21
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	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, 2023	Dec. 31, 2022
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 14,575	$ 13,243
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	13,027	12,239
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	4,656	4,486
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	4,185	4,259
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	2,404	2,307
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	2,150	2,128
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	3,004	2,920
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 2,594	$ 2,616

Derivative Instruments and He_4

Derivative Instruments and Hedging Activities - Intro (Details) - USD ($) $ in Millions	Sep. 30, 2023	Dec. 31, 2022
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, 2023 USD ($) Bcf	Sep. 30, 2022 USD ($)	Sep. 30, 2023 USD ($)	Sep. 30, 2022 USD ($)	Dec. 31, 2022 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	0		0		25
Liability value	37		37		73
Interest Rate Swaps [Member] | Price risk management assets, current [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 [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	0		0		1
Interest Rate Swaps [Member] | Price risk management assets, noncurrent [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0		0
Interest Rate Swaps [Member] | Other deferred credits and noncurrent liabilities [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	3		3		6
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	54
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
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, 2023	Dec. 31, 2022
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 0	$ 25
Liability value	37	73
Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	20
Other current liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	1
Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	5
Price risk management assets, noncurrent [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Other deferred credits and noncurrent liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	3	6
Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	29	63
Price risk management assets, current [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	8	10
Louisville Gas And Electric Co [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value		7
Louisville Gas And Electric Co [Member] | Current Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Current Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Noncurrent Assets [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Louisville Gas And Electric Co [Member] | Current Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	1
Louisville Gas And Electric Co [Member] | Current Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	0	1
Louisville Gas And Electric Co [Member] | Noncurrent Liabilities [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	3	6
Louisville Gas And Electric Co [Member] | Noncurrent Liabilities [Member] | Interest Rate Swaps [Member]
Fair Values by Balance Sheet Location [Abstract]
Liability value	$ 3	$ 6

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022	Dec. 31, 2022
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	$ 165	$ 136	$ 494	$ 361
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	16	10	51	36
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)	0	(3)	(2)
Amount of gain (loss) reclassified from AOCI to income	(1)	0	(3)	(2)
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Income (Loss) from Discontinued Operations (net of income taxes)
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income		0		0
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Other Income (Expense) -net
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Amount of gain (loss) reclassified from AOCI to income	0		0
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(5)	17	(12)	27
Gain (loss) recognized as regulatory liabilities/assets	(8)		11
Asset value	0		0		$ 25
Liability value	37		37		73
Not Designated As Hedging Instruments [Member] | Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		5
Not Designated As Hedging Instruments [Member] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	29		29		63
Not Designated As Hedging Instruments [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		20
Not Designated As Hedging Instruments [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	8		8		10
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		$ 1
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]		Interest Expense		Interest Expense
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	4	$ 3	4	$ 11
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		$ 17		$ 26
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]		Energy purchases		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	2		(5)
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	(14)		12
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 | Energy Purchases
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(4)		(11)
Louisville Gas And Electric Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	25	$ 23	76	$ 64
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	0	0	2	3
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
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | 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] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0		0		1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Current 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] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	3		3		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	$ 1
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] | 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] | Current Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	0		0		1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Current Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Noncurrent Liabilities [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	3		3		$ 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	4	$ 3	4	$ 11
Kentucky Utilities Co [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	$ 1	$ 2	$ 6	$ 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, 2023	Dec. 31, 2022
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	22
Derivative, Net Liability Position, Aggregate Fair Value	21
Treasury Derivatives [Member]
Assets [Abstract]
Gross	0	25
Derivative instruments - eligible for offset	0	20
Cash collateral received - eligible for offset	0	0
Net	0	5
Liabilities [Abstract]
Gross	37	73
Derivative instruments - eligible for offset	0	62
Cash collateral pledged - eligible for offset	0	0
Net	37	11
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	3	7
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 3	$ 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, 2023	Dec. 31, 2022
Commodity Purchases [Line Items]
Liability value	$ 37	$ 73
Asset value	0	25
Current Assets [Member]
Commodity Purchases [Line Items]
Asset value	0	20
Current Assets [Member] | Gas Contract
Commodity Purchases [Line Items]
Asset value	0	20
Current Liabilities [Member]
Commodity Purchases [Line Items]
Liability value	29	63
Current Liabilities [Member] | Gas Contract
Commodity Purchases [Line Items]
Liability value	29	62
Noncurrent Assets [Member]
Commodity Purchases [Line Items]
Asset value	0	5
Noncurrent Assets [Member] | Gas Contract
Commodity Purchases [Line Items]
Asset value	0	5
Noncurrent Liabilities [Member]
Commodity Purchases [Line Items]
Liability value	8	10
Noncurrent Liabilities [Member] | Gas Contract
Commodity Purchases [Line Items]
Liability value	$ 5	$ 4

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Millions	9 Months Ended
	Sep. 30, 2023 USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 177
Accretion	6
New Obligation s Incurred	2
Changes in estimated timing or cost	14
Obligations settled	(26)
Asset Retirement Obligations, Period Change, Miscellaneous	(5)
Balance at End of Period	168
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	86
Accretion	3
New Obligation s Incurred	1
Changes in estimated timing or cost	11
Obligations settled	(9)
Asset Retirement Obligations, Period Change, Miscellaneous	(6)
Balance at End of Period	86
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	82
Accretion	3
New Obligation s Incurred	1
Changes in estimated timing or cost	5
Obligations settled	(17)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	$ 74

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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (137)	$ (124)	$ (124)	$ (157)
Amounts arising during the period	(6)	(10)	(20)	12
Reclassifications from AOCI	1	4	2	15
Net OCI during the period	(5)	(6)	(18)	27
Balance at end of period	(142)	(130)	(142)	(130)
Unrealized gains (losses) on qualifying derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	4	2	3	1
Amounts arising during the period	0	0	0	0
Reclassifications from AOCI	1	0	2	1
Net OCI during the period	1	0	2	1
Balance at end of period	5	2	5	2
Defined benefit plans Prior service costs [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(4)	(6)	(5)	(6)
Amounts arising during the period	0	0	0	(1)
Reclassifications from AOCI	0	1	1	2
Net OCI during the period	0	1	1	1
Balance at end of period	(4)	(5)	(4)	(5)
Defined benefit plans Actuarial gain (loss) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(140)	(122)	(124)	(152)
Amounts arising during the period	(6)	(10)	(21)	11
Reclassifications from AOCI	0	3	(1)	12
Net OCI during the period	(6)	(7)	(22)	23
Balance at end of period	(146)	(129)	(146)	(129)
Equity Investees' OCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	3	2	2	0
Amounts arising during the period	0	0	1	2
Reclassifications from AOCI	0	0	0	0
Net OCI during the period	0	0	1	2
Balance at end of period	$ 3	$ 2	$ 3	$ 2

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, 2023	Sep. 30, 2022	Sep. 30, 2023	Sep. 30, 2022
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (165)	$ (136)	$ (494)	$ (361)
Other Income (Expense) - net	16	10	51	36
Income Tax Expense (Benefit)	(58)	(41)	(170)	(147)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(1)	(4)	(2)	(15)
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)	(7)	0	(20)
Income Tax Expense (Benefit)	1	3	0	6
Total After-tax	0	(4)	0	(14)
Defined Benefit Plans [Member] | Prior Service Costs [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	0	(2)	(1)	(3)
Defined Benefit Plans [Member] | Net Actuarial Loss [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	(1)	(5)	1	(17)
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)	0	(3)	(2)
Income Tax Expense (Benefit)	0	0	1	1
Total After-tax	(1)	0	(2)	(1)
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)	$ 0	$ (3)	$ (2)