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

Document and Entity Information

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2024	Apr. 26, 2024
Document Entity Information [Line Items]
Entity Shell Company	false
Entity Interactive Data Current	Yes
Entity File Number	1-11459
Entity Incorporation, State or Country Code	PA
Entity Address, Address Line One	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	Mar. 31, 2024
Amendment Flag	false
Entity Registrant Name	PPL Corporation
Entity Tax Identification Number	23-2758192
Entity Central Index Key	0000922224
Current Fiscal Year End Date	--12-31
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Common Stock, Shares Outstanding		737,740,859
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
		Mar. 31, 2024		Mar. 31, 2023
Operating Revenues
Operating Revenues		$ 2,304		$ 2,415
Operation
Fuel		209		201
Energy purchases		520		734
Other operation and maintenance		626		559
Depreciation		316		313
Taxes, other than income		88		110
Total Operating Expenses		1,759		1,917
Operating Income		545		498
Other Income (Expense) - net		22		30
Interest Expense		179		164
Income Taxes		81		79
Net Income (Loss)		$ 307		$ 285
Net Income:
Diluted (in dollars per share)		$ 0.42		$ 0.39
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Basic (in shares)		737,512		736,829
Diluted (in shares)		738,820		737,698
Income from Continuing Operations Before Income Taxes		$ 388		$ 364
Income (Loss) from Continuing Operations After Income Taxes, Basic		$ 0.42		$ 0.39
Income (Loss) from Continuing Operations after income taxes, Diluted		$ 0.42		$ 0.39
Rhode Island Regulated
Operating Revenues
Operating Revenues		$ 549		$ 565
Operation
Net Income (Loss)		64		54
PPL Electric Utilities Corp [Member]
Operating Revenues
Operating Revenues		770		891
Operation
Energy purchases		214		358
Other operation and maintenance		181		162
Depreciation		99		99
Taxes, other than income		36		44
Total Operating Expenses		530		663
Operating Income		240		228
Other Income (Expense) - net		9		12
Interest Expense		62		57
Income Taxes		48		45
Net Income (Loss)	[1]	149		138
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		197		183
PPL Electric Utilities Corp [Member] | Related Party
Operation
Interest Income from affiliate		10		0
Louisville Gas And Electric Co [Member]
Operating Revenues
Operating Revenues		476		474
Operation
Fuel		86		79
Energy purchases		71		84
Energy purchases from affiliate		1		1
Other operation and maintenance		88		91
Depreciation		76		75
Taxes, other than income		13		12
Total Operating Expenses		335		342
Operating Income		141		132
Other Income (Expense) - net		2		2
Interest Expense		26		25
Income Taxes		24		23
Net Income (Loss)		93	[2]	86
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		117		109
Louisville Gas And Electric Co [Member] | Related Party
Operating Revenues
Retail and wholesale		16		13
Louisville Gas And Electric Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		460		461
Kentucky Utilities Co [Member]
Operating Revenues
Operating Revenues		525		499
Operation
Fuel		123		122
Energy purchases		6		6
Energy purchases from affiliate		16		13
Other operation and maintenance		102		109
Depreciation		99		98
Taxes, other than income		12		10
Total Operating Expenses		358		358
Operating Income		167		141
Other Income (Expense) - net		2		2
Interest Expense		34		33
Income Taxes		27		22
Net Income (Loss)	[3]	108		88
Weighted-Average Shares of Common Stock Outstanding (in thousands)
Income from Continuing Operations Before Income Taxes		135		110
Kentucky Utilities Co [Member] | Related Party
Operating Revenues
Retail and wholesale		1		1
Kentucky Utilities Co [Member] | Nonrelated Party
Operating Revenues
Retail and wholesale		$ 524		$ 498
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONDENSED CONSOLIDATED STATEM_2

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Net income (loss)	$ 307	$ 285
Amounts arising during the period - gains (losses), net of tax (expense) benefit:
Equity investees' other comprehensive income (loss), net of tax	1	1
Reclassifications from AOCI - (gains) losses, net of tax expense (benefit):
Qualifying derivatives, net of tax	1	1
Other Comprehensive (Income) Loss, Defined Benefit Plans, after Reclassification Adjustment, after Tax [Abstract]
Defined benefit plans, Net actuarial (gain) loss, net of tax	0	(1)
Total other comprehensive income (loss)	2	1
Comprehensive income (loss)	$ 309	$ 286

CONDENSED CONSOLIDATED STATEM_3

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Unaudited) (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Tax effect of qualifying derivatives reclassified from AOCI	$ 0	$ 0
Tax effect of net actuarial (gain) loss reclassified from AOCI	0	0
Tax effect of equity investee's other comprehensive income (loss)	$ 0	$ 0

CONDENSED CONSOLIDATED STATEM_4

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Millions		3 Months Ended
		Mar. 31, 2024		Mar. 31, 2023
Cash Flows from Operating Activities
Net income (loss)		$ 307		$ 285
Depreciation		316		313
Amortization		24		17
Defined benefit plans - (income) expense		(15)		(18)
Deferred income taxes and investment tax credits		72		77
Other		3		8
Change in current assets and current liabilities
Accounts receivable		(75)		(94)
Accounts payable		(221)		(63)
Unbilled revenues		57		109
Fuel, materials and supplies		33		10
Prepayments		(108)		(83)
Taxes payable		(47)		(42)
Regulatory assets and liabilities, net		(61)		(46)
Accrued interest		90		67
Other		(103)		(14)
Other operating activities
Defined benefit plans - funding		(5)		(3)
Other assets		(1)		(61)
Other liabilities		16		(32)
Net cash provided by operating activities		282		430
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(596)		(499)
Other investing activities		5		(4)
Net cash used in investing activities		(591)		(503)
Cash Flows from Financing Activities
Issuance of long-term debt		1,148		3,127
Retirement of long-term debt		0		(1,750)
Payment of common stock dividends		(177)		(171)
Net increase (decrease) in short-term debt		(701)		(985)
Other financing activities		(22)		(44)
Net cash provided by financing activities		248		177
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(61)		104
Cash and Cash Equivalents at Beginning of Period		331
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		382		357
Cash and Cash Equivalents at End of Period		276
Cash, Cash Equivalents and Restricted Cash at End of Period		321		461
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		253		257
PPL Electric Utilities Corp [Member]
Cash Flows from Operating Activities
Net income (loss)	[1]	149		138
Depreciation		99		99
Amortization		12		9
Defined benefit plans - (income) expense		(11)		(10)
Deferred income taxes and investment tax credits		32		26
Other		(7)		(5)
Change in current assets and current liabilities
Accounts receivable		(33)		(115)
Accounts payable		(59)		30
Unbilled revenues		30		20
Fuel, materials and supplies		(4)		(17)
Prepayments		(110)		(77)
Taxes payable		(48)		(36)
Regulatory assets and liabilities, net		(28)		(12)
Accrued interest		35		15
Other		(26)		17
Other operating activities
Defined benefit plans - funding		(1)		(1)
Other assets		0		(22)
Other liabilities		(2)		(20)
Net cash provided by operating activities		28		39
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(229)		(155)
Expenditures for intangible assets		(1)		(1)
Notes receivable from affiliates		(554)		0
Other investing activities		4		0
Net cash used in investing activities		(780)		(156)
Cash Flows from Financing Activities
Issuance of long-term debt		649		1,329
Retirement of long-term debt		0		(1,150)
Payment of common stock dividends to parent		(88)		(74)
Net increase (decrease) in short-term debt		(509)		(145)
Contributions from parent		675		200
Debt Issuance Costs		(5)		(12)
Net cash provided by financing activities		722		148
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(30)		31
Cash and Cash Equivalents at Beginning of Period		51
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		51		25
Cash and Cash Equivalents at End of Period		21
Cash, Cash Equivalents and Restricted Cash at End of Period		21		56
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		146		142
Louisville Gas And Electric Co [Member]
Cash Flows from Operating Activities
Net income (loss)		93	[2]	86
Depreciation		76		75
Amortization		3		3
Defined benefit plans - (income) expense		1		0
Deferred income taxes and investment tax credits		2		0
Change in current assets and current liabilities
Accounts receivable		(19)		28
Accounts receivable from affiliates		(11)		14
Accounts payable		6		(35)
Increase (Decrease) in Accounts Payable, Related Parties		34		31
Unbilled revenues		16		33
Fuel, materials and supplies		13		41
Taxes payable		(26)		(27)
Regulatory assets and liabilities, net		(21)		21
Accrued interest		23		18
Other		(19)		(11)
Other operating activities
Defined benefit plans - funding		(1)		0
Expenditures for asset retirement obligations		(2)		(2)
Other assets		0		(10)
Other liabilities		(2)		(1)
Net cash provided by operating activities		166		264
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(92)		(86)
Notes receivable from affiliates		(28)		(9)
Net cash used in investing activities		(120)		(95)
Cash Flows from Financing Activities
Issuance of long-term debt		0		399
Retirement of long-term debt		0		(300)
Payment of common stock dividends to parent		(37)		(31)
Net increase (decrease) in short-term debt		28		(179)
Return of capital to parent		(51)		(120)
Other financing activities		0		(3)
Net cash provided by financing activities		(60)		(234)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(14)		(65)
Cash and Cash Equivalents at Beginning of Period		18
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		44		93
Cash and Cash Equivalents at End of Period		8
Cash, Cash Equivalents and Restricted Cash at End of Period		30		28
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		35		46
Kentucky Utilities Co [Member]
Cash Flows from Operating Activities
Net income (loss)	[3]	108		88
Depreciation		99		98
Amortization		5		5
Defined benefit plans - (income) expense		(1)		0
Deferred income taxes and investment tax credits		(1)		(1)
Other		(1)		(1)
Change in current assets and current liabilities
Accounts receivable		(21)		16
Accounts payable		(13)		(16)
Increase (Decrease) in Accounts Payable, Related Parties		52		2
Unbilled revenues		6		25
Fuel, materials and supplies		8		(8)
Taxes payable		(17)		(11)
Regulatory assets and liabilities, net		1		8
Accrued interest		32		26
Other		(7)		2
Other operating activities
Defined benefit plans - funding		(1)		0
Expenditures for asset retirement obligations		(2)		(5)
Other assets		8		(13)
Other liabilities		(3)		(1)
Net cash provided by operating activities		252		214
Cash Flows from Investing Activities
Expenditures for property, plant and equipment		(148)		(141)
Net cash used in investing activities		(148)		(141)
Cash Flows from Financing Activities
Issuance of long-term debt		0		399
Retirement of long-term debt		0		(300)
Increase Decrease In Notes Payable To Affiliates		37		9
Payment of common stock dividends to parent		(47)		(35)
Net increase (decrease) in short-term debt		(48)		(101)
Return of capital to parent		(50)		(54)
Other financing activities		0		(3)
Net cash provided by financing activities		(108)		(85)
Net Increase (Decrease) in Cash, Cash Equivalents and Restricted Cash		(4)		(12)
Cash and Cash Equivalents at Beginning of Period		14
Cash, Cash Equivalents and Restricted Cash at Beginning of Period		38		21
Cash and Cash Equivalents at End of Period		12
Cash, Cash Equivalents and Restricted Cash at End of Period		34		9
Supplemental Disclosures of Cash Flow Information
Accrued expenditures for property, plant and equipment at March 31,		$ 44		$ 60
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

CONDENSED CONSOLIDATED BALANCE

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Millions		Mar. 31, 2024	Dec. 31, 2023
Assets, Current [Abstract]
Cash and cash equivalents		$ 276	$ 331
Accounts receivable (less reserve:)
Customer		999	950
Other		271	271
Unbilled revenues		371	428
Fuel, materials and supplies		477	505
Prepayments		212	103
Regulatory Assets, Current		330	293
Other current assets		101	51
Total Current Assets		3,037	2,932
Property, Plant and Equipment
Regulated utility plant		39,031	38,608
Less:  accumulated depreciation - regulated utility plant		9,327	9,156
Regulated utility plant, net		29,704	29,452
Non-regulated property, plant and equipment		71	72
Less:  accumulated depreciation - non-regulated property, plant and equipment		24	23
Non-regulated property, plant and equipment, net		47	49
Construction work in progress		1,996	1,917
Property, Plant and Equipment, net		31,747	31,418
Other Noncurrent Assets
Regulatory assets		1,859	1,874
Goodwill		2,247	2,247
Other intangibles		304	306
Other noncurrent assets		437	459
Assets, Noncurrent		4,847	4,886
Total Assets		39,631	39,236
Current Liabilities
Short-term debt		291	992
Long-term debt due within one year		1	1
Accounts payable		903	1,104
Taxes		83	130
Interest		214	124
Dividends		186	173
Regulatory liabilities		223	225
Other current liabilities		474	591
Liabilities, Current, Total		2,375	3,340
Long-term Debt, Unclassified [Abstract]
Long-term Debt		15,753	14,611
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		3,195	3,105
Investment tax credits		113	114
Accrued pension obligations		255	275
Asset retirement obligations		127	133
Regulatory liabilities		3,351	3,340
Other deferred credits and noncurrent liabilities		404	385
Total Deferred Credits and Other Noncurrent Liabilities		7,445	7,352
Commitments and Contingent Liabilities
Equity
Common stock	[1]	8	8
Additional paid-in capital		12,314	12,326
Treasury Stock		(931)	(948)
Earnings reinvested		2,828	2,710
Accumulated other comprehensive loss		(161)	(163)
Total Equity		14,058	13,933
Total Liabilities and Equity		39,631	39,236
PPL Electric Utilities Corp [Member]
Assets, Current [Abstract]
Cash and cash equivalents		21	51
Accounts receivable (less reserve:)
Other		10	8
Unbilled revenues		119	149
Notes Receivable from affiliates		554	0
Fuel, materials and supplies		103	99
Prepayments		155	44
Regulatory Assets, Current		84	57
Other current assets		33	17
Total Current Assets		1,539	869
Property, Plant and Equipment
Regulated utility plant		15,740	15,575
Less:  accumulated depreciation - regulated utility plant		3,889	3,822
Regulated utility plant, net		11,851	11,753
Construction work in progress		744	680
Property, Plant and Equipment, net		12,595	12,433
Other Noncurrent Assets
Regulatory assets		592	598
Other intangibles		269	269
Other noncurrent assets		121	125
Assets, Noncurrent		982	992
Total Assets		15,116	14,294
Current Liabilities
Short-term debt		0	509
Taxes		3	51
Interest		78	43
Regulatory liabilities		90	91
Other current liabilities		82	100
Liabilities, Current, Total		709	1,292
Long-term Debt, Unclassified [Abstract]
Long-term Debt		5,211	4,567
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		1,608	1,573
Regulatory liabilities		839	836
Other deferred credits and noncurrent liabilities		110	123
Total Deferred Credits and Other Noncurrent Liabilities		2,557	2,532
Commitments and Contingent Liabilities
Equity
Common stock	[2]	364	364
Additional paid-in capital		4,715	4,040
Earnings reinvested		1,560	1,499
Total Equity		6,639	5,903
Total Liabilities and Equity		$ 15,116	$ 14,294
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]		CEP Reserves, Inc	CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | Related Party
Accounts receivable (less reserve:)
Customer		$ 10	$ 10
Notes Receivable from affiliates		554	0
Current Liabilities
Accounts payable		52	44
PPL Electric Utilities Corp [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		450	434
Current Liabilities
Accounts payable		404	454
Louisville Gas And Electric Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		8	18
Accounts receivable (less reserve:)
Other		24	17
Unbilled revenues		72	88
Fuel, materials and supplies		130	143
Prepayments		11	11
Regulatory Assets, Current		14	7
Other current assets		6	0
Total Current Assets		454	429
Property, Plant and Equipment
Regulated utility plant		7,715	7,669
Less:  accumulated depreciation - regulated utility plant		1,599	1,549
Regulated utility plant, net		6,116	6,120
Construction work in progress		342	312
Property, Plant and Equipment, net		6,458	6,432
Other Noncurrent Assets
Regulatory assets		388	395
Goodwill		389	389
Other intangibles		17	18
Other noncurrent assets		92	90
Assets, Noncurrent		886	892
Total Assets		7,798	7,753
Current Liabilities
Short-term debt		28	0
Taxes		15	41
Price risk management liabilities current		1	1
Interest		44	21
Current Customer Deposits		35	34
Regulatory liabilities		2	16
Asset Retirement Obligation, Current		13	13
Other current liabilities		32	47
Liabilities, Current, Total		374	337
Long-term Debt, Unclassified [Abstract]
Long-term Debt		2,469	2,469
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		782	776
Investment tax credits		30	31
Asset retirement obligations		71	72
Regulatory liabilities		824	827
Price risk management liabilities		4	6
Other deferred credits and noncurrent liabilities		67	63
Total Deferred Credits and Other Noncurrent Liabilities		1,778	1,775
Commitments and Contingent Liabilities
Equity
Common stock	[3]	424	424
Additional paid-in capital		1,942	1,993
Earnings reinvested		811	755
Total Equity		3,177	3,172
Total Liabilities and Equity		7,798	7,753
Louisville Gas And Electric Co [Member] | Related Party
Accounts receivable (less reserve:)
Customer		40	29
Notes Receivable from affiliates		28	0
Current Liabilities
Accounts payable		83	49
Louisville Gas And Electric Co [Member] | Nonrelated Party
Accounts receivable (less reserve:)
Customer		121	116
Current Liabilities
Accounts payable		121	115
Kentucky Utilities Co [Member]
Assets, Current [Abstract]
Cash and cash equivalents		12	14
Accounts receivable (less reserve:)
Customer		152	143
Other		19	12
Unbilled revenues		91	97
Fuel, materials and supplies		177	185
Prepayments		11	13
Regulatory Assets, Current		7	3
Other current assets		2	1
Total Current Assets		471	468
Property, Plant and Equipment
Regulated utility plant		10,038	9,896
Less:  accumulated depreciation - regulated utility plant		2,547	2,476
Regulated utility plant, net		7,491	7,420
Construction work in progress		594	604
Property, Plant and Equipment, net		8,085	8,024
Other Noncurrent Assets
Regulatory assets		435	439
Goodwill		607	607
Other intangibles		18	19
Other noncurrent assets		157	157
Assets, Noncurrent		1,217	1,222
Total Assets		9,773	9,714
Current Liabilities
Short-term debt		$ 45	$ 93
Notes Payable, Related Party, Type [Extensible Enumeration]		Affiliated Entity [Member]	Affiliated Entity [Member]
Notes Payable to affiliates		$ 37	$ 0
Taxes		15	32
Interest		56	24
Current Customer Deposits		38	35
Regulatory liabilities		6	1
Asset Retirement Obligation, Current		16	13
Other current liabilities		44	52
Liabilities, Current, Total		450	402
Long-term Debt, Unclassified [Abstract]
Long-term Debt		3,064	3,064
Deferred Credits and Other Noncurrent Liabilities
Deferred income taxes		917	912
Investment tax credits		83	83
Asset retirement obligations		48	53
Regulatory liabilities		1,016	1,018
Other deferred credits and noncurrent liabilities		32	30
Total Deferred Credits and Other Noncurrent Liabilities		2,096	2,096
Commitments and Contingent Liabilities
Equity
Common stock	[4]	308	308
Additional paid-in capital		2,983	3,033
Earnings reinvested		872	811
Total Equity		4,163	4,152
Total Liabilities and Equity		9,773	9,714
Kentucky Utilities Co [Member] | Related Party
Current Liabilities
Accounts payable		123	72
Kentucky Utilities Co [Member] | Nonrelated Party
Current Liabilities
Accounts payable		$ 70	$ 80
[1] 1,560,000 shares authorized, 770,013 shares issued and 737,736 shares outstanding at March 31, 2024. 1,560,000 shares authorized, 770,013 shares issued and 737,130 shares outstanding at December 31, 2023. 170,000 shares authorized; 66,368 shares issued and outstanding at March 31, 2024 and December 31, 2023. 75,000 shares authorized; 21,294 shares issued and outstanding at March 31, 2024 and December 31, 2023. 80,000 shares authorized; 37,818 shares issued and outstanding at March 31, 2024 and December 31, 2023.

CONDENSED CONSOLIDATED BALANC_2

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) (Parenthetical) - USD ($) shares in Thousands, $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 146	$ 123
Unbilled revenues, reserve	4	4
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)	737,736	737,130
PPL Electric Utilities Corp [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 57	$ 46
Unbilled revenues, reserve	2	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	$ 6
Unbilled revenues, reserve	$ 0	$ 0
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	75,000	75,000
Common stock shares issued (in shares)	21,294	21,294
Common stock shares outstanding (in shares)	21,294	21,294
Kentucky Utilities Co [Member]
Receivables, Net, Current [Abstract]
Accounts receivable reserve for doubtful accounts	$ 3	$ 2
Unbilled revenues, reserve	$ 0	$ 0
Equity
Common stock, no par value (in dollars per share)	$ 0	$ 0
Common stock shares authorized (in shares)	80,000	80,000
Common stock shares issued (in shares)	37,818	37,818
Common stock shares outstanding (in shares)	37,818	37,818

CONDENSED CONSOLIDATED STATEM_5

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) - USD ($) shares in Thousands, $ in Millions	Total		Common Stock [Member]		Additional Paid-in Capital [Member]	Earnings Reinvested [Member]		Accumulated Other Comprehensive Loss [Member]	Treasury Stock, Common	Noncontrolling Interest	PPL Electric Utilities Corp [Member]		PPL Electric Utilities Corp [Member] Common Stock [Member]		PPL Electric Utilities Corp [Member] Additional Paid-in Capital [Member]	PPL Electric Utilities Corp [Member] Earnings Reinvested [Member]	Louisville Gas And Electric Co [Member]		Louisville Gas And Electric Co [Member] Common Stock [Member]		Louisville Gas And Electric Co [Member] Additional Paid-in Capital [Member]	Louisville Gas And Electric Co [Member] Earnings Reinvested [Member]	Kentucky Utilities Co [Member]		Kentucky Utilities Co [Member] Common Stock [Member]		Kentucky Utilities Co [Member] Additional Paid-in Capital [Member]	Kentucky Utilities Co [Member] Earnings Reinvested [Member]
Total Equity	$ 13,918		$ 8		$ 12,317	$ 2,681		$ (124)	$ (967)	$ 3	$ 5,751		$ 364		$ 4,084	$ 1,303	$ 3,166		$ 424		$ 2,087	$ 655	$ 4,038		$ 308		$ 3,041	$ 689
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2400
Balance at beginning of period - shares at Dec. 31, 2022			736,487	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 19				2				$ 17
Stock Issued During Period, Shares, Treasury Stock Reissued									580
Stock-based compensation	(9)				(9)
Net income (loss)	285					285					138	[5]				138	86					86	88	[6]				88
Capital contributions from parent											200																(54)
Dividends and dividend equivalents	(178)	[7]				(178)	[7]									(74)						(31)						(35)
Dividends declared											(74)						(31)						(35)
Other comprehensive income (loss)	1							1
Balance at end of period - shares at Mar. 31, 2023			737,067	[1]									66,368	[2]					21,294	[3]					37,818	[4]
Contributions from parent											200				200
Return of Capital to Parent																					(120)						(54)
Total Equity	14,036		$ 8		12,310	2,788		(123)	$ (950)	3	6,015		$ 364		4,284	1,367	3,101		$ 424		1,967	710	4,037		$ 308		2,987	742
Total Equity	$ 13,933		$ 8		12,326	2,710		(163)	(948)	0	$ 5,903		$ 364		4,040	1,499	$ 3,172		$ 424		1,993	755	$ 4,152		$ 308		3,033	811
Dividends Declared Per Share of Common Stock (in dollars per share)	$ 0.2575
Balance at beginning of period - shares at Dec. 31, 2023	737,130		737,130	[1]							66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Stock Issued During Period, Value, Treasury Stock Reissued	$ 17				0				$ 17
Stock Issued During Period, Shares, Treasury Stock Reissued									606
Stock-based compensation	(12)				(12)
Net income (loss)	307					307					$ 149	[5]				149	$ 93	[8]				93	$ 108	[6]				108
Capital contributions from parent											675
Dividends and dividend equivalents	(189)	[7]				(189)	[7]									(88)						(37)						(47)
Dividends declared											$ (88)						$ (37)						$ (47)
Other comprehensive income (loss)	$ 2							2
Balance at end of period - shares at Mar. 31, 2024	737,736		737,736								66,368		66,368	[2]			21,294		21,294	[3]			37,818		37,818	[4]
Contributions from parent											$ 675				675
Return of Capital to Parent																					(51)						(50)
Total Equity	$ 14,058		$ 8		$ 12,314	$ 2,828		$ (161)	$ (931)	$ 0	$ 6,639		$ 364		$ 4,715	$ 1,560	$ 3,177		$ 424		$ 1,942	$ 811	$ 4,163		$ 308		$ 2,983	$ 872
[1] Shares in thousands. Each share entitles the holder to one vote on any question presented at any shareowners' meeting. Shares in thousands. All common shares of PPL Electric stock are owned by PPL Energy Holdings. Shares in thousands. All common shares of LG&E stock are owned by LKE. Shares in thousands. All common shares of KU stock are owned by LKE. Net income equals comprehensive income. Net income equals comprehensive income. Dividends declared per share of common stock were $0.2575 for the three months ended March 31, 2024 and $0.2400 for the three months ended March 31, 2023. Net income equals comprehensive income.

CONDENSED CONSOLIDATED STATEM_6

CONDENSED CONSOLIDATED STATEMENTS OF EQUITY (Unaudited) (Parenthetical) - vote	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Vote per share of PPL's common stock	1	1

Segment and Related Information

Segment and Related Information	3 Months Ended
	Mar. 31, 2024
Segment Reporting [Abstract]
Segment and Related Information	2. Segment and Related Information (PPL) PPL is organized into three segments: Kentucky Regulated, Pennsylvania Regulated and Rhode Island Regulated. PPL's segments are determined by geographic location. The Kentucky Regulated segment includes the regulated electricity generation, transmission and distribution operations conducted by LG&E and KU, as well as LG&E's regulated distribution and sale of natural gas. The Pennsylvania Regulated segment includes the regulated electricity transmission and distribution operations of PPL Electric. The Rhode Island Regulated segment includes the regulated electricity transmission and distribution and natural gas distribution operations of RIE. "Corporate and Other" primarily includes corporate level financing costs, certain unallocated costs and certain non-recoverable costs incurred in conjunction with the acquisition of Narragansett Electric. "Corporate and Other" is presented to reconcile segment information to PPL's consolidated results. Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended March 31 are as follows: Three Months 2024 2023 Operating Revenues from external customers Kentucky Regulated $ 984 $ 960 Pennsylvania Regulated 770 891 Rhode Island Regulated 549 565 Corporate and Other 1 (1) Total $ 2,304 $ 2,415 Net Income (Loss) Kentucky Regulated $ 190 $ 166 Pennsylvania Regulated 149 138 Rhode Island Regulated 64 54 Corporate and Other (96) (73) Total $ 307 $ 285 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of: March 31, December 31, Assets Kentucky Regulated $ 17,074 $ 17,029 Pennsylvania Regulated 15,116 14,294 Rhode Island Regulated 6,614 6,515 Corporate and Other (a) 827 1,398 Total $ 39,631 $ 39,236 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions. (PPL Electric, LG&E and KU)

Earnings Per Share

Earnings Per Share	3 Months Ended
	Mar. 31, 2024
Earnings Per Share [Abstract]
Earnings Per Share	4. Earnings Per Share (PPL) Basic EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding during the applicable period. Diluted EPS is computed by dividing income available to PPL common shareowners by the weighted-average number of common shares outstanding, increased by the number of incremental shares that would be outstanding if potentially dilutive share-based payment awards were converted to common shares as calculated using the Two-Class Method or Treasury Stock Method. Incremental non-participating securities that have a dilutive impact are detailed in the table below. Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended March 31 used in the EPS calculation are: Three Months 2024 2023 Income (Numerator) Net income attributable to PPL $ 307 $ 285 Less amounts allocated to participating securities — 1 Net income available to PPL common shareowners - Basic and Diluted $ 307 $ 284 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,512 736,829 Add: Dilutive share-based payment awards (a) 1,308 869 Weighted-average shares - Diluted EPS 738,820 737,698 Basic and Diluted EPS Net Income available to PPL common shareowners $ 0.42 $ 0.39 (a) The Treasury Stock Method was applied to non-participating share-based payment awards. For the periods ended March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months 2024 2023 Stock-based compensation awards — 534

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2024
Income Tax Disclosure [Abstract]
Income Taxes	5. Income Taxes Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows. (PPL) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 81 $ 76 Increase (decrease) due to: State income taxes, net of federal income tax benefit 17 22 Utility rate-making tax adjustments (a) (5) (5) Amortization of excess deferred federal and state income taxes (13) (12) Other 1 (2) Total increase (decrease) — 3 Total income tax expense (benefit) $ 81 $ 79 (a) Primarily consists of tax impacts of AFUDC equity and related depreciation across all PPL utilities and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. (PPL Electric) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 41 $ 38 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 14 Utility rate-making tax adjustments (a) (4) (4) Amortization of excess deferred federal and state income taxes (2) (2) Other (1) (1) Total increase (decrease) 7 7 Total income tax expense (benefit) $ 48 $ 45 (a) Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense. (LG&E) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 25 $ 23 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 4 Amortization of excess deferred federal and state income taxes (3) (3) Other (2) (1) Total increase (decrease) (1) — Total income tax expense (benefit) $ 24 $ 23 (KU) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 28 $ 23 Increase (decrease) due to: State income taxes, net of federal income tax benefit 5 4 Amortization of excess deferred federal and state income taxes (5) (4) Other (1) (1) Total increase (decrease) (1) (1) Total income tax expense (benefit) $ 27 $ 22 Other IRS Revenue Procedure 2023-15 (PPL and LG&E) On April 14, 2023, the IRS issued Revenue Procedure 2023-15, which provides a safe harbor method of accounting that taxpayers may use to determine whether expenses to repair, maintain, replace, or improve natural gas transmission and distribution property must be capitalized for tax purposes. PPL and LG&E are currently reviewing the revenue procedure to determine what impact the guidance may have on their financial statements. Transfer of Certain Credits under the Inflation Reduction Act (PPL) On April 25, 2024, the IRS released the final Internal Revenue Code Section 6418 regulations related to the transfer of certain credits under the Inflation Reduction Act. The regulations were published in the Federal Register on April 30, 2024, and will be effective on July 1, 2024. PPL is currently reviewing the final regulations to determine what impact the guidance may have on their financial statements.

Utility Rate Regulation

Utility Rate Regulation	3 Months Ended
	Mar. 31, 2024
Regulated Operations [Abstract]
Utility Rate Regulation	6. Utility Rate Regulation (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric LG&E KU March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, Current Regulatory Assets: Rate adjustment mechanisms $ 129 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 15 14 — — — — — — Derivative instruments 29 51 — — — — — — Smart meter rider 6 6 6 6 — — — — Universal service rider 8 — 8 — — — — — Storm damage costs 33 12 33 12 — — — — Gas supply clause 4 — — — 4 — — — Fuel adjustment clause 12 4 — — 6 3 6 — Transmission service charge 36 43 26 31 — — — — Transmission formula rate 15 5 — — — — — — Distribution system improvement charge 8 7 8 7 — — — — Other 35 33 3 1 4 4 1 3 Total current regulatory assets $ 330 $ 293 $ 84 $ 57 $ 14 $ 7 $ 7 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 880 $ 887 $ 417 $ 417 $ 212 $ 217 $ 134 $ 136 Plant outage costs 36 38 — — 9 10 27 28 Net metering 123 112 — — — — — — Environmental cost recovery 97 99 — — — — — — Storm costs 96 97 — — 14 15 14 14 Unamortized loss on debt 22 22 3 3 10 10 7 7 Interest rate swaps 5 7 — — 5 7 — — Terminated interest rate swaps 56 58 — — 33 34 23 24 Accumulated cost of removal of utility plant 171 178 171 178 — — — — AROs 288 289 — — 76 76 212 213 Derivatives instruments 4 8 — — — — — — Other 81 79 1 — 29 26 18 17 Total noncurrent regulatory assets $ 1,859 $ 1,874 $ 592 $ 598 $ 388 $ 395 $ 435 $ 439 PPL PPL Electric LG&E KU March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, Current Regulatory Liabilities: Generation supply charge $ 64 $ 51 $ 64 $ 51 $ — $ — $ — $ — Tax Cuts and Jobs Act customer refund — 5 — 5 — — — — Act 129 compliance rider 12 15 12 15 — — — — Transmission formula rate 17 21 14 18 — — — — Rate adjustment mechanism 68 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — Other 37 23 — 2 2 1 6 1 Total current regulatory liabilities $ 223 $ 225 $ 90 $ 91 $ 2 $ 16 $ 6 $ 1 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,008 $ 996 $ — $ — $ 309 $ 306 $ 402 $ 399 Power purchase agreement - OVEC 16 19 — — 11 13 5 6 Net deferred taxes 1,960 1,977 759 763 454 459 517 523 Defined benefit plans 256 252 80 73 20 20 60 59 Terminated interest rate swaps 56 57 — — 28 29 28 28 Energy efficiency 18 5 — — — — — — Other 37 34 — — 2 — 4 3 Total noncurrent regulatory liabilities $ 3,351 $ 3,340 $ 839 $ 836 $ 824 $ 827 $ 1,016 $ 1,018 Regulatory Matters Rhode Island Activities (PPL) Rate Case Proceedings Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC. The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5. Advanced Metering Functionality (AMF) In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory. On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending, even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC (i) an updated electric Service Quality Plan on December 27, 2023 for RIPUC approval and (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023 for RIPUC approval. RIE cannot predict the outcome of these matters. Grid Modernization RIE filed a new GMP with the RIPUC on December 30, 2022. The new GMP filing consists of a holistic suite of grid modernization investments that will provide RIE with the tools and capability to manage the electric distribution system more granularly considering a range of distributed energy resources adoption levels, accelerated by Rhode Island's climate mandates, while at the same time maintaining a safe and reliable electric distribution system. The GMP is an informational guidance document that supports the grid modernization investments to be proposed in future electric ISR plans. Consequently, RIE did not request approval from the RIPUC for any specific investments or seek cost recovery as part of the GMP; rather, RIE requested that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023, to discuss the scope of the RIPUC’s review of the GMP and its potential impact future electric ISR plans. RIE cannot predict the outcome of this matter. Petition for Deferral of Credit Card Fees On January 31, 2024, RIE filed a petition to request approval to recognize regulatory assets related to the credit card, debit card, and related fees (Electronic Transaction Fees) that RIE has waived and will continue to waive on a going forward basis pursuant to the RIPUC orders in RIPUC Docket No. 5022 related to COVID-19 impacts. If approved, RIE plans to include a proposal as part of its next base distribution rate case for the amortization/recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. The Rhode Island Division of Public Utilities and Carriers (the Division) and Intervenor testimony is due two weeks following the filing of RIE's Revised 2022 Earnings Reports, which RIE intends to file in the second quarter of 2024. RIE's rebuttal testimony is due two weeks following the Division's filing of its testimony. No hearings have been scheduled at this time. RIE simultaneously filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges pending in Docket No. 5154. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter. FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. T he RIPUC has not taken any action to date on this issue, including in its recent action on the FY 2025 Gas ISR Plan. FY 2024 Gas ISR Plan At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below. FY 2025 Gas ISR Plan On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend, plus up to an additional $11 million of contingency plan spend in light of the Pipeline and Hazardous Materials Safety Administration’s potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), p lus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. FY 2024 Electric ISR Plan The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below. FY 2025 Electric ISR Plan On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. Kentucky Activities (PPL, LG&E and KU) KPSC Investigation Related to Winter Storm Elliott On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties have been granted intervenor status for the proceeding and a hearing on the matter is scheduled for May 23, 2024. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition. Pennsylvania Activities (PPL and PPL Electric) PAPUC investigation into billing issues On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC’s Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric’s hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E have 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The final approval of the Settlement Agreement is pending the issuance of the PAPUC's order and PPL Electric and I&E's decision on whether to accept the modifications . PPL Electric cannot predict the outcome of this matter. PPL Electric incurred costs related to the billing issues of $15 million and $3 million for the three-month periods ended March 31, 2024 and March 31, 2023. PPL Electric will not seek regulatory recovery of these costs. DSIC Petition On April 26, 2024, PPL Electric filed a Petition with the PAPUC requesting that the PAPUC waive PPL Electric’s DSIC cap of 5% of billed revenues and increase the maximum allowable DSIC to 9% for bills rendered on or after January 1, 2025. PPL Electric requested PAPUC approval no later than the PAPUC’s public meeting on December 5, 2024. 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 filed a petition for review of the FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals and provided refunds in accordance with the FERC order on December 1, 2023. The FERC issued an order on LG&E and KU's compliance filing on November 16, 2023, and LG&E and KU filed a petition for review of this November 16, 2023 order on February 14, 2024. The proceedings at the D.C. Circuit Court of Appeals were held on abeyance to allow the FERC time to substantively address LG&E and KU's request for rehearing of the November 16 order. FERC issued the substantive order on rehearing on March 21, 2024. LG&E and KU filed an unopposed motion to lift the abeyance on April 24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May of 2024. LG&E and KU cannot predict the ultimate outcome of the proceedings or any other post decision process but do not expect the annual impact to have a material effect on their operations or financial condition. LG&E and KU currently receive recovery of certain waivers and credits primarily through base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings. Recovery of Transmission Costs (PPL) Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum ROE of 11.74% on its transmission assets. The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the 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 months ended March 31, 2024 and 2023, PPL Electric purchased $419 million and $358 million of accounts receivable from alternative suppliers. (PPL)

Financing Activities

Financing Activities	3 Months Ended
	Mar. 31, 2024
Debt Disclosure [Abstract]
Financing Activities	7. Financing Activities Credit Arrangements and Short-term Debt (All Registrants) The Registrants maintain credit facilities to enhance liquidity, provide credit support and provide a backstop to commercial paper programs. For reporting purposes, on a consolidated basis, the credit facilities and commercial paper programs of PPL Electric, LG&E and KU are attributable to PPL. The amounts listed in the borrowed column below are recorded as "Short-term debt" on the Balance Sheets. The following credit facilities were in place at: March 31, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Borrowed Letters of PPL PPL Capital Funding (a) Syndicated Credit Facility (b) Dec. 2028 $ 1,250 $ — $ 218 $ 1,032 $ — $ 390 Bilateral Credit Facility Feb. 2025 100 — — 100 — — Bilateral Credit Facility Feb. 2025 100 — 13 87 — 13 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 231 $ 1,219 $ — $ 403 PPL Electric Syndicated Credit Facility Dec. 2028 $ 650 $ — $ 1 $ 649 $ — $ 511 Total PPL Electric Credit Facilities $ 650 $ — $ 1 $ 649 $ — $ 511 LG&E Syndicated Credit Facility Dec. 2028 $ 500 $ — $ 28 $ 472 $ — $ — Total LG&E Credit Facilities $ 500 $ — $ 28 $ 472 $ — $ — KU Syndicated Credit Facility Dec. 2028 $ 400 $ — $ 45 $ 355 $ — $ 93 Total KU Credit Facilities $ 400 $ — $ 45 $ 355 $ — $ 93 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) The PPL Capital Funding $1.25 billion syndicated credit facility includes a $400 million borrowing sublimit for RIE and a $850 million sublimit for PPL Capital Funding at March 31, 2024. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At December 31, 2023, the borrowing sublimit for RIE was $250 million and a $1 billion sublimit for PPL Capital Funding. At March 31, 2024, PPL Capital Funding had $218 million commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL. (c) Commercial paper issued reflects the undiscounted face value of the issuance. (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: March 31, 2024 December 31, 2023 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) (b) 5.51% $ 1,350 $ 218 $ 1,132 5.66% $ 365 RIE (b) 400 — 400 5.72% 25 PPL Electric 650 — 650 5.67% 510 LG&E 5.49% 500 28 472 — KU 5.49% 400 45 355 5.64% 93 Total $ 3,300 $ 291 $ 3,009 $ 993 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility, which has a total capacity of $1.25 billion. At March 31, 2024, the borrowing sublimits were $400 million for RIE and $850 million for PPL Capital Funding. At December 31, 2023, the borrowing sublimits under the facility were $250 million at RIE and $1 billion at PPL Capital Funding. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. (c) Commercial paper issued reflects the undiscounted face value of the issuance. (PPL Electric, LG&E, and KU) See Note 11 for discussion of intercompany borrowings. Long-term Debt (PPL) In March 2024, RIE issued $500 million of 5.35% Senior Notes due 2034. RIE received proceeds of $496 million, net of discounts and underwriting fees, which will be used to repay short-term debt and for other general corporate purposes. (PPL and PPL Electric) In January 2024, PPL Electric issued $650 million of 4.85% First Mortgage Bonds due 2034. PPL Electric received proceeds of $644 million, net of discounts and underwriting fees, which will be used to repay short-term debt and for other general corporate purposes. Dividends

Defined Benefits

Defined Benefits	3 Months Ended
	Mar. 31, 2024
Retirement Benefits [Abstract]
Defined Benefits	9. Defined Benefits (PPL) Certain net periodic defined benefit costs are applied to accounts that are further distributed among capital, expense, regulatory assets and regulatory liabilities, including certain costs allocated to applicable subsidiaries for plans sponsored by PPL Services and LKE. Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended March 31: Pension Benefits Three Months 2024 2023 PPL Service cost $ 9 $ 9 Interest cost 46 46 Expected return on plan assets (75) (78) Amortization of: Prior service cost 1 2 Actuarial loss 2 — Net periodic defined benefit costs (credits) $ (17) $ (21) Other Postretirement Benefits Three Months 2024 2023 PPL Service cost $ 1 $ 2 Interest cost 7 7 Expected return on plan assets (7) (8) Amortization of: Actuarial loss (1) (1) Net periodic defined benefit costs (credits) $ — $ — (All Registrants) The non-service cost components of net periodic defined benefit costs (credits) (interest cost, expected return on plan assets, amortization of prior service cost and amortization of actuarial gain and loss) are presented in "Other Income (Expense) - net" on the Statements of Income. See Note 12 for additional information.

Related Party Transactions

Related Party Transactions	3 Months Ended
	Mar. 31, 2024
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LG&E and KU) PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. Three Months 2024 2023 PPL Electric from PPL Services $ 56 $ 59 LG&E from LKS 29 32 LG&E from PPL Services 11 8 KU from LKS 38 41 KU from PPL Services 11 9 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2024, CEP Reserves had $ 554 million no (LG&E and KU) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be reflected in "Notes payable to affiliates" on the LG&E Balance Sheets. 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 March 31, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $ 37 million no
Louisville Gas And Electric Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LG&E and KU) PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. Three Months 2024 2023 PPL Electric from PPL Services $ 56 $ 59 LG&E from LKS 29 32 LG&E from PPL Services 11 8 KU from LKS 38 41 KU from PPL Services 11 9 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2024, CEP Reserves had $ 554 million no (LG&E and KU) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be reflected in "Notes payable to affiliates" on the LG&E Balance Sheets. 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 March 31, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $ 37 million no
Kentucky Utilities Co [Member]
Related Party Transactions [Line Items]
Related Party Transactions	11. Related Party Transactions Support Costs (PPL Electric, LG&E and KU) PPL Services and LKS provide the Registrants, their respective subsidiaries and each other with administrative, management and support services. For all services companies, the costs of directly assignable and attributable services are charged to the respective recipients as direct support costs. General costs that cannot be directly attributed to a specific entity are allocated and charged to the respective recipients as indirect support costs. PPL Services and LKS use a three-factor methodology that includes the applicable recipients' invested capital, operation and maintenance expenses and number of employees to allocate indirect costs. PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. Three Months 2024 2023 PPL Electric from PPL Services $ 56 $ 59 LG&E from LKS 29 32 LG&E from PPL Services 11 8 KU from LKS 38 41 KU from PPL Services 11 9 In addition to the charges for services noted above, LKS makes payments on behalf of LG&E and KU for fuel purchases and other costs for products or services provided by third parties. LG&E and KU also provide services to each other and to LKS. Billings between LG&E and KU relate to labor and overheads associated with union and hourly employees performing work for the other company, charges related to jointly-owned generating units and other miscellaneous charges. Tax settlements between PPL and LG&E and KU are reimbursed through LKS. Intercompany Borrowings (PPL Electric) CEP Reserves maintains a $800 million revolving line of credit with a PPL Electric subsidiary. At March 31, 2024, CEP Reserves had $ 554 million no (LG&E and KU) LG&E participates in an intercompany money pool agreement whereby LKE and/or KU make available to LG&E funds up to the difference between LG&E's FERC borrowing limit and LG&E's commercial paper issued at an interest rate based on the lower of a market index of commercial paper issues and two additional rate options based on SOFR. At March 31, 2024, LG&E's money pool unused capacity was $722 million. At March 31, 2024 and December 31, 2023, LG&E had insignificant borrowings outstanding from KU and/or LKE. These balances would be reflected in "Notes payable to affiliates" on the LG&E Balance Sheets. 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 March 31, 2024, KU's money pool unused capacity was $568 million. At March 31, 2024, KU had borrowings outstanding from LG&E and/or LKE of $ 37 million no

Fair Value Measurements

Fair Value Measurements	3 Months Ended
	Mar. 31, 2024
Fair Value Disclosures [Abstract]
Fair Value Measurements	13. Fair Value Measurements (All Registrants) Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (an exit price). A market approach (generally, data from market transactions), an income approach (generally, present value techniques and option pricing models) and/or a cost approach (generally, replacement cost) are used to measure the fair value of an asset or liability, as appropriate. These valuation approaches incorporate inputs such as observable, independent market data and/or unobservable data that management believes are predicated on the assumptions market participants would use to price an asset or liability. These inputs may incorporate, as applicable, certain risks such as nonperformance risk, which includes credit risk. The fair value of a group of financial assets and liabilities is measured on a net basis. See Note 1 in each Registrant's 2023 Form 10-K for information on the levels in the fair value hierarchy. Recurring Fair Value Measurements The assets and liabilities measured at fair value were: March 31, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 276 $ 276 $ — $ — $ 331 $ 331 $ — $ — Restricted cash and cash equivalents (a) 45 45 — — 51 51 — — Total Cash, Cash Equivalents and Restricted Cash (b) 321 321 — — 382 382 — — Special use funds (a): Money market fund 2 2 — — 1 1 — — Commingled debt fund measured at NAV (c) 7 — — — 9 — — — Commingled equity fund measured at NAV (c) 7 — — — 8 — — — Total special use funds 16 2 — — 18 1 — — Price risk management assets (d): Gas contracts 1 — 1 — 1 — 1 — Total assets $ 338 $ 323 $ 1 $ — $ 401 $ 383 $ 1 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 5 $ — $ 5 $ — $ 7 $ — $ 7 $ — Gas contracts 34 — 33 1 60 — 41 19 Total price risk management liabilities $ 39 $ — $ 38 $ 1 $ 67 $ — $ 48 $ 19 PPL Electric Assets Cash and cash equivalents $ 21 $ 21 $ — $ — $ 51 $ 51 $ — $ — Total assets $ 21 $ 21 $ — $ — $ 51 $ 51 $ — $ — LG&E Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 18 $ 18 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 26 26 — — Total Cash, Cash Equivalents and Restricted Cash (b) 30 30 — — 44 44 — — Total assets $ 30 $ 30 $ — $ — $ 44 $ 44 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 5 $ — $ 5 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 5 $ — $ 5 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 12 $ 12 $ — $ — $ 14 $ 14 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 24 24 — — Total Cash, Cash Equivalents and Restricted Cash (b) 34 34 — — 38 38 — — Total assets $ 34 $ 34 $ — $ — $ 38 $ 38 $ — $ — (a) Current portion is included in "Other current assets" and noncurrent portion is included in "Other noncurrent assets" on the Balance Sheets. (b) Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows. (c) In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Balance Sheets. (d) Current portion is included in "Other current 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 three months ended March 31 is as follows: Gas Contracts 2024 Balance at beginning of period $ 19 Settlements (18) Balance at end of period $ 1 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. March 31, 2024 December 31, 2023 Carrying Fair Value Carrying Fair Value PPL $ 15,754 $ 15,016 $ 14,612 $ 14,031 PPL Electric 5,211 5,023 4,567 4,475 LG&E 2,469 2,344 2,469 2,369 KU 3,064 2,832 3,064 2,861 (a) Amounts are net of debt issuance costs. The carrying amounts of other current financial instruments (except for long-term debt due within one year) approximate their fair values because of their short-term nature.

Derivative Instruments and Hedg

Derivative Instruments and Hedging Activities	3 Months Ended
	Mar. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments and Hedging Activities	14. Derivative Instruments and Hedging Activities (All Registrants) Risk Management Objectives PPL has a risk management policy approved by the Board of Directors to manage market risk associated with commodities, interest rates on debt issuances (including price, liquidity and volumetric risk) and credit risk (including non-performance risk and payment default risk). The Risk Management Committee, comprised of senior management and chaired by the Vice President-Financial Strategy and Chief Risk Officer, oversees the risk management function. Key risk control activities designed to ensure compliance with the risk policy and detailed programs include, but are not limited to, credit review and approval, validation of transactions, verification of risk and transaction limits, value-at-risk analyses (VaR, a statistical model that attempts to estimate the value of potential loss over a given holding period under normal market conditions at a given confidence level) and the coordination and reporting of the Enterprise Risk Management program. Market Risk Market risk includes the potential loss that may be incurred as a result of price changes associated with a particular financial or commodity instrument as well as market liquidity and volumetric risks. Forward contracts, futures contracts, options, swaps and structured transactions are utilized as part of risk management strategies to minimize unanticipated fluctuations in earnings caused by changes in commodity prices and interest rates. Many of these contracts meet the definition of a derivative. All derivatives are recognized on the Balance Sheets at their fair value, unless NPNS is elected. The following summarizes the market risks that affect PPL and its subsidiaries. Interest Rate Risk • PPL and its subsidiaries are exposed to interest rate risk associated with forecasted fixed-rate and existing floating-rate debt issuances. PPL and LG&E utilize over-the-counter interest rate swaps to limit exposure to market fluctuations on floating-rate debt. PPL, LG&E and KU utilize forward starting interest rate swaps to hedge changes in benchmark interest rates, when appropriate, in connection with future debt issuance. • PPL and its subsidiaries are exposed to interest rate risk associated with debt securities and derivatives held by defined benefit plans. This risk is significantly mitigated to the extent that the plans are sponsored at, or sponsored on behalf of, the regulated utilities due to the recovery methods in place. Commodity Price Risk PPL is exposed to commodity price risk through its subsidiaries as described below. • PPL Electric is required to purchase electricity to fulfill its obligation as a PLR. Potential commodity price risk is mitigated through its PAPUC-approved cost recovery mechanism and full-requirement supply agreements to serve its PLR customers which transfer the risk to energy suppliers. • LG&E's and KU's rates include certain mechanisms for fuel, fuel-related expenses and energy purchases. In addition, LG&E's rates include a mechanism for natural gas supply costs. These mechanisms generally provide for timely recovery of market price fluctuations associated with these costs. • RIE utilizes derivative instruments pursuant to its RIPUC-approved plan to manage commodity price risk associated with its natural gas purchases. RIE's commodity price risk management strategy is to reduce fluctuations in firm gas sales prices to its customers. RIE's costs associated with derivatives instruments are recoverable through its RIPUC-approved cost recovery mechanisms. RIE is required to purchase electricity to fulfill its obligation to provide Last Resort Service (LRS). Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms and full requirements service agreements to serve LRS customers, which transfer the risk to energy suppliers. RIE is required to contract through long-term agreements for clean energy supply under the Rhode Island Renewable Energy Growth program and Long-term Clean Energy Standard. Potential commodity price risk is mitigated through its RIPUC-approved cost recovery mechanisms, which true-up cost differences between contract prices and market prices. Volumetric Risk Volumetric risk is the risk related to the changes in volume of retail sales due to weather, economic conditions or other factors. PPL is exposed to volumetric risk through its subsidiaries as described below: • PPL Electric, LG&E and KU are exposed to volumetric risk on retail sales, mainly due to weather and other economic conditions for which there is limited mitigation between rate cases. • RIE is exposed to volumetric risk, which is significantly mitigated by regulatory mechanisms. RIE's electric and gas distribution rates both have a revenue decoupling mechanism, which allows for annual adjustments to RIE's delivery rates. Equity Securities Price Risk • PPL and its subsidiaries are exposed to equity securities price risk associated with the fair value of the defined benefit plans' assets. This risk is significantly mitigated due to the recovery methods in place. • PPL is exposed to equity securities price risk from future stock sales and/or purchases. Credit Risk Credit risk is the potential loss that may be incurred due to a counterparty's non-performance. PPL is exposed to credit risk from "in-the-money" transactions with counterparties as well as additional credit risk through certain of its subsidiaries, as discussed below. In the event a supplier of PPL, PPL Electric, LG&E or KU defaults on its contractual obligation, those Registrants would be required to seek replacement power or replacement fuel in the market. In general, subject to regulatory review or other processes, appropriate incremental costs incurred by these entities would be recoverable from customers through applicable rate mechanisms, thereby mitigating the financial risk for these entities. PPL and its subsidiaries have credit policies in place to manage credit risk, including the use of an established credit approval process, daily monitoring of counterparty positions and the use of master netting agreements or provisions. These agreements generally include credit mitigation provisions, such as margin, prepayment or collateral requirements. PPL and its subsidiaries may request additional credit assurance, in certain circumstances, if a counterparty's credit ratings fall below investment grade, their tangible net worth falls below specified percentages or its exposures exceed an established credit limit. Master Netting Arrangements (PPL, LG&E and KU) Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements. PPL, LG&E and KU had no obligation to return or post cash collateral under master netting arrangements at March 31, 2024 and December 31, 2023. See "Offsetting Derivative Instruments" below for a summary of derivative positions presented in the balance sheets where a right of setoff exists under these arrangements. Interest Rate Risk (All Registrants) PPL and its subsidiaries issue debt to finance their operations, which exposes them to interest rate risk. A variety of financial derivative instruments are utilized to adjust the mix of fixed and floating interest rates in their debt portfolios, adjust the duration of the debt portfolios and lock in benchmark interest rates in anticipation of future financing, when appropriate. Risk limits under PPL's risk management program are designed to balance risk exposure to volatility in interest expense and changes in the fair value of the debt portfolio due to changes in benchmark interest rates. In addition, the interest rate risk of certain subsidiaries is potentially mitigated as a result of the existing regulatory framework or the timing of rate cases. Cash Flow Hedges (PPL) Interest rate risks include exposure to adverse interest rate movements for outstanding variable rate debt and for future anticipated financings. Financial interest rate swap contracts that qualify as cash flow hedges may be entered into to hedge floating interest rate risk associated with both existing and anticipated debt issuances. PPL had no such contracts at March 31, 2024. Cash flow hedges are discontinued if it is no longer probable that the original forecasted transaction will occur by the end of the originally specified time period and any amounts previously recorded in AOCI are reclassified into earnings once it is determined that the hedged transaction is not probable of occurring. For the three months ended March 31, 2024 and 2023, PPL had no cash flow hedges reclassified into earnings associated with discontinued cash flow hedges. At March 31, 2024, the amount of accumulated net unrecognized after-tax gains (losses) on qualifying derivatives expected to be reclassified into earnings during the next 12 months is insignificant. Amounts are reclassified as the hedged interest expense is recorded. Economic Activity (PPL and LG&E) LG&E enters into interest rate swap contracts that economically hedge interest payments. Because realized gains and losses from the swaps, including terminated swap contracts, are recoverable through regulated rates, any subsequent changes in fair value of these derivatives are included in regulatory assets or liabilities until they are realized as interest expense. Realized gains and losses are recognized in "Interest Expense" on the Statements of Income at the time the underlying hedged interest expense is recorded. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2024 and December 31, 2023. At March 31, 2024, LG&E held contracts with a notional amount of $64 million that mature in 2033. Commodity Price Risk (PPL) Economic Activity RIE enters into derivative contracts that economically hedge natural gas purchases. Realized gains and losses from the derivatives are recoverable through regulated rates, therefore subsequent changes in fair value are included in regulatory assets or liabilities until they are realized as purchased gas. Realized gains and losses are recognized in "Energy Purchases" on the Statements of Income upon settlement of the contracts. At March 31, 2024, RIE held contracts with notional volumes of 41 Bcf that range in maturity from 2024 through 2029. Accounting and Reporting (All Registrants) All derivative instruments are recorded at fair value on the Balance Sheet as an asset or liability unless NPNS is elected. NPNS contracts include certain full requirement purchase contracts and other physical purchase contracts. Changes in the fair value of derivatives not designated as NPNS are recognized in earnings unless specific hedge accounting criteria are met and designated as such, except for the changes in fair values of LG&E's interest rate swaps and certain RIE commodity gas contracts that are recognized as regulatory assets or regulatory liabilities. See Note 6 for amounts recorded in regulatory assets and regulatory liabilities at March 31, 2024 and December 31, 2023. See Note 1 in each Registrant's 2023 Form 10-K for additional information on accounting policies related to derivative instruments. (PPL) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. March 31, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps (a) $ — $ 1 $ — $ 1 Gas contracts (a) 1 30 1 51 Total current 1 31 1 52 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps (a) — 4 — 6 Gas contracts (a) — 4 — 9 Total noncurrent — 8 — 15 Total derivatives $ 1 $ 39 $ 1 $ 67 (a) Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Excludes accrued interest, if applicable. The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2024. Three Months Three Months Derivative Derivative Gain Location of Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — Interest expense $ (1) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Gas contracts Energy purchases $ (16) Total $ (16) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Interest rate swaps Regulatory assets - noncurrent $ 2 Gas contracts Regulatory assets - current 22 Regulatory assets - noncurrent 4 Total $ 28 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 March 31, 2023. Three Months Three Months Derivative Derivative Gain Location of Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — Interest expense $ (1) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Interest rate swaps Interest expense $ — Gas contracts Energy purchases (2) Other income (expense) - net 1 Total $ (1) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Interest rate swaps Regulatory assets - noncurrent $ (1) Gas contracts Regulatory assets - current 28 Regulatory assets - noncurrent (7) Total $ 20 The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2024. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 179 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) The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2023. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 164 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) (LG&E) The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. March 31, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 1 Total current — 1 — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 4 — 6 Total noncurrent — 4 — 6 Total derivatives $ — $ 5 $ — $ 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 March 31, 2024. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Interest rate swaps Interest expense $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Interest rate swaps Regulatory assets - noncurrent $ 2 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 March 31, 2023. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Interest rate swaps Interest expense $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Interest rate swaps Regulatory assets - noncurrent $ (1) (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 March 31, 2024 Derivatives PPL $ 1 $ — $ — $ 1 $ 39 $ — $ — $ 39 LG&E — — — — 5 — — 5 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7 Credit Risk-Related Contingent Features Certain derivative contracts contain credit risk-related contingent features which, when in a net liability position, would permit the counterparties to require the transfer of additional collateral upon a decrease in the credit ratings of PPL, LG&E and KU or certain of their subsidiaries. Most of these features would require the transfer of additional collateral or permit the counterparty to terminate the contract if the applicable credit rating were to fall below investment grade. Some of these features also would allow the counterparty to require additional collateral upon each downgrade in credit rating at levels that remain above investment grade. In either case, if the applicable credit rating were to fall below investment grade, and assuming no assignment to an investment grade affiliate were allowed, most of these credit contingent features require either immediate payment of the net liability as a termination payment or immediate and ongoing full collateralization on derivative instruments in net liability positions. Additionally, certain derivative contracts contain credit risk-related contingent features that require adequate assurance of performance be provided if the other party has reasonable concerns regarding the performance of PPL's, LG&E's and KU's obligations under the contracts. A counterparty demanding adequate assurance could require a transfer of additional collateral or other security, including letters of credit, cash and guarantees from a creditworthy entity. This would typically involve negotiations among the parties. However, such amounts would represent assumed immediate payment or immediate and ongoing full collateralization for derivative instruments in net liability positions with "adequate assurance" features. (PPL) At March 31, 2024, derivative contracts in a net liability position that contain credit risk-related contingent features was $28 million. At March 31, 2024, the aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade was $29 million.

Asset Retirement Obligations

Asset Retirement Obligations	3 Months Ended
	Mar. 31, 2024
Asset Retirement Obligations [Line Items]
Asset Retirement Obligations	15. Asset Retirement Obligations (PPL, LG&E and KU) PPL's, LG&E's and KU's ARO liabilities are primarily related to CCR closure costs. See Note 10 for information on the CCR rule. LG&E and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 2 1 1 Obligations settled (5) (2) (3) Other 1 — — Balance at March 31, 2024 $ 156 $ 84 $ 64
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 and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 2 1 1 Obligations settled (5) (2) (3) Other 1 — — Balance at March 31, 2024 $ 156 $ 84 $ 64
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 and RIE also have AROs related to natural gas mains and wells. LG&E's and KU's transmission and distribution lines largely operate under perpetual property easement agreements, which do not generally require restoration upon removal of the property. Therefore, no material AROs are recorded for transmission and distribution assets. For LG&E, KU and RIE, all ARO accretion and depreciation expenses are reclassified as a regulatory asset or regulatory liability. ARO regulatory assets associated with certain CCR projects are amortized to expense in accordance with regulatory approvals. For other AROs, deferred accretion and depreciation expense is recovered through cost of removal. The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 2 1 1 Obligations settled (5) (2) (3) Other 1 — — Balance at March 31, 2024 $ 156 $ 84 $ 64

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income (Loss)	3 Months Ended
	Mar. 31, 2024
Accumulated Other Comprehensive Income (Loss) [Line Items]
Accumulated Other Comprehensive Income (Loss)	16. Accumulated Other Comprehensive Income (Loss) (PPL) The after-tax changes in AOCI by component for the periods ended March 31 were as follows. Unrealized gains (losses) Defined benefit plans Equity Prior Actuarial Total PPL December 31, 2023 $ 6 $ 3 $ (4) $ (168) $ (163) Amounts arising during the period — 1 — — 1 Reclassifications from AOCI 1 — — — 1 Net OCI during the period 1 1 — — 2 March 31, 2024 $ 7 $ 4 $ (4) $ (168) $ (161) December 31, 2022 $ 3 $ 2 $ (5) $ (124) $ (124) Amounts arising during the period — 1 — — 1 Reclassifications from AOCI 1 — — (1) — Net OCI during the period 1 1 — (1) 1 March 31, 2023 $ 4 $ 3 $ (5) $ (125) $ (123) The following table presents PPL's gains (losses) and related income taxes for reclassifications from AOCI for the periods ended March 31. Three Months Affected Line Item on the Details about AOCI 2024 2023 Statements of Income Qualifying derivatives Interest rate swaps $ (1) $ (1) Interest Expense Total Pre-tax (1) (1) Income Taxes — — Total After-tax (1) (1) Defined benefit plans Net actuarial loss (a) — 1 Total Pre-tax — 1 Income Taxes — — Total After-tax — 1 Total reclassifications during the period $ (1) $ — (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	3 Months Ended
	Mar. 31, 2024
Interim Financial Statements [Abstract]
Interim Financial Statements	1. Interim Financial Statements (All Registrants) Capitalized terms and abbreviations appearing in the unaudited combined notes to condensed financial statements are defined in the glossary. Dollars are in millions, except per share data, unless otherwise noted. The specific Registrant to which disclosures are applicable is identified in parenthetical headings in italics above the applicable disclosure or within the applicable disclosure for each Registrant's related activities and disclosures. Within combined disclosures, amounts are disclosed for any Registrant when significant. The accompanying unaudited condensed financial statements have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X and, therefore, do not include all of the information and footnote disclosures required by GAAP for complete financial statements. In the opinion of management, all adjustments considered necessary for a fair presentation in accordance with GAAP are reflected in the condensed financial statements. All adjustments are of a normal recurring nature, except as otherwise disclosed. Each Registrant's Balance Sheet at December 31, 2023 is derived from that Registrant's 2023 audited Balance Sheet. The financial statements and notes thereto should be read in conjunction with the financial statements and notes contained in each Registrant's 2023 Form 10-K. The results of operations for the three months ended March 31, 2024 are not necessarily indicative of the results to be expected for the full year ending December 31, 2024 or other future periods, because results for interim periods can be disproportionately influenced by various factors, developments and seasonal variations.

Summary of Significant Accounti

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2024
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	XX. Summary of Significant Accounting Policies (All Registrants) The following accounting policy disclosures represent updates to Note 1 in each Registrant's 2023 Form 10-K and should be read in conjunction with those disclosures. Restricted Cash and Cash Equivalents (PPL) Reconciliation of Cash, Cash Equivalents and Restricted Cash The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL March 31, December 31, Cash and cash equivalents $ 276 $ 331 Restricted cash - current (a) 45 1 Total Cash, Cash Equivalents and Restricted Cash $ 321 $ 332 (a) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets."

Revenue from Contracts with Cus

Revenue from Contracts with Customers	3 Months Ended
	Mar. 31, 2024
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' 2023 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 March 31. 2024 Three Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 2,304 $ 770 $ 476 $ 525 Revenues derived from: Alternative revenue programs (b) 7 (3) 2 5 Other (c) (8) (5) (1) (1) Revenues from Contracts with Customers $ 2,303 $ 762 $ 477 $ 529 2023 Three Months PPL PPL Electric LG&E KU Operating Revenues (a) $ 2,415 $ 891 $ 474 $ 499 Revenues derived from: Alternative revenue programs (b) 36 1 1 — Other (c) (4) (2) (1) (1) Revenues from Contracts with Customers $ 2,447 $ 890 $ 474 $ 498 (a) PPL includes $549 million for the three months ended March 31, 2024 and $565 million for the three months ended March 31, 2023 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. (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 March 31. Three Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 2024 PA Regulated $ 426 $ 106 $ 12 $ 13 $ — $ — $ 205 $ 762 KY Regulated 443 267 161 97 6 15 — 989 RI Regulated 261 78 4 161 — — 47 551 Corp and Other — — — 1 — — — 1 Total PPL $ 1,130 $ 451 $ 177 $ 272 $ 6 $ 15 $ 252 $ 2,303 2023 PA Regulated $ 537 $ 128 $ 20 $ 13 $ — $ — $ 192 $ 890 KY Regulated 443 274 164 60 7 11 — 959 RI Regulated 229 101 9 215 — — 45 599 Corp and Other — — — (1) — — — (1) Total PPL $ 1,209 $ 503 $ 193 $ 287 $ 7 $ 11 $ 237 $ 2,447 Three Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL Electric 2024 $ 426 $ 106 $ 12 $ 13 $ — $ — $ 205 $ 762 2023 $ 537 $ 128 $ 20 $ 13 $ — $ — $ 192 $ 890 LG&E 2024 $ 218 $ 138 $ 47 $ 52 $ — $ 22 $ — $ 477 2023 $ 241 $ 152 $ 49 $ 16 $ — $ 16 $ — $ 474 KU 2024 $ 225 $ 129 $ 114 $ 46 $ 6 $ 9 $ — $ 529 2023 $ 202 $ 123 $ 115 $ 44 $ 7 $ 7 $ — $ 498 (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 March 31. Three Months 2024 2023 PPL (a) $ 42 $ 21 PPL Electric (a) 28 10 LG&E 1 1 KU 1 — (a) 2024 includes amounts impaired related to PPL Electric's billing issues. See Note 6 for additional information. The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers. PPL PPL Electric LG&E KU Contract liabilities at December 31, 2023 $ 43 $ 29 $ 6 $ 7 Contract liabilities at March 31, 2024 30 20 5 5 Revenue recognized during the three months ended March 31, 2024 that was included in the contract liability balance at December 31, 2023 25 11 6 7 Contract liabilities at December 31, 2022 $ 34 $ 23 $ 5 $ 6 Contract liabilities at March 31, 2023 46 35 5 5 Revenue recognized during the three months ended March 31, 2023 that was included in the contract liability balance at December 31, 2022 17 6 5 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	3 Months Ended
	Mar. 31, 2024
Business Combinations [Abstract]
Mergers, Acquisitions and Dispositions Disclosures	8. Acquisitions, Developments and Divestitures Acquisitions (PPL) Acquisition of Narragansett Electric On May 25, 2022, PPL Rhode Island Holdings acquired 100% of the outstanding shares of common stock of Narragansett Electric from National Grid USA, a subsidiary of National Grid plc (the Acquisition) for approximately $3.8 billion. Following the closing of the Acquisition, Narragansett Electric provides services doing business under the name Rhode Island Energy (RIE). In connection with the Acquisition, National Grid USA Service Company, Inc., National Grid USA and Narragansett Electric have entered into a transition services agreement (TSA), pursuant to which the National Grid entities have 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 certain aspects have been extended to the third quarter of 2024. TSA costs of $48 million and $58 million were incurred during the three months ended March 31, 2024 and 2023. Commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island As a condition to the Acquisition, PPL made certain commitments to the Rhode Island Division of Public Utilities and Carriers and the Attorney General of the State of Rhode Island. See Note 9 in PPL's 2023 Form 10-K for a complete listing of those commitments. PPL incurred the following expenses related to some of the remaining commitments: • RIE will forgo potential recovery of any and all transition costs which includes (1) the installation of certain information technology systems; (2) modification and enhancements to physical facilities in Rhode Island; and (3) incurring costs related to severance payments, communications and branding changes, and other transition related costs. These costs, which are being expensed as incurred, were $81 million and $54 million for the three months ended March 31, 2024 and 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 $1 million and $2 million for the three months ended March 31, 2024 and 2023. Developments (PPL, LG&E and KU) Mill Creek Unit 5 Construction In December 2022, LG&E and KU filed a Certificate of Public Convenience and Necessity (CPCN) with the KPSC requesting approval to construct a 640 MW net summer rating Natural Gas Combined Cycle (NGCC) combustion turbine at LG&E’s Mill Creek Generating Station. In November 2023, the KPSC issued an order approving the request as well as the requested AFUDC accounting treatment for associated financing costs relating to the NGCC. The new NGCC facility will be jointly owned by LG&E (31%) and KU (69%). In February 2024, LG&E and KU entered into agreements to begin construction. Total project costs are estimated at approximately $1.0 billion, including AFUDC. Commercial operation of the facility is anticipated to begin mid-2027. See Note 7 in PPL's 2023 Form 10-K for additional information on the CPCN filing.

Other Income (Expense) - net

Other Income (Expense) - net	3 Months Ended
	Mar. 31, 2024
Other Income (Expense) Net [Line Items]
Other Income (Expense) - net	12. Other Income (Expense) - net (PPL) The details of "Other Income (Expense) - net" for the periods ended March 31, were: Three Months 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 8 $ 17 Interest income 9 9 AFUDC - equity component 9 6 Charitable contributions (2) (1) Miscellaneous (2) (1) Other Income (Expense) - net $ 22 $ 30 (PPL Electric) The details of "Other Income (Expense) - net" for the periods ended March 31, were: Three Months 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 4 $ 5 Interest income 1 4 AFUDC - equity component 5 4 Charitable contributions (1) (1) Other Income (Expense) - net $ 9 $ 12

New Accounting Guidance Pending

New Accounting Guidance Pending Adoption	3 Months Ended
	Mar. 31, 2024
Accounting Policies [Abstract]
Accounting Standards Update and Change in Accounting Principle	17. New Accounting Guidance Pending Adoption (All Registrants) Improvements to Reportable Segment Disclosures In November 2023, the FASB issued ASU 2023-07 which improves reportable segment disclosure requirements, primarily through enhanced disclosures about segment expenses. The standard also requires public entities to disclose the title and position of the Chief Operating Decision Maker (CODM) and explain how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources. Disclosure of certain segment-related disclosures that previously were required only on an annual basis will be required in interim periods. In addition, public entities that have a single reportable segment are required to provide disclosures required by the new ASU and existing segment disclosure in Topic 280 (Segment Reporting). For public business entities, this guidance will be applied retrospectively to all prior periods presented in the financial statements and will be effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. Early adoption is permitted. The Registrants are currently assessing the impact of adopting this guidance. Improvements to Income Tax Disclosures In December 2023, the FASB issued ASU 2023-09 which requires public business entities to provide additional income tax disclosures including a disaggregated rate reconciliation as well as information on income taxes paid. For public business entities, this guidance will be applied on a prospective basis. Retrospective application is permitted. This guidance will be effective for annual periods beginning after December 15, 2024. Early adoption is permitted for annual financial statements that have not yet been issued or made available for issuance. The Registrants are currently assessing the impact of adopting this guidance.

Derivative Instruments and He_2

Derivative Instruments and Hedging Activities (Policies)	3 Months Ended
	Mar. 31, 2024
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivatives, Offsetting Fair Value Amounts, Policy	Net derivative positions on the balance sheets are not offset against the right to reclaim cash collateral (a receivable) or the obligation to return cash collateral (a payable) under master netting arrangements.

Adoption of Accounting Guidance

Adoption of Accounting Guidance (Tables)	3 Months Ended
	Mar. 31, 2024
Summary Of Significant Accounting Policies [Line Items]
Financing Receivable, Allowance for Credit Loss [Table Text Block]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement	The following provides a reconciliation of Cash, Cash Equivalents and Restricted Cash reported within the Balance Sheets that sum to the total of the same amounts shown on the Statements of Cash Flows: PPL March 31, December 31, Cash and cash equivalents $ 276 $ 331 Restricted cash - current (a) 45 1 Total Cash, Cash Equivalents and Restricted Cash $ 321 $ 332 (a) Bank deposits and other cash equivalents that are restricted by agreement or that have been clearly designated for a specific purpose are classified as restricted cash. On the Balance Sheets, the current portion of restricted cash is included in "Other current assets."

Segment and Related Informati_2

Segment and Related Information (Tables)	3 Months Ended
	Mar. 31, 2024
Segment Reporting [Abstract]
Segment and Related Information	Income Statement data for the segments and reconciliation to PPL's consolidated results for the periods ended March 31 are as follows: Three Months 2024 2023 Operating Revenues from external customers Kentucky Regulated $ 984 $ 960 Pennsylvania Regulated 770 891 Rhode Island Regulated 549 565 Corporate and Other 1 (1) Total $ 2,304 $ 2,415 Net Income (Loss) Kentucky Regulated $ 190 $ 166 Pennsylvania Regulated 149 138 Rhode Island Regulated 64 54 Corporate and Other (96) (73) Total $ 307 $ 285 The following provides Balance Sheet data for the segments and reconciliation to PPL's consolidated Balance Sheets as of: March 31, December 31, Assets Kentucky Regulated $ 17,074 $ 17,029 Pennsylvania Regulated 15,116 14,294 Rhode Island Regulated 6,614 6,515 Corporate and Other (a) 827 1,398 Total $ 39,631 $ 39,236 (a) Primarily consists of unallocated items, including cash, PP&E, goodwill and the elimination of inter-segment transactions.

Revenue from Contracts with C_2

Revenue from Contracts with Customers (Tables)	3 Months Ended
	Mar. 31, 2024
Revenue from Contracts with Customers [Line Items]
Disaggregation of Revenue [Table Text Block]	The following tables show revenues from contracts with customers disaggregated by customer class for the periods ended March 31. Three Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL 2024 PA Regulated $ 426 $ 106 $ 12 $ 13 $ — $ — $ 205 $ 762 KY Regulated 443 267 161 97 6 15 — 989 RI Regulated 261 78 4 161 — — 47 551 Corp and Other — — — 1 — — — 1 Total PPL $ 1,130 $ 451 $ 177 $ 272 $ 6 $ 15 $ 252 $ 2,303 2023 PA Regulated $ 537 $ 128 $ 20 $ 13 $ — $ — $ 192 $ 890 KY Regulated 443 274 164 60 7 11 — 959 RI Regulated 229 101 9 215 — — 45 599 Corp and Other — — — (1) — — — (1) Total PPL $ 1,209 $ 503 $ 193 $ 287 $ 7 $ 11 $ 237 $ 2,447 Three Months Residential Commercial Industrial Other (a) Wholesale - municipality Wholesale - other (b) Transmission Revenues from Contracts with Customers PPL Electric 2024 $ 426 $ 106 $ 12 $ 13 $ — $ — $ 205 $ 762 2023 $ 537 $ 128 $ 20 $ 13 $ — $ — $ 192 $ 890 LG&E 2024 $ 218 $ 138 $ 47 $ 52 $ — $ 22 $ — $ 477 2023 $ 241 $ 152 $ 49 $ 16 $ — $ 16 $ — $ 474 KU 2024 $ 225 $ 129 $ 114 $ 46 $ 6 $ 9 $ — $ 529 2023 $ 202 $ 123 $ 115 $ 44 $ 7 $ 7 $ — $ 498 (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 March 31. Three Months 2024 2023 PPL (a) $ 42 $ 21 PPL Electric (a) 28 10 LG&E 1 1 KU 1 — (a) 2024 includes amounts impaired related to PPL Electric's billing issues. See Note 6 for additional information.
Contract with Customer, Asset and Liability [Table Text Block]	The following table shows the balances and certain activity of contract liabilities resulting from contracts with customers. PPL PPL Electric LG&E KU Contract liabilities at December 31, 2023 $ 43 $ 29 $ 6 $ 7 Contract liabilities at March 31, 2024 30 20 5 5 Revenue recognized during the three months ended March 31, 2024 that was included in the contract liability balance at December 31, 2023 25 11 6 7 Contract liabilities at December 31, 2022 $ 34 $ 23 $ 5 $ 6 Contract liabilities at March 31, 2023 46 35 5 5 Revenue recognized during the three months ended March 31, 2023 that was included in the contract liability balance at December 31, 2022 17 6 5 6

Earnings Per Share (Tables)

Earnings Per Share (Tables)	3 Months Ended
	Mar. 31, 2024
Earnings Per Share [Abstract]
Basic and Diluted EPS Computations	Reconciliations of the amounts of income and shares of PPL common stock (in thousands) for the periods ended March 31 used in the EPS calculation are: Three Months 2024 2023 Income (Numerator) Net income attributable to PPL $ 307 $ 285 Less amounts allocated to participating securities — 1 Net income available to PPL common shareowners - Basic and Diluted $ 307 $ 284 Shares of Common Stock (Denominator) Weighted-average shares - Basic EPS 737,512 736,829 Add: Dilutive share-based payment awards (a) 1,308 869 Weighted-average shares - Diluted EPS 738,820 737,698 Basic and Diluted EPS Net Income available to PPL common shareowners $ 0.42 $ 0.39
Common Stock Issuances
Antidilutive Securities Excluded From Diluted EPS	For the periods ended March 31, the following shares (in thousands) were excluded from the computations of diluted EPS because the effect would have been antidilutive. Three Months 2024 2023 Stock-based compensation awards — 534

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2024
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows. (PPL) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 81 $ 76 Increase (decrease) due to: State income taxes, net of federal income tax benefit 17 22 Utility rate-making tax adjustments (a) (5) (5) Amortization of excess deferred federal and state income taxes (13) (12) Other 1 (2) Total increase (decrease) — 3 Total income tax expense (benefit) $ 81 $ 79 (a) Primarily consists of tax impacts of AFUDC equity and related depreciation across all PPL utilities and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.
PPL Electric Utilities Corp [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows. (PPL Electric) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 41 $ 38 Increase (decrease) due to: State income taxes, net of federal income tax benefit 14 14 Utility rate-making tax adjustments (a) (4) (4) Amortization of excess deferred federal and state income taxes (2) (2) Other (1) (1) Total increase (decrease) 7 7 Total income tax expense (benefit) $ 48 $ 45 (a) Primarily consists of tax impacts of AFUDC equity and related depreciation and flow through tax impacts of Pennsylvania utility ratemaking. Flow through occurs when the regulator excludes deferred tax expense or benefit from recoverable costs when determining income tax expense.
Louisville Gas And Electric Co [Member]
Income Taxes [Line Items]
Schedule of Effective Income Tax Rate Reconciliation	Reconciliations of income tax expense (benefit) for the periods ended March 31 are as follows. (LG&E) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 25 $ 23 Increase (decrease) due to: State income taxes, net of federal income tax benefit 4 4 Amortization of excess deferred federal and state income taxes (3) (3) Other (2) (1) Total increase (decrease) (1) — Total income tax expense (benefit) $ 24 $ 23
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 March 31 are as follows. (KU) Three Months 2024 2023 Federal income tax on Income Before Income Taxes at statutory tax rate - 21% $ 28 $ 23 Increase (decrease) due to: State income taxes, net of federal income tax benefit 5 4 Amortization of excess deferred federal and state income taxes (5) (4) Other (1) (1) Total increase (decrease) (1) (1) Total income tax expense (benefit) $ 27 $ 22

Utility Rate Regulation (Tables

Utility Rate Regulation (Tables)	3 Months Ended
	Mar. 31, 2024
Utility Rate Regulation [Line Items]
Regulatory Assets and Liabilities	The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric LG&E KU March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, Current Regulatory Assets: Rate adjustment mechanisms $ 129 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 15 14 — — — — — — Derivative instruments 29 51 — — — — — — Smart meter rider 6 6 6 6 — — — — Universal service rider 8 — 8 — — — — — Storm damage costs 33 12 33 12 — — — — Gas supply clause 4 — — — 4 — — — Fuel adjustment clause 12 4 — — 6 3 6 — Transmission service charge 36 43 26 31 — — — — Transmission formula rate 15 5 — — — — — — Distribution system improvement charge 8 7 8 7 — — — — Other 35 33 3 1 4 4 1 3 Total current regulatory assets $ 330 $ 293 $ 84 $ 57 $ 14 $ 7 $ 7 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 880 $ 887 $ 417 $ 417 $ 212 $ 217 $ 134 $ 136 Plant outage costs 36 38 — — 9 10 27 28 Net metering 123 112 — — — — — — Environmental cost recovery 97 99 — — — — — — Storm costs 96 97 — — 14 15 14 14 Unamortized loss on debt 22 22 3 3 10 10 7 7 Interest rate swaps 5 7 — — 5 7 — — Terminated interest rate swaps 56 58 — — 33 34 23 24 Accumulated cost of removal of utility plant 171 178 171 178 — — — — AROs 288 289 — — 76 76 212 213 Derivatives instruments 4 8 — — — — — — Other 81 79 1 — 29 26 18 17 Total noncurrent regulatory assets $ 1,859 $ 1,874 $ 592 $ 598 $ 388 $ 395 $ 435 $ 439 PPL PPL Electric LG&E KU March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, Current Regulatory Liabilities: Generation supply charge $ 64 $ 51 $ 64 $ 51 $ — $ — $ — $ — Tax Cuts and Jobs Act customer refund — 5 — 5 — — — — Act 129 compliance rider 12 15 12 15 — — — — Transmission formula rate 17 21 14 18 — — — — Rate adjustment mechanism 68 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — Other 37 23 — 2 2 1 6 1 Total current regulatory liabilities $ 223 $ 225 $ 90 $ 91 $ 2 $ 16 $ 6 $ 1 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,008 $ 996 $ — $ — $ 309 $ 306 $ 402 $ 399 Power purchase agreement - OVEC 16 19 — — 11 13 5 6 Net deferred taxes 1,960 1,977 759 763 454 459 517 523 Defined benefit plans 256 252 80 73 20 20 60 59 Terminated interest rate swaps 56 57 — — 28 29 28 28 Energy efficiency 18 5 — — — — — — Other 37 34 — — 2 — 4 3 Total noncurrent regulatory liabilities $ 3,351 $ 3,340 $ 839 $ 836 $ 824 $ 827 $ 1,016 $ 1,018

Financing Activities (Tables)

Financing Activities (Tables)	3 Months Ended
	Mar. 31, 2024
Debt Disclosure [Abstract]
Schedule of Line of Credit Facilities	The following credit facilities were in place at: March 31, 2024 December 31, 2023 Expiration Capacity Borrowed Letters of Unused Borrowed Letters of PPL PPL Capital Funding (a) Syndicated Credit Facility (b) Dec. 2028 $ 1,250 $ — $ 218 $ 1,032 $ — $ 390 Bilateral Credit Facility Feb. 2025 100 — — 100 — — Bilateral Credit Facility Feb. 2025 100 — 13 87 — 13 Total PPL Capital Funding Credit Facilities $ 1,450 $ — $ 231 $ 1,219 $ — $ 403 PPL Electric Syndicated Credit Facility Dec. 2028 $ 650 $ — $ 1 $ 649 $ — $ 511 Total PPL Electric Credit Facilities $ 650 $ — $ 1 $ 649 $ — $ 511 LG&E Syndicated Credit Facility Dec. 2028 $ 500 $ — $ 28 $ 472 $ — $ — Total LG&E Credit Facilities $ 500 $ — $ 28 $ 472 $ — $ — KU Syndicated Credit Facility Dec. 2028 $ 400 $ — $ 45 $ 355 $ — $ 93 Total KU Credit Facilities $ 400 $ — $ 45 $ 355 $ — $ 93 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) The PPL Capital Funding $1.25 billion syndicated credit facility includes a $400 million borrowing sublimit for RIE and a $850 million sublimit for PPL Capital Funding at March 31, 2024. RIE’s borrowing sublimit is adjustable, at the borrowers’ option, from $0 to $600 million, with the remaining balance of the $1.25 billion available under the facility allocated to PPL Capital Funding. At December 31, 2023, the borrowing sublimit for RIE was $250 million and a $1 billion sublimit for PPL Capital Funding. At March 31, 2024, PPL Capital Funding had $218 million commercial paper outstanding and RIE had no commercial paper outstanding. At December 31, 2023, PPL Capital Funding had $365 million commercial paper outstanding and RIE had $25 million commercial paper outstanding. RIE's obligations under the facility are not guaranteed by PPL. (c) Commercial paper issued reflects the undiscounted face value of the issuance.
Schedule of Short-term Debt	The following commercial paper programs were in place at: March 31, 2024 December 31, 2023 Weighted - Capacity Commercial Unused Weighted - Commercial PPL Capital Funding (a) (b) 5.51% $ 1,350 $ 218 $ 1,132 5.66% $ 365 RIE (b) 400 — 400 5.72% 25 PPL Electric 650 — 650 5.67% 510 LG&E 5.49% 500 28 472 — KU 5.49% 400 45 355 5.64% 93 Total $ 3,300 $ 291 $ 3,009 $ 993 (a) PPL Capital Funding's obligations are fully and unconditionally guaranteed by PPL. (b) Issuances under the PPL Capital Funding and RIE commercial paper programs are supported by the PPL Capital Funding syndicated credit facility, which has a total capacity of $1.25 billion. At March 31, 2024, the borrowing sublimits were $400 million for RIE and $850 million for PPL Capital Funding. At December 31, 2023, the borrowing sublimits under the facility were $250 million at RIE and $1 billion at PPL Capital Funding. PPL Capital Funding’s Commercial paper program is also backed by a separate bilateral credit facility for $100 million. (c) Commercial paper issued reflects the undiscounted face value of the issuance.

Defined Benefits (Tables)

Defined Benefits (Tables)	3 Months Ended
	Mar. 31, 2024
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule Of Net Periodic Defined Benefit Costs (Credits)	Following are the net periodic defined benefit costs (credits) of the plans sponsored by PPL and its subsidiaries for the periods ended March 31: Pension Benefits Three Months 2024 2023 PPL Service cost $ 9 $ 9 Interest cost 46 46 Expected return on plan assets (75) (78) Amortization of: Prior service cost 1 2 Actuarial loss 2 — Net periodic defined benefit costs (credits) $ (17) $ (21) Other Postretirement Benefits Three Months 2024 2023 PPL Service cost $ 1 $ 2 Interest cost 7 7 Expected return on plan assets (7) (8) Amortization of: Actuarial loss (1) (1) Net periodic defined benefit costs (credits) $ — $ —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2024
Commitments and Contingencies Disclosure [Abstract]
Guarantees	The table below details guarantees provided as of March 31, 2024. Exposure at March 31, 2024 Expiration PPL Indemnifications related to certain tax liabilities related to the sale of the U.K. utility business £ 50 (a) 2028 PPL guarantee of Safari payment obligations under certain sale/leaseback financing transactions related to the sale of Safari Holdings $ 121 (b) 2028 Indemnifications for losses suffered related to items not covered by Aspen Power's representation and warranty insurance associated with the sale of Safari Holdings 140 (c) 2028 LG&E and KU LG&E and KU obligation of shortfall related to OVEC (d) (a) PPL WPD Limited, a PPL indirect U.K. subsidiary, entered into a Tax Deed dated June 9, 2021, in which it agreed to a tax indemnity regarding certain potential tax liabilities of the entities sold with respect to periods prior to the completion of the sale, subject to customary exclusions and limitations. Because National Grid Holdings One plc, the buyer, agreed to purchase indemnity insurance, the amount of the cap on the indemnity for these liabilities is £1, except with respect to certain surrenders of tax losses, for which the amount of the cap on the indemnity is £50 million. (b) PPL guaranteed the payment obligations of Safari under certain sale/leaseback financing transactions executed by Safari. These guarantees will remain in place until Safari exercises its option to buy-out the projects under the sale/leaseback financings by the year 2028. Safari will indemnify PPL for any payments made by PPL or claims against PPL under the sale/leaseback transaction guarantees up to $25 million. (c) Aspen Power has obtained representation and warranty insurance, therefore, PPL generally has no liability for its representations and warranties under the agreement except for losses suffered related to items not covered. Pursuant to the agreement, expiration of these indemnifications range from 18 months to 6 years from the date of the closing of the transaction, and PPL’s aggregate liability for these claims will not exceed $140 million, pursuant to the agreement, subject to certain adjustments plus the support obligations provided by PPL under sale-leaseback financings. (d) Pursuant to the OVEC power purchase contract, LG&E and KU are obligated to pay for their share of OVEC's excess debt service, post-retirement, and decommissioning costs, as well as any shortfall from amounts included within a demand charge designed and expected to cover these costs over the term of the contract. PPL's proportionate share of OVEC's outstanding debt was $86 million at March 31, 2024, consisting of LG&E's share of $60 million and KU's share of $26 million. The maximum exposure and the expiration date of these potential obligations are not presently determinable. See "Energy Purchase Commitments" in Note 13 in PPL's, LG&E's and KU's 2023 Form 10-K for additional information on the OVEC power purchase contract.

Related Party Transactions (Tab

Related Party Transactions (Tables)	3 Months Ended
	Mar. 31, 2024
PPL Electric Utilities Corp [Member]
Related Party Transactions [Line Items]
Intercompany Support Cost Allocations	PPL Services and LKS charged the following amounts for the periods ended March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. Three Months 2024 2023 PPL Electric from PPL Services $ 56 $ 59 LG&E from LKS 29 32 LG&E from PPL Services 11 8 KU from LKS 38 41 KU from PPL Services 11 9
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 March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. Three Months 2024 2023 PPL Electric from PPL Services $ 56 $ 59 LG&E from LKS 29 32 LG&E from PPL Services 11 8 KU from LKS 38 41 KU from PPL Services 11 9
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 March 31, including amounts applied to accounts that are further distributed between capital and expense on the books of the recipients, based on methods that are believed to be reasonable. Three Months 2024 2023 PPL Electric from PPL Services $ 56 $ 59 LG&E from LKS 29 32 LG&E from PPL Services 11 8 KU from LKS 38 41 KU from PPL Services 11 9

Other Income (Expense) - net (T

Other Income (Expense) - net (Tables)	3 Months Ended
	Mar. 31, 2024
Other Income (Expense) Net [Line Items]
Schedule of Other Nonoperating Income (Expense)	The details of "Other Income (Expense) - net" for the periods ended March 31, were: Three Months 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 8 $ 17 Interest income 9 9 AFUDC - equity component 9 6 Charitable contributions (2) (1) Miscellaneous (2) (1) Other Income (Expense) - net $ 22 $ 30
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 March 31, were: Three Months 2024 2023 Defined benefit plans - non-service credits (Note 9) $ 4 $ 5 Interest income 1 4 AFUDC - equity component 5 4 Charitable contributions (1) (1) Other Income (Expense) - net $ 9 $ 12

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	3 Months Ended
	Mar. 31, 2024
Fair Value Disclosures [Abstract]
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis	The assets and liabilities measured at fair value were: March 31, 2024 December 31, 2023 Total Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 PPL Assets Cash and cash equivalents $ 276 $ 276 $ — $ — $ 331 $ 331 $ — $ — Restricted cash and cash equivalents (a) 45 45 — — 51 51 — — Total Cash, Cash Equivalents and Restricted Cash (b) 321 321 — — 382 382 — — Special use funds (a): Money market fund 2 2 — — 1 1 — — Commingled debt fund measured at NAV (c) 7 — — — 9 — — — Commingled equity fund measured at NAV (c) 7 — — — 8 — — — Total special use funds 16 2 — — 18 1 — — Price risk management assets (d): Gas contracts 1 — 1 — 1 — 1 — Total assets $ 338 $ 323 $ 1 $ — $ 401 $ 383 $ 1 $ — Liabilities Price risk management liabilities (d): Interest rate swaps $ 5 $ — $ 5 $ — $ 7 $ — $ 7 $ — Gas contracts 34 — 33 1 60 — 41 19 Total price risk management liabilities $ 39 $ — $ 38 $ 1 $ 67 $ — $ 48 $ 19 PPL Electric Assets Cash and cash equivalents $ 21 $ 21 $ — $ — $ 51 $ 51 $ — $ — Total assets $ 21 $ 21 $ — $ — $ 51 $ 51 $ — $ — LG&E Assets Cash and cash equivalents $ 8 $ 8 $ — $ — $ 18 $ 18 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 26 26 — — Total Cash, Cash Equivalents and Restricted Cash (b) 30 30 — — 44 44 — — Total assets $ 30 $ 30 $ — $ — $ 44 $ 44 $ — $ — Liabilities Price risk management liabilities: Interest rate swaps $ 5 $ — $ 5 $ — $ 7 $ — $ 7 $ — Total price risk management liabilities $ 5 $ — $ 5 $ — $ 7 $ — $ 7 $ — KU Assets Cash and cash equivalents $ 12 $ 12 $ — $ — $ 14 $ 14 $ — $ — Restricted cash and cash equivalents (a) 22 22 — — 24 24 — — Total Cash, Cash Equivalents and Restricted Cash (b) 34 34 — — 38 38 — — Total assets $ 34 $ 34 $ — $ — $ 38 $ 38 $ — $ — (a) Current portion is included in "Other current assets" and noncurrent portion is included in "Other noncurrent assets" on the Balance Sheets. (b) Total Cash, Cash Equivalents and Restricted Cash provides a reconciliation of these items reported within the Balance Sheets to the sum shown on the Statements of Cash Flows. (c) In accordance with accounting guidance, certain investments that are measured at fair value using net asset value per share (NAV), or its equivalent, have not been classified in the fair value hierarchy. The fair value amounts presented in the table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Balance Sheets. (d) Current portion is included in "Other current 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 three months ended March 31 is as follows: Gas Contracts 2024 Balance at beginning of period $ 19 Settlements (18) Balance at end of period $ 1
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. March 31, 2024 December 31, 2023 Carrying Fair Value Carrying Fair Value PPL $ 15,754 $ 15,016 $ 14,612 $ 14,031 PPL Electric 5,211 5,023 4,567 4,475 LG&E 2,469 2,344 2,469 2,369 KU 3,064 2,832 3,064 2,861 (a) Amounts are net of debt issuance costs.

Derivative Instruments and He_3

Derivative Instruments and Hedging Activities (Tables)	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Derivative Instruments And Hedging Activities [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	The following table presents the fair value and the location on the Balance Sheets of derivatives not designated as hedging instruments. March 31, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps (a) $ — $ 1 $ — $ 1 Gas contracts (a) 1 30 1 51 Total current 1 31 1 52 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps (a) — 4 — 6 Gas contracts (a) — 4 — 9 Total noncurrent — 8 — 15 Total derivatives $ 1 $ 39 $ 1 $ 67 (a) Current portion is included in "Other current assets" and "Other current liabilities" and noncurrent portion is included in "Other noncurrent assets" and "Other deferred credits and noncurrent liabilities" on the Balance Sheets. Excludes accrued interest, if applicable.
Derivative Instruments, Gain (Loss)	The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2024. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 179 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)	The following table presents the effect of cash flow hedge activity on the Statement of Income for the period ended March 31, 2023. Location and Amount of Gain (Loss) Recognized in Income on Hedging Relationships Three Months Interest Expense Total income and expense line items presented in the income statement in which the effect of cash flow hedges are recorded $ 164 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)
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 March 31, 2024 Derivatives PPL $ 1 $ — $ — $ 1 $ 39 $ — $ — $ 39 LG&E — — — — 5 — — 5 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7
Schedule of Derivatives Instruments Statements of Financial Performance and Financial Position, Location	The following tables present the pre-tax effect of derivative instruments recognized in income, OCI or regulatory assets and regulatory liabilities for the period ended March 31, 2024. Three Months Three Months Derivative Derivative Gain Location of Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — Interest expense $ (1) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Gas contracts Energy purchases $ (16) Total $ (16) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Interest rate swaps Regulatory assets - noncurrent $ 2 Gas contracts Regulatory assets - current 22 Regulatory assets - noncurrent 4 Total $ 28	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 March 31, 2023. Three Months Three Months Derivative Derivative Gain Location of Gain (Loss) Cash Flow Hedges: Interest rate swaps $ — Interest expense $ (1) Derivatives Not Designated as Location of Gain (Loss) Recognized in Three Months Interest rate swaps Interest expense $ — Gas contracts Energy purchases (2) Other income (expense) - net 1 Total $ (1) Derivatives Not Designated as Location of Gain (Loss) Recognized as Three Months Interest rate swaps Regulatory assets - noncurrent $ (1) Gas contracts Regulatory assets - current 28 Regulatory assets - noncurrent (7) Total $ 20
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. March 31, 2024 December 31, 2023 Assets Liabilities Assets Liabilities Current: Price Risk Management Assets/Liabilities: Interest rate swaps $ — $ 1 $ — $ 1 Total current — 1 — 1 Noncurrent: Price Risk Management Assets/Liabilities: Interest rate swaps — 4 — 6 Total noncurrent — 4 — 6 Total derivatives $ — $ 5 $ — $ 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 March 31, 2024. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Interest rate swaps Interest expense $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Interest rate swaps Regulatory assets - noncurrent $ 2	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 March 31, 2023. Location of Gain (Loss) Recognized in Derivative Instruments Income on Derivatives Three Months Interest rate swaps Interest expense $ — Location of Gain (Loss) Recognized in Derivative Instruments Regulatory Assets Three Months Interest rate swaps Regulatory assets - noncurrent $ (1)
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 March 31, 2024 Derivatives PPL $ 1 $ — $ — $ 1 $ 39 $ — $ — $ 39 LG&E — — — — 5 — — 5 Assets Liabilities Eligible for Offset Eligible for Offset Gross Derivative Cash Net Gross Derivative Cash Net December 31, 2023 Derivatives PPL $ 1 $ — $ — $ 1 $ 67 $ — $ — $ 67 LG&E — — — — 7 — — 7

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	3 Months Ended
	Mar. 31, 2024
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 2 1 1 Obligations settled (5) (2) (3) Other 1 — — Balance at March 31, 2024 $ 156 $ 84 $ 64
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 2 1 1 Obligations settled (5) (2) (3) Other 1 — — Balance at March 31, 2024 $ 156 $ 84 $ 64
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation Roll Forward	The changes in the carrying amounts of AROs were as follows. PPL LG&E KU Balance at December 31, 2023 $ 158 $ 85 $ 66 Accretion 2 1 1 Obligations settled (5) (2) (3) Other 1 — — Balance at March 31, 2024 $ 156 $ 84 $ 64

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Income (Loss) (Tables)	3 Months Ended
	Mar. 31, 2024
Accumulated Other Comprehensive Income (Loss) [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	The after-tax changes in AOCI by component for the periods ended March 31 were as follows. Unrealized gains (losses) Defined benefit plans Equity Prior Actuarial Total PPL December 31, 2023 $ 6 $ 3 $ (4) $ (168) $ (163) Amounts arising during the period — 1 — — 1 Reclassifications from AOCI 1 — — — 1 Net OCI during the period 1 1 — — 2 March 31, 2024 $ 7 $ 4 $ (4) $ (168) $ (161) December 31, 2022 $ 3 $ 2 $ (5) $ (124) $ (124) Amounts arising during the period — 1 — — 1 Reclassifications from AOCI 1 — — (1) — Net OCI during the period 1 1 — (1) 1 March 31, 2023 $ 4 $ 3 $ (5) $ (125) $ (123)
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 March 31. Three Months Affected Line Item on the Details about AOCI 2024 2023 Statements of Income Qualifying derivatives Interest rate swaps $ (1) $ (1) Interest Expense Total Pre-tax (1) (1) Income Taxes — — Total After-tax (1) (1) Defined benefit plans Net actuarial loss (a) — 1 Total Pre-tax — 1 Income Taxes — — Total After-tax — 1 Total reclassifications during the period $ (1) $ — (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	Mar. 31, 2024	Dec. 31, 2023
Summary Of Significant Accounting Policies [Line Items]
Goodwill	$ 2,247	$ 2,247
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	276	331
Restricted Cash, Current	45	1
Cash, Cash Equivalents and Restricted Cash	321	332
PPL Electric Utilities Corp [Member]
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	21	51
Louisville Gas And Electric Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Goodwill	389	389
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	8	18
Kentucky Utilities Co [Member]
Summary Of Significant Accounting Policies [Line Items]
Goodwill	607	607
Reconciliation of Cash, Cash Equivalents and Restricted Cash from the Balance Sheet to Cash Flow Statement [Line Items]
Cash and cash equivalents	$ 12	$ 14

Segment and Related Informati_3

Segment and Related Information (Details) $ in Millions		3 Months Ended
		Mar. 31, 2024 USD ($) Integer		Mar. 31, 2023 USD ($)	Dec. 31, 2023 USD ($)
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 2,304		$ 2,415
Net income (loss)		307		285
Balance Sheet Data [Abstract]
Assets		39,631			$ 39,236
Segment (Numeric) [Abstract]
Goodwill		$ 2,247			2,247
Number of Reportable Segments | Integer		3
Kentucky Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 984		960
Net income (loss)		190		166
Balance Sheet Data [Abstract]
Assets		17,074			17,029
Pennsylvania Regulated [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		770		891
Net income (loss)		149		138
Balance Sheet Data [Abstract]
Assets		15,116			14,294
Corporate and Other [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		1		(1)
Net income (loss)		(96)		(73)
Balance Sheet Data [Abstract]
Assets		827			1,398
Rhode Island Regulated
Income Statement Data [Abstract]
Operating Revenues from external customers		549		565
Net income (loss)		64		54
Balance Sheet Data [Abstract]
Assets		6,614			6,515
PPL Electric Utilities Corp [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		770		891
Net income (loss)	[1]	149		138
Balance Sheet Data [Abstract]
Assets		$ 15,116			14,294
Segment (Numeric) [Abstract]
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		2
Louisville Gas And Electric Co [Member]
Income Statement Data [Abstract]
Operating Revenues from external customers		$ 476		474
Net income (loss)		93	[2]	86
Balance Sheet Data [Abstract]
Assets		7,798			7,753
Segment (Numeric) [Abstract]
Goodwill		$ 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		$ 525		499
Net income (loss)	[3]	108		$ 88
Balance Sheet Data [Abstract]
Assets		9,773			9,714
Segment (Numeric) [Abstract]
Goodwill		$ 607			$ 607
Number of Reportable Segments | Integer		1
Number of Operating Segments | Integer		1
[1] Net income equals comprehensive income. Net income equals comprehensive income. Net income equals comprehensive income.

Revenue from Contracts with C_3

Revenue from Contracts with Customers (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023	Dec. 31, 2022
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	$ 2,304	$ 2,415
Alternative Revenue Programs	7	36
Other Revenue	(8)	(4)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	2,303	2,447
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	42	21
Contract with Customer, Liability	30	46	$ 43	$ 34
Contract with Customer, Liability, Revenue Recognized	25	17
Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	1,130	1,209
Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	451	503
Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	177	193
Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	272	287
Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	7
Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	15	11
Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	252	237
Pennsylvania Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	770	891
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	762	890
Pennsylvania Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	426	537
Pennsylvania Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	106	128
Pennsylvania Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	12	20
Pennsylvania Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	13	13
Pennsylvania Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Pennsylvania Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Pennsylvania Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	205	192
Kentucky Regulated [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	984	960
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	989	959
Kentucky Regulated [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	443	443
Kentucky Regulated [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	267	274
Kentucky Regulated [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	161	164
Kentucky Regulated [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	97	60
Kentucky Regulated [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	7
Kentucky Regulated [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	15	11
Kentucky Regulated [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	1	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	1	(1)
Corporate and Other [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	1	(1)
Corporate and Other [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Corporate and Other [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Rhode Island Regulated
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	549	565
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	551	599
Rhode Island Regulated | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	261	229
Rhode Island Regulated | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	78	101
Rhode Island Regulated | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	4	9
Rhode Island Regulated | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	161	215
Rhode Island Regulated | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Rhode Island Regulated | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Rhode Island Regulated | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	47	45
PPL Electric Utilities Corp [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	770	891
Alternative Revenue Programs	(3)	1
Other Revenue	(5)	(2)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	762	890
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	28	10
Contract with Customer, Liability	20	35	29	23
Contract with Customer, Liability, Revenue Recognized	11	6
PPL Electric Utilities Corp [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	426	537
PPL Electric Utilities Corp [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	106	128
PPL Electric Utilities Corp [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	12	20
PPL Electric Utilities Corp [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	13	13
PPL Electric Utilities Corp [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
PPL Electric Utilities Corp [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
PPL Electric Utilities Corp [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	205	192
Louisville Gas And Electric Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	476	474
Alternative Revenue Programs	2	1
Other Revenue	(1)	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	477	474
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	1
Contract with Customer, Liability	5	5	6	5
Contract with Customer, Liability, Revenue Recognized	6	5
Louisville Gas And Electric Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	218	241
Louisville Gas And Electric Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	138	152
Louisville Gas And Electric Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	47	49
Louisville Gas And Electric Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	52	16
Louisville Gas And Electric Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Louisville Gas And Electric Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	22	16
Louisville Gas And Electric Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	0	0
Kentucky Utilities Co [Member]
Reconciliation of Revenue from Contracts with Customers [Abstract]
Operating Revenues	525	499
Alternative Revenue Programs	5	0
Other Revenue	(1)	(1)
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	529	498
Contract with Customer, Asset and Liability [Abstract]
Accounts Receivable, Credit Loss Expense (Reversal)	1	0
Contract with Customer, Liability	5	5	$ 7	$ 6
Contract with Customer, Liability, Revenue Recognized	7	6
Kentucky Utilities Co [Member] | Residential [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	225	202
Kentucky Utilities Co [Member] | Commercial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	129	123
Kentucky Utilities Co [Member] | Industrial [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	114	115
Kentucky Utilities Co [Member] | Other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	46	44
Kentucky Utilities Co [Member] | Wholesale - municipal [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	6	7
Kentucky Utilities Co [Member] | Wholesale - other [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	9	7
Kentucky Utilities Co [Member] | Transmission [Member]
Disaggregation of Revenue [Abstract]
Revenues from Contracts with Customers	$ 0	$ 0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Income (Numerator) [Abstract]
Net income (loss)	$ 307	$ 285
Less amounts allocated to participating securities	0	1
Net Income (Loss) Available to Common Stockholders, Basic	307	284
Net income (loss) available to PPL common shareowners - Diluted	$ 307	$ 284
Shares of Common Stock (Denominator) [Abstract]
Weighted-average shares - Basic EPS (in shares)	737,512	736,829
Add incremental non-participating securities: [Abstract]
Share-based payment awards (in shares)	1,308	869
Weighted-average shares - Diluted EPS (in shares)	738,820	737,698
Income (Loss) from Continuing Operations after income taxes, Diluted	$ 0.42	$ 0.39
Income (Loss) from Continuing Operations After Income Taxes, Basic	0.42	0.39
Basic EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	0.42	0.39
Diluted EPS - Available to PPL common shareowners: [Abstract]
Net Income Available to PPL common shareowners (in dollars per share)	$ 0.42	$ 0.39
Stock Options [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Shares excluded from the computations of diluted EPS	0	534

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	$ 81	$ 76
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	17	22
Depreciation and other items not normalized	(5)	(5)
Amortization of excess deferred income taxes	(13)	(12)
Other	1	(2)
Total increase (decrease)	0	3
Total income tax expense (benefit)	81	79
PPL Electric Utilities Corp [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	41	38
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	14	14
Depreciation and other items not normalized	(4)	(4)
Amortization of excess deferred income taxes	(2)	(2)
Other	(1)	(1)
Total increase (decrease)	7	7
Total income tax expense (benefit)	48	45
Louisville Gas And Electric Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	25	23
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	4	4
Amortization of excess deferred income taxes	(3)	(3)
Other	(2)	(1)
Total increase (decrease)	(1)	0
Total income tax expense (benefit)	24	23
Kentucky Utilities Co [Member]
Reconciliation of Income Tax Expense [Abstract]
Federal income tax on Income Before Income Taxes at statutory tax rate	28	23
Increase (decrease) due to: [Abstract]
State income taxes, net of federal income tax benefit	5	4
Amortization of excess deferred income taxes	(5)	(4)
Other	(1)	(1)
Total increase (decrease)	(1)	(1)
Total income tax expense (benefit)	$ 27	$ 22

Utility Rate Regulation - Regul

Utility Rate Regulation - Regulatory Assets (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Regulatory Assets [Line Items]
Current regulatory assets	$ 330	$ 293
Noncurrent regulatory assets	1,859	1,874
Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	36	38
Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	0
Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	6
Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	15	5
Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	36	43
Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	880	887
Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	96	97
Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	22	22
Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	5	7
Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	56	58
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	171	178
Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	288	289
Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	33	12
Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	12	4
Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	123	112
Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	129	118
Derivative Instruments [Member]
Regulatory Assets [Line Items]
Current regulatory assets	29	51
Noncurrent regulatory assets	4	8
Renewable energy certificates
Regulatory Assets [Line Items]
Current regulatory assets	15	14
Universal Service Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	8	0
Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	7
Other
Regulatory Assets [Line Items]
Current regulatory assets	35	33
Noncurrent regulatory assets	81	79
Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	97	99
PPL Electric Utilities Corp [Member]
Regulatory Assets [Line Items]
Current regulatory assets	84	57
Noncurrent regulatory assets	592	598
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	6	6
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	26	31
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	417	417
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	3	3
PPL Electric Utilities Corp [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	171	178
PPL Electric Utilities Corp [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	33	12
PPL Electric Utilities Corp [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
PPL Electric Utilities Corp [Member] | 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	8	0
PPL Electric Utilities Corp [Member] | Distribution System Improvement Charge
Regulatory Assets [Line Items]
Current regulatory assets	8	7
PPL Electric Utilities Corp [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	3	1
Noncurrent regulatory assets	1	0
PPL Electric Utilities Corp [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	14	7
Noncurrent regulatory assets	388	395
Louisville Gas And Electric Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	9	10
Louisville Gas And Electric Co [Member] | Gas supply clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	4	0
Louisville Gas And Electric Co [Member] | Smart Meter Rider [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Transmission Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	212	217
Louisville Gas And Electric Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	14	15
Louisville Gas And Electric Co [Member] | Unamortized Loss On Debt [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	10	10
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	5	7
Louisville Gas And Electric Co [Member] | Terminated Interest Rate Swaps [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	33	34
Louisville Gas And Electric Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	76	76
Louisville Gas And Electric Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	3
Louisville Gas And Electric Co [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Louisville Gas And Electric Co [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Louisville Gas And Electric Co [Member] | 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
Louisville Gas And Electric Co [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	4	4
Noncurrent regulatory assets	29	26
Louisville Gas And Electric Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member]
Regulatory Assets [Line Items]
Current regulatory assets	7	3
Noncurrent regulatory assets	435	439
Kentucky Utilities Co [Member] | Plant outage costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	27	28
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 Formula Rate [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Transmission Service Charge [Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	134	136
Kentucky Utilities Co [Member] | Storm Costs [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	14	14
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	23	24
Kentucky Utilities Co [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Asset Retirement Obligations [Member]
Regulatory Assets [Line Items]
Noncurrent regulatory assets	212	213
Kentucky Utilities Co [Member] | Storm Damage costs[Member]
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | Fuel adjustment clause [Member]
Regulatory Assets [Line Items]
Current regulatory assets	6	0
Kentucky Utilities Co [Member] | Net metering
Regulatory Assets [Line Items]
Noncurrent regulatory assets	0	0
Kentucky Utilities Co [Member] | Rate adjustment mechanism
Regulatory Assets [Line Items]
Current regulatory assets	0	0
Kentucky Utilities Co [Member] | 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
Kentucky Utilities Co [Member] | Other
Regulatory Assets [Line Items]
Current regulatory assets	1	3
Noncurrent regulatory assets	18	17
Kentucky Utilities Co [Member] | Environmental cost recovery
Regulatory Assets [Line Items]
Noncurrent regulatory assets	$ 0	$ 0

Utility Rate Regulation - Reg_2

Utility Rate Regulation - Regulatory Liabilities (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Dec. 31, 2023
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 223	$ 225
Noncurrent regulatory liabilities	$ 3,351	3,340
Utility Rate Regulation	6. Utility Rate Regulation (All Registrants) The following table provides information about the regulatory assets and liabilities of cost-based rate-regulated utility operations. PPL PPL Electric LG&E KU March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, Current Regulatory Assets: Rate adjustment mechanisms $ 129 $ 118 $ — $ — $ — $ — $ — $ — Renewable energy certificates 15 14 — — — — — — Derivative instruments 29 51 — — — — — — Smart meter rider 6 6 6 6 — — — — Universal service rider 8 — 8 — — — — — Storm damage costs 33 12 33 12 — — — — Gas supply clause 4 — — — 4 — — — Fuel adjustment clause 12 4 — — 6 3 6 — Transmission service charge 36 43 26 31 — — — — Transmission formula rate 15 5 — — — — — — Distribution system improvement charge 8 7 8 7 — — — — Other 35 33 3 1 4 4 1 3 Total current regulatory assets $ 330 $ 293 $ 84 $ 57 $ 14 $ 7 $ 7 $ 3 Noncurrent Regulatory Assets: Defined benefit plans $ 880 $ 887 $ 417 $ 417 $ 212 $ 217 $ 134 $ 136 Plant outage costs 36 38 — — 9 10 27 28 Net metering 123 112 — — — — — — Environmental cost recovery 97 99 — — — — — — Storm costs 96 97 — — 14 15 14 14 Unamortized loss on debt 22 22 3 3 10 10 7 7 Interest rate swaps 5 7 — — 5 7 — — Terminated interest rate swaps 56 58 — — 33 34 23 24 Accumulated cost of removal of utility plant 171 178 171 178 — — — — AROs 288 289 — — 76 76 212 213 Derivatives instruments 4 8 — — — — — — Other 81 79 1 — 29 26 18 17 Total noncurrent regulatory assets $ 1,859 $ 1,874 $ 592 $ 598 $ 388 $ 395 $ 435 $ 439 PPL PPL Electric LG&E KU March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, March 31, 2024 December 31, Current Regulatory Liabilities: Generation supply charge $ 64 $ 51 $ 64 $ 51 $ — $ — $ — $ — Tax Cuts and Jobs Act customer refund — 5 — 5 — — — — Act 129 compliance rider 12 15 12 15 — — — — Transmission formula rate 17 21 14 18 — — — — Rate adjustment mechanism 68 72 — — — — — — Energy efficiency 25 23 — — — — — — Gas supply clause — 15 — — — 15 — — Other 37 23 — 2 2 1 6 1 Total current regulatory liabilities $ 223 $ 225 $ 90 $ 91 $ 2 $ 16 $ 6 $ 1 Noncurrent Regulatory Liabilities: Accumulated cost of removal of utility plant $ 1,008 $ 996 $ — $ — $ 309 $ 306 $ 402 $ 399 Power purchase agreement - OVEC 16 19 — — 11 13 5 6 Net deferred taxes 1,960 1,977 759 763 454 459 517 523 Defined benefit plans 256 252 80 73 20 20 60 59 Terminated interest rate swaps 56 57 — — 28 29 28 28 Energy efficiency 18 5 — — — — — — Other 37 34 — — 2 — 4 3 Total noncurrent regulatory liabilities $ 3,351 $ 3,340 $ 839 $ 836 $ 824 $ 827 $ 1,016 $ 1,018 Regulatory Matters Rhode Island Activities (PPL) Rate Case Proceedings Pursuant to Report and Order No. 23823 issued May 5, 2020, the RIPUC approved the terms of an Amended Settlement Agreement (ASA), reflecting an allowed return on equity (ROE) rate of 9.275% based on a common equity ratio of approximately 51%. RIE is currently in year six of the multi-year rate plan (Rate Plan). On June 30, 2021, the Rhode Island Division of Public Utilities and Carriers consented to an open-ended extension of the term of the Rate Plan. Pursuant to the settlement with the Rhode Island Office of the Attorney General in connection with the acquisition of RIE by PPL, RIE currently does not anticipate filing a new base rate case before October 1, 2025. Pursuant to the open-ended extension, the Rate Year 3 level of base distribution rates under ASA will remain in effect and RIE will continue to operate under the current Rate Plan until a new Rate Plan is approved by the RIPUC. The ASA includes additional provisions, including (i) an Electric Transportation Initiative (the ET Initiative) to facilitate the growth of Electric Vehicle (EV) adoption and scaling of the market for EV charging equipment to advance Rhode Island's zero emission vehicles and greenhouse gas emissions policy goals, (ii) two energy storage demonstration projects, which are online and fully connected, (iii) a performance incentive for System Efficiency: Annual Megawatt Capacity Savings, which sunset in 2021 and is a tracking and reporting only metric, and (iv) several additional metrics for tracking and reporting purposes only. The RIPUC discussed the ET Initiative at an Open Meeting on August 30, 2022, advising RIE to seek RIPUC authorization to continue the ET Initiative and/or to alter any of the targets established in the ASA for Rate Year 5 and beyond. No votes or official rulings were taken; however, based on this feedback, RIE paused the ET programs in Rate Year 5. Advanced Metering Functionality (AMF) In 2021, RIE filed its Updated AMF Business Case and Grid Modernization Plan (GMP) with the RIPUC in accordance with the ASA approved by the RIPUC in August 2018, and which, among other things, sought approval to deploy smart meters throughout the service territory. After PPL completed the acquisition of RIE, RIE filed a new AMF Business Case with the RIPUC in 2022, consisting of a detailed proposal for full-scale deployment of AMF across its electric service territory. On September 27, 2023, the RIPUC unanimously approved RIE to deploy an AMF-based metering system for the electric distribution business. RIE is authorized to seek recovery of the approved capital investment through the ISR process with an overall multi-year cap on recovery at approximately $153 million, subject to certain terms, conditions and limitations with respect to the potential offsets and recoverability of certain costs. RIE is required to continue spending, even if above the recovery cap, until it achieves the functionalities outlined in the AMF Business Case. RIE filed with the RIPUC (i) an updated electric Service Quality Plan on December 27, 2023 for RIPUC approval and (ii) additional compliance tariff provisions regarding recovery and updated cost schedules to reflect the RIPUC's decision on December 22, 2023 for RIPUC approval. RIE cannot predict the outcome of these matters. Grid Modernization RIE filed a new GMP with the RIPUC on December 30, 2022. The new GMP filing consists of a holistic suite of grid modernization investments that will provide RIE with the tools and capability to manage the electric distribution system more granularly considering a range of distributed energy resources adoption levels, accelerated by Rhode Island's climate mandates, while at the same time maintaining a safe and reliable electric distribution system. The GMP is an informational guidance document that supports the grid modernization investments to be proposed in future electric ISR plans. Consequently, RIE did not request approval from the RIPUC for any specific investments or seek cost recovery as part of the GMP; rather, RIE requested that the RIPUC issues an order affirming RIE's compliance with its obligation to file a GMP that meets the requirements of the ASA. The RIPUC held a status conference on October 26, 2023, to discuss the scope of the RIPUC’s review of the GMP and its potential impact future electric ISR plans. RIE cannot predict the outcome of this matter. Petition for Deferral of Credit Card Fees On January 31, 2024, RIE filed a petition to request approval to recognize regulatory assets related to the credit card, debit card, and related fees (Electronic Transaction Fees) that RIE has waived and will continue to waive on a going forward basis pursuant to the RIPUC orders in RIPUC Docket No. 5022 related to COVID-19 impacts. If approved, RIE plans to include a proposal as part of its next base distribution rate case for the amortization/recovery of the regulatory assets and to include future Electronic Transaction Fees in base distribution rates. The Rhode Island Division of Public Utilities and Carriers (the Division) and Intervenor testimony is due two weeks following the filing of RIE's Revised 2022 Earnings Reports, which RIE intends to file in the second quarter of 2024. RIE's rebuttal testimony is due two weeks following the Division's filing of its testimony. No hearings have been scheduled at this time. RIE simultaneously filed a Notice of Withdrawal of its April 2021 petition to create regulatory assets for COVID-19 related bad debt expense and the lost revenue from unassessed late payment charges pending in Docket No. 5154. RIE is continuing to evaluate these other COVID-19 related costs and intends to reserve its rights to file for recovery of these costs in the future. RIE cannot predict the outcome of this matter. FY 2023 Gas Infrastructure, Safety and Reliability (ISR) Plan At an Open Meeting on March 29, 2022, the RIPUC conditionally approved RIE's FY 2023 Gas ISR Plan and associated revenue requirement, subject to further review regarding RIE's Proactive Main Replacement Program and its decision to reconstruct and purchase heating and pressure regulation equipment located at RIE's Wampanoag and Tiverton take stations. In response to RIPUC direction, RIE filed testimony with the RIPUC on May 16, 2022 regarding its replacement of heating and pressure regulation facilities at the Wampanoag and Tiverton take stations and addressing: (i) a cost-benefit analysis arising from RIE's decision to take ownership of the reconstructed take station equipment; (ii) the potential that the benefits derived from the reconstruction and ownership transfer of the take station equipment will not be realized due to the future use of hydrogen or abandonment of the gas system; and (iii) the depreciation and accounting treatment of the reconstructed take station equipment. T he RIPUC has not taken any action to date on this issue, including in its recent action on the FY 2025 Gas ISR Plan. FY 2024 Gas ISR Plan At an Open Meeting on March 29, 2023, the RIPUC approved RIE's FY 2024 Gas ISR Plan with an adjustment to the budget for the Proactive Main Replacement Program category resulting in a total approved FY 2024 Gas ISR Plan of $163 million for capital investment spend. On March 31, 2023, the RIPUC approved RIE's March 30, 2023 compliance filing for rates effective April 1, 2023. Certain open issues regarding the Gas ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Gas ISR Plan, have been resolved in connection with the approval of the FY 2025 Gas ISR Plan, as discussed below. FY 2025 Gas ISR Plan On December 22, 2023, RIE filed its FY 2025 Gas ISR Plan with the RIPUC with a budget that includes $185 million of capital investment spend, plus up to an additional $11 million of contingency plan spend in light of the Pipeline and Hazardous Materials Safety Administration’s potential enactment of regulations during FY 2025 that, if enacted, would significantly alter RIE's leak detection and repair obligations under such regulations. RIE also filed its proposed gas ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with a total approved FY 2025 Gas ISR Plan of $180 million of which $168 million is for capital investment spend and $12 million spend for paving costs as operations and maintenance (O&M), p lus the potential additional $11 million available if the above-mentioned regulations are implemented by the Pipeline and Hazardous Materials Safety Administration. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. FY 2024 Electric ISR Plan The RIPUC held hearings in March 2023, and on March 29, 2023, approved RIE's FY 2024 Electric ISR Plan, as supplemented, with modifications to the proposed capital investment spend, resulting in a total approved FY 2024 Electric ISR Plan of $112 million for capital investment spend, $14 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 31, 2023, the RIPUC approved RIE's compliance filing for rates effective April 1, 2023. Certain open issues regarding the Electric ISR Plan budgetary and reconciliation framework, raised in connection with the FY 2024 Electric ISR Plan, have been resolved in connection with the approval of the FY 2025 Electric ISR plan, as discussed below. FY 2025 Electric ISR Plan On December 21, 2023, RIE filed its FY 2025 Electric ISR Plan with the RIPUC with a budget that includes $141 million of capital investment spend, $13 million of vegetation O&M spend and $1 million of Other O&M spend. RIE also filed its proposed electric ISR plan budgetary and reconciliation framework, addressing issues raised in connection with its FY 2024 submission, with its FY 2025 ISR Plan. The RIPUC held hearings in March 2024, and on March 26, 2024, approved the plan, including the proposed budgetary and reconciliation framework, with modifications to the proposed capital investment spend, resulting in a total approved FY 2025 Electric ISR Plan of $132 million for capital investment spend, $13 million for vegetation management O&M spend, and $1 million for Other O&M spend. On March 28, 2024, the RIPUC approved RIE's compliance filing for rates effective April 1, 2024. Kentucky Activities (PPL, LG&E and KU) KPSC Investigation Related to Winter Storm Elliott On December 22, 2023, the KPSC initiated an investigation into the practices of LG&E and KU regarding the provision of electric service from December 23, 2022 through December 25, 2022, during a period of extreme temperatures during Winter Storm Elliott. The investigation is the result of LG&E's and KU's need to implement brief service interruptions to approximately 55,000 customers during this period. The purpose of the investigation is to supplement discovery and examination already completed through LG&E's and KU's CPCN proceedings, a legislative hearing completed in February 2023 and reports completed by the NERC and the FERC related to the issue. Additionally, the investigation will evaluate LG&E's and KU's actions taken, or planned to be taken, since Winter Storm Elliott that affect their ability to provide service during periods of variable weather and power system stress. LG&E and KU believe actions taken during the period under question were necessary and appropriate. Several parties have been granted intervenor status for the proceeding and a hearing on the matter is scheduled for May 23, 2024. LG&E and KU cannot predict the outcome of this matter, and an estimate of the impact, if any, cannot be determined, but LG&E and KU do not believe this matter will have a significant impact on their operations or financial condition. Pennsylvania Activities (PPL and PPL Electric) PAPUC investigation into billing issues On January 31, 2023, the PAPUC initiated an investigation focused on billing issues related to estimated, irregular bills and customer service concerns following customer complaints, which for many customers were driven by increased prices for electricity supply. Certain bills issued during the time period of December 20, 2022 through January 9, 2023 were estimated due to a technical issue that prevented PPL Electric from providing actual collected meter data to customer facing and other internal systems. Customers also reported difficulties accessing PPL Electric's website and contacting the customer service call center. The PAPUC’s Bureau of Investigation & Enforcement (I&E) has directed PPL Electric to respond to certain inquiries and document requests. PPL Electric submitted its responses to the information request and cooperated fully with the investigation. PPL Electric reached a Settlement Agreement with I&E on November 21, 2023. In the settlement, PPL Electric agreed to pay a civil penalty of $1 million, make certain remedial improvements to its billing systems and processes, and agreed to not seek recovery for extraordinary costs incurred in responding to or resulting from the billing event. On November 21, 2023, PPL Electric and I&E submitted a Joint Petition for Approval of Settlement to the PAPUC. On January 18, 2024, the PAPUC issued an Order requesting public comment prior to the PAPUC entering a Final Order on the petition. Comments were due on February 28, 2024, and comments were filed by the Office of Consumer Advocate, CAUSE-PA (low-income advocate), and individual customers. On March 19, 2024, PPL Electric filed reply comments. On April 25, 2024, the PAPUC announced at its public meeting that it would be issuing an order approving the Settlement Agreement with modifications. The modifications included converting the $1 million civil penalty to a $1 million donation to PPL Electric’s hardship fund, Operation HELP, and requiring PPL Electric to make various progress reports on efforts to remediate the billing issue. PPL Electric and I&E have 20 business days from the issuance of the PAPUC order to accept or reject the proposed modifications to the Settlement Agreement. The final approval of the Settlement Agreement is pending the issuance of the PAPUC's order and PPL Electric and I&E's decision on whether to accept the modifications . PPL Electric cannot predict the outcome of this matter. PPL Electric incurred costs related to the billing issues of $15 million and $3 million for the three-month periods ended March 31, 2024 and March 31, 2023. PPL Electric will not seek regulatory recovery of these costs. DSIC Petition On April 26, 2024, PPL Electric filed a Petition with the PAPUC requesting that the PAPUC waive PPL Electric’s DSIC cap of 5% of billed revenues and increase the maximum allowable DSIC to 9% for bills rendered on or after January 1, 2025. PPL Electric requested PAPUC approval no later than the PAPUC’s public meeting on December 5, 2024. 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 filed a petition for review of the FERC's May 18, 2023 order with the D.C. Circuit Court of Appeals and provided refunds in accordance with the FERC order on December 1, 2023. The FERC issued an order on LG&E and KU's compliance filing on November 16, 2023, and LG&E and KU filed a petition for review of this November 16, 2023 order on February 14, 2024. The proceedings at the D.C. Circuit Court of Appeals were held on abeyance to allow the FERC time to substantively address LG&E and KU's request for rehearing of the November 16 order. FERC issued the substantive order on rehearing on March 21, 2024. LG&E and KU filed an unopposed motion to lift the abeyance on April 24, 2024 and anticipate a resumption of activities with the D.C. Circuit Court of Appeal in May of 2024. LG&E and KU cannot predict the ultimate outcome of the proceedings or any other post decision process but do not expect the annual impact to have a material effect on their operations or financial condition. LG&E and KU currently receive recovery of certain waivers and credits primarily through base rates increases, provided, however, that increases associated with the FERC's May 18, 2023 order are expected to be subject to future rate proceedings. Recovery of Transmission Costs (PPL) Until December 2022, RIE's transmission facilities were operated in combination with the transmission facilities of National Grid USA's New England affiliates, Massachusetts Electric Company (MECO) and New England Power (NEP), as a single integrated system with NEP designated as the combined operator. As of January 1, 2023, RIE operates its own transmission facilities. NE-ISO allocates RIE's costs among transmission customers in New England, in accordance with the ISO Open Access Transmission Tariff (ISO-NE OATT). According to the FERC orders, RIE is compensated for its actual monthly transmission costs, with its authorized maximum ROE of 11.74% on its transmission assets. The ROE for transmission rates under the ISO-NE OATT is the subject of four complaints that are pending before the FERC. On October 16, 2014, the FERC issued an order on the first complaint, Opinion No. 531-A, resetting the base ROE applicable to transmission assets under the ISO-NE OATT from 11.14% to 10.57% effective as of October 16, 2014 and establishing a maximum ROE of 11.74%. On April 14, 2017, this order was vacated and remanded by the D. C. Circuit Court of Appeals (Court of Appeals). After the remand, the FERC issued an order on October 16, 2018 applicable to all four pending cases where it proposed a new base ROE methodology that, with subsequent input and support from the New England Transmission Owners (NETO), yielded a base ROE of 10.41%. Subsequent to the FERC's October 2018 order in the 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 months ended March 31, 2024 and 2023, PPL Electric purchased $419 million and $358 million of accounts receivable from alternative suppliers. (PPL)
Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	$ 64	51
TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	5
Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	12	15
Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,008	996
Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	16	19
Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	1,960	1,977
Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	256	252
Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	56	57
Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	25	23
Noncurrent regulatory liabilities	18	5
Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	68	72
Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	17	21
Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	15
Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	37	23
Noncurrent regulatory liabilities	37	34
PPL Electric Utilities Corp [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	90	91
Noncurrent regulatory liabilities	839	836
PPL Electric Utilities Corp [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	64	51
PPL Electric Utilities Corp [Member] | TCJA customer refund [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	5
PPL Electric Utilities Corp [Member] | Act 129 Compliance Rider [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	12	15
PPL Electric Utilities Corp [Member] | Accumulated Cost Of Removal Of Utility Plant [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	759	763
PPL Electric Utilities Corp [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	80	73
PPL Electric Utilities Corp [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	14	18
PPL Electric Utilities Corp [Member] | Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
PPL Electric Utilities Corp [Member] | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	2
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	16
Noncurrent regulatory liabilities	824	827
Louisville Gas And Electric Co [Member] | Generation Supply Charge [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | 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	309	306
Louisville Gas And Electric Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	11	13
Louisville Gas And Electric Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	454	459
Louisville Gas And Electric Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	20	20
Louisville Gas And Electric Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	28	29
Louisville Gas And Electric Co [Member] | Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Louisville Gas And Electric Co [Member] | Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	15
Louisville Gas And Electric Co [Member] | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	2	1
Noncurrent regulatory liabilities	2	0
Kentucky Utilities Co [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	1
Noncurrent regulatory liabilities	1,016	1,018
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	402	399
Kentucky Utilities Co [Member] | Power Purchase Agreement OVEC [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	5	6
Kentucky Utilities Co [Member] | Net deferred taxes [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	517	523
Kentucky Utilities Co [Member] | Defined Benefit Plans [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	60	59
Kentucky Utilities Co [Member] | Terminated interest rate swaps [Member]
Regulatory Liabilities [Line Items]
Noncurrent regulatory liabilities	28	28
Kentucky Utilities Co [Member] | Energy efficiency charge
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Noncurrent regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Rate adjustment mechanism
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Transmission Formula Rate [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Gas supply clause [Member]
Regulatory Liabilities [Line Items]
Current regulatory liabilities	0	0
Kentucky Utilities Co [Member] | Other
Regulatory Liabilities [Line Items]
Current regulatory liabilities	6	1
Noncurrent regulatory liabilities	$ 4	$ 3

Utility Rate Regulation - Reg_3

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

1 Months Ended

3 Months Ended

Mar. 26, 2024 USD ($)

Nov. 06, 2023 MW

Sep. 27, 2023 USD ($)

Mar. 29, 2023 USD ($)

Oct. 16, 2018

Aug. 24, 2018

Dec. 31, 2023 USD ($)

Mar. 31, 2024 USD ($)

Mar. 31, 2023 USD ($)

Mar. 31, 2016

Apr. 26, 2024

Apr. 25, 2024 USD ($)

Nov. 21, 2023 USD ($)

PPL Electric [Member]

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

Billing Issues, Expenses Incurred

$ 15

$ 3

Distribution System Improvement Charge Cap

5%

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

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

Accounts Receivable, Purchase

$ 419

358

PPL Electric [Member] | Pennsylvania Public Utility Commission

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

PPL Electric Billing Issue, Civil Penalty to be Paid

$ 1

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

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

PPL Electric Billing Issue, Donation to be Paid

$ 1

Requested Distribution System Improvement Charge Cap

9%

LGE [Member]

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

CPCN NGCC Combustion Turbine Facilities Power | MW

640

KU [Member]

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

CPCN NGCC Combustion Turbine Facilities Power | MW

640

Rhode Island Energy | Rhode Island Public Uitilty Commsion

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

Public Utilities, Approved Return on Equity, Percentage

9.275%

RIPUC Approved FY 2024 Gas ISR Plan for capital investment spend

$ 163

Recovery Cap on Capital Investment Related to AMF Program

$ 153

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

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

RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend

14

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

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

RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend

1

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

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

RIPUC Approved FY 2024 Electric ISR Plan for capital investment spend

$ 112

Rhode Island Energy | Rhode Island Public 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%

Rhode Island Energy | Rhode Island Public Utility Commission

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

Capital Investment Spend on FY 2025 Gas ISR Plan

$ 185

Proposed Capital Investment Spend on FY 2025 Electric ISR Plan

141

Proposed Contingency Plan Spend on FY 2025 Gas ISR Plan

11

Approved Capital Investment Spend on FY 2025 Gas ISR Plan

$ 180

Approved Contingency Plan Spend on FY 2025 Gas ISR Plan

11

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

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

Approved Capital Investment Spend on FY 2025 Gas ISR Plan

168

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

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

Approved Capital Investment Spend on FY 2025 Gas ISR Plan

12

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

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

Proposed Capital Investment Spend on FY 2025 Electric ISR Plan

13

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

13

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

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

Proposed Capital Investment Spend on FY 2025 Electric ISR Plan

$ 1

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

1

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

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

Approved Capital Investment Spend on FY 2025 Electric ISR Plan

$ 132

PPL Electric Utilities Corp [Member]

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

Billing Issues, Expenses Incurred

$ 15

3

Distribution System Improvement Charge Cap

5%

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

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

Accounts Receivable, Purchase

$ 419

$ 358

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

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

PPL Electric Billing Issue, Civil Penalty to be Paid

$ 1

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

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

PPL Electric Billing Issue, Donation to be Paid

$ 1

Requested Distribution System Improvement Charge Cap

9%

Louisville Gas And Electric Co [Member]

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

CPCN NGCC Combustion Turbine Facilities Power | MW

640

New NGCC LG&E Planned Ownership Percentage

31%

Kentucky Utilities Co [Member]

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

CPCN NGCC Combustion Turbine Facilities Power | MW

640

New NGCC KU Planned Ownership Percentage

69%

Utility Rate Regulation - Other

Utility Rate Regulation - Other (Details) - Unaffiliated Third Party Entity [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
PPL Electric [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 419	$ 358
PPL Electric Utilities Corp [Member]
Purchases Of Accounts Receivable [Line Items]
Accounts Receivable, Purchase	$ 419	$ 358

Financing Activities - Credit A

Financing Activities - Credit Arrangements (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	$ 291	$ 993
PPL Capital Funding [Member]
Line of Credit Facility [Line Items]
Capacity	1,450
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	231	403
Unused Capacity	1,219
PPL Capital Funding [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	218	365
PPL Capital Funding [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	1,250
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	218	390
Unused Capacity	1,032
Line of Credit Facility, Borrowing Capacity Sublimit	850	1,000
PPL Capital Funding [Member] | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	218	365
PPL Capital Funding [Member] | Bilateral Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	100
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	13	13
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	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
PPL Electric [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	510
PPL Electric [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
LGE [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
LGE [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	28	0
LGE [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
KU [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	93
Unused Capacity	355
KU [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	45	93
KU [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	93
Unused Capacity	355
Rhode Island Energy | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	25
Rhode Island Energy | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Line of Credit Facility, Borrowing Capacity Sublimit	400	250
Line of Credit Facility, Borrowing Capacity Sublimit, Maximum	600
Rhode Island Energy | Syndicated Credit Facility [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	25
PPL Electric Utilities Corp [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
PPL Electric Utilities Corp [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	0	510
PPL Electric Utilities Corp [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	650
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	1	511
Unused Capacity	649
Louisville Gas And Electric Co [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
Louisville Gas And Electric Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	28	0
Louisville Gas And Electric Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	500
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	28	0
Unused Capacity	472
Kentucky Utilities Co [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	93
Unused Capacity	355
Kentucky Utilities Co [Member] | Commercial Paper [Member]
Line of Credit Facility [Line Items]
Commercial Paper Issuances (c)	45	93
Kentucky Utilities Co [Member] | Syndicated Credit Facility [Member]
Line of Credit Facility [Line Items]
Capacity	400
Borrowed	0	0
Letters of Credit and Commercial Paper Issued (c)	45	$ 93
Unused Capacity	$ 355

Financing Activities - Short-te

Financing Activities - Short-term Debt (Details) - Commercial Paper [Member] - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Short-term Debt [Line Items]
Capacity	$ 3,300
Commercial Paper Issuances (c)	291	$ 993
Unused Capacity	$ 3,009
PPL Capital Funding [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.51%	5.66%
Capacity	$ 1,350
Commercial Paper Issuances (c)	218	$ 365
Unused Capacity	1,132
PPL Electric [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.67%
Capacity	650
Commercial Paper Issuances (c)	0	$ 510
Unused Capacity	$ 650
LGE [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%
Capacity	$ 500
Commercial Paper Issuances (c)	28	$ 0
Unused Capacity	$ 472
KU [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%	5.64%
Capacity	$ 400
Commercial Paper Issuances (c)	45	$ 93
Unused Capacity	355
Rhode Island Energy
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.72%
Capacity	400
Commercial Paper Issuances (c)	0	$ 25
Unused Capacity	400
PPL Electric Utilities Corp [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate		5.67%
Capacity	650
Commercial Paper Issuances (c)	0	$ 510
Unused Capacity	$ 650
Louisville Gas And Electric Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%
Capacity	$ 500
Commercial Paper Issuances (c)	28	$ 0
Unused Capacity	$ 472
Kentucky Utilities Co [Member]
Short-term Debt [Line Items]
Weighted - Average Interest Rate	5.49%	5.64%
Capacity	$ 400
Commercial Paper Issuances (c)	45	$ 93
Unused Capacity	$ 355

Financing Activities - Long-ter

Financing Activities - Long-term Debt (Details) - USD ($) $ in Millions	1 Months Ended
	Mar. 31, 2024	Jan. 31, 2024	Dec. 31, 2023
Long-term Debt (Numeric) [Abstract]
Long-term debt due within one year	$ 1		$ 1
Long-term Debt, Excluding Current Maturities	15,753		14,611
PPL Electric [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	650
Borrowed	0		0
PPL Electric [Member] | First Mortgage Bond [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 650
Stated interest rate		4.85%
Proceeds from Issuance of First Mortgage Bond		$ 644
PPL Capital Funding [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	1,450
Borrowed	0		0
LGE [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	500
Borrowed	0		0
KU [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	400
Borrowed	0		0
Rhode Island Energy | First Mortgage Bond [Member] | Senior Notes due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount	$ 500
Stated interest rate	5.35%
Proceeds from Issuance of First Mortgage Bond	$ 496
PPL Electric Utilities Corp [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	650
Borrowed	0		0
Long-term Debt, Excluding Current Maturities	5,211		4,567
PPL Electric Utilities Corp [Member] | First Mortgage Bond [Member] | First Mortgage Bonds due 2034
Long-term Debt (Numeric) [Abstract]
Principal amount		$ 650
Stated interest rate		4.85%
Proceeds from Issuance of First Mortgage Bond		$ 644
Louisville Gas And Electric Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	500
Borrowed	0		0
Long-term Debt, Excluding Current Maturities	2,469		2,469
Kentucky Utilities Co [Member]
Long-term Debt (Numeric) [Abstract]
Capacity	400
Borrowed	0		0
Long-term Debt, Excluding Current Maturities	$ 3,064		$ 3,064

Financing Activities - Equity S

Financing Activities - Equity Securities (Details)	1 Months Ended
	Feb. 29, 2024 $ / shares
Securities Financing Transaction [Line Items]
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.03

Financing Activities - Distribu

Financing Activities - Distributions (Details) - $ / shares	1 Months Ended	3 Months Ended
	Feb. 29, 2024	Mar. 31, 2024	Mar. 31, 2023
Distributions (Numeric) [Abstract]
Current quarterly common stock dividend (in dollars per share)	$ 0.2575	$ 0.2575	$ 0.2400
Annualized current quarterly common stock dividend (in dollars per share)	$ 1.03

Acquisitions, Development and_2

Acquisitions, Development and Divestitures - Development (Details) $ in Millions			3 Months Ended			6 Months Ended
		Nov. 06, 2023 MW	Mar. 31, 2024 USD ($)		Mar. 31, 2023 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2023 USD ($)
Business Acquisition [Line Items]
Transition Service Agreement Cost			$ 48		$ 58
Goodwill			2,247				$ 2,247
Operating Revenues from external customers			2,304		2,415
Net income (loss)			307		285
Indemnification for Safari sale/leaseback			25
Louisville Gas And Electric Co [Member]
Business Acquisition [Line Items]
Goodwill			389				389
Operating Revenues from external customers			476		474
Net income (loss)			93	[1]	86
New NGCC LG&E Planned Ownership Percentage		31%
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Kentucky Utilities Co [Member]
Business Acquisition [Line Items]
Goodwill			607				$ 607
Operating Revenues from external customers			525		499
Net income (loss)	[2]		108		88
New NGCC KU Planned Ownership Percentage		69%
CPCN NGCC Combustion Turbine Facilities Power | MW		640
Narragansett Electric
Business Acquisition [Line Items]
Total cash consideration						$ 3,800
Rhode Island Regulated
Business Acquisition [Line Items]
Operating Revenues from external customers			549		565
Net income (loss)			64		54
Corporate and Other [Member]
Business Acquisition [Line Items]
Operating Revenues from external customers			1		(1)
Net income (loss)			(96)		(73)
Rhode Island Energy | Rhode Island Energy TSA
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense			81		54
Rhode Island Energy | Accrual for TSA Markup
Business Acquisition [Line Items]
Other Nonrecurring (Income) Expense			1		$ 2
LGE [Member]
Business Acquisition [Line Items]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
KU [Member]
Business Acquisition [Line Items]
CPCN NGCC Combustion Turbine Facilities Power | MW		640
LKE [Member]
Business Acquisition [Line Items]
ExpectedCapitalCostOfExpansionProject			$ 1,000
[1] Net income equals comprehensive income. Net income equals comprehensive income.

Defined Benefits (Details)

Defined Benefits (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	$ 5	$ 3
Pension Plan [Member] | U.S.
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	9	9
Interest cost	46	46
Expected return on plan assets	(75)	(78)
Amortization of: [Abstract]
Prior service cost	1	2
Actuarial loss	2	0
Net periodic defined benefit costs (credits)	(17)	(21)
Other Postretirement Benefits Plan [Member]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	1	2
Interest cost	7	7
Expected return on plan assets	(7)	(8)
Amortization of: [Abstract]
Actuarial loss	(1)	(1)
Net periodic defined benefit costs (credits)	0	0
PPL Electric Utilities Corp [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	1	1
Louisville Gas And Electric Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	1	0
Kentucky Utilities Co [Member]
Net Periodic Defined Benefit Costs Allocated to Subsidiary by Sponsor (Numeric) [Abstract]
Defined benefit plans - funding	$ 1	$ 0

Commitments and Contingencies -

Commitments and Contingencies - Legal Matters and Regulatory Issues (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Dec. 31, 2023
Claim By Former Affiliate [Abstract]
Period Over Which Distribution Adjustment Charge-related Costs Are amortized	10 years
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	98	$ 99
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8	8
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Claim By Former Affiliate [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 8	$ 8

Commitments and Contingencies_2

Commitments and Contingencies - Environmental Matters and Other (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (13)	$ (12)
Period RIE Environmental Remediation Costs To Be Incurred Over	30 years
RIE Environmental Remediation
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	$ 98		$ 99
PPL Electric [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		8
PPL Electric Utilities Corp [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(2)	(2)
PPL Electric Utilities Corp [Member] | PPL Electric Additional Sites [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Accrual for Environmental Loss Contingencies, Gross	8		$ 8
Louisville Gas And Electric Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	(3)	(3)
Kentucky Utilities Co [Member]
Other - Labor Union Agreements (Numeric) [Abstract]
Amortization of excess deferred income taxes	$ (5)	$ (4)

Commitments and Contingencies_3

Commitments and Contingencies - Guarantees and Other Assurances (Details) - 3 months ended Mar. 31, 2024 £ in Millions, $ in Millions	USD ($)	GBP (£)	USD ($)
Other Guarantee (Numeric) [Abstract]
Maximum aggregate coverage bodily injury and property damage			$ 231
Indemnification Cap, Surrenders of Tax Losses | £		£ 50
Indemnification for Safari sale/leaseback	$ 25
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | LGE [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			60
Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member] | KU [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			26
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			121
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			86
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable.
Louisville Gas And Electric Co [Member] | Financial Guarantee [Member] | LGE And KU Guarantee Of Shortfall Related To OVEC [Member]
Guarantor Obligations [Line Items]
Recorded liability for all guarantees			60
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			$ 26
Maximum exposure is not estimable	The maximum exposure and the expiration date of these potential obligations are not presently determinable

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
PPL Electric Utilities Corp [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Receivable from affiliates	$ 554		$ 0
Financing Receivable, after Allowance for Credit Loss, Related Party, Type [Extensible Enumeration]	CEP Reserves, Inc		CEP Reserves, Inc
PPL Electric Utilities Corp [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 56	$ 59
PPL Electric Utilities Corp [Member] | CEP Reserves, Inc
Intercompany Borrowings (Numeric) [Abstract]
Intercompany note with affiliate maximum borrowing capacity	800
Louisville Gas And Electric Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	11	8
Louisville Gas And Electric Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	722
Louisville Gas And Electric Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	29	32
Kentucky Utilities Co [Member]
Intercompany Borrowings (Numeric) [Abstract]
Notes Payable to affiliates	$ 37		$ 0
Notes Payable, Related Party, Type [Extensible Enumeration]	Affiliated Entity [Member]		Affiliated Entity [Member]
Kentucky Utilities Co [Member] | PPL Services [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 11	9
Kentucky Utilities Co [Member] | Parent And Affiliate [Member]
Intercompany Borrowings (Numeric) [Abstract]
Intercompany Money Pool Agreement Unused Borrowing Capacity	568
Kentucky Utilities Co [Member] | LKS [Member]
Support Costs (Details) [Abstract]
Related Party Transaction, Amounts of Transaction	$ 38	$ 41

Other Income (Expense) - net (D

Other Income (Expense) - net (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Other Income
Defined benefit plans - non-service credits	$ 8	$ 17
AFUDC - equity component	9	6
Miscellaneous	(2)	(1)
Other Expense
Charitable Contributions	(2)	(1)
Other Income (Expense) - net	22	30
Interest Income (Expense), Nonoperating, Net	9	9
PPL Electric Utilities Corp [Member]
Other Income
Defined benefit plans - non-service credits	4	5
AFUDC - equity component	5	4
Other Expense
Charitable Contributions	(1)	(1)
Other Income (Expense) - net	9	12
Interest Income (Expense), Nonoperating, Net	$ 1	$ 4

Fair Value Measurements - Asset

Fair Value Measurements - Assets and Liabilities Measured on Recurring Basis Table (Details) - Recurring Fair Value Measurements [Member] - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Dec. 31, 2023
Assets
Cash and cash equivalents	$ 276	$ 331
Restricted cash and cash equivalents	45	51
Total Cash, Cash Equivalents and Restricted Cash	321	382
Special Use Funds [Abstract]
Money market fund	2	1
Commingled debt fund measured at NAV	7	9
Commingled equity fund measured at NAV	7	8
Total special use funds	16	18
Gas Contracts	1	1
Price risk management assets:
Total Assets	338	401
Price risk management liabilities:
Interest rate swaps	5	7
Gas Contracts	34	60
Total price risk management liabilities	39	67
Level 1 [Member]
Assets
Cash and cash equivalents	276	331
Restricted cash and cash equivalents	45	51
Total Cash, Cash Equivalents and Restricted Cash	321	382
Special Use Funds [Abstract]
Money market fund	2	1
Total special use funds	2	1
Gas Contracts	0	0
Price risk management assets:
Total Assets	323	383
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	0	0
Total price risk management liabilities	0	0
Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Special Use Funds [Abstract]
Money market fund	0	0
Total special use funds	0	0
Gas Contracts	1	1
Price risk management assets:
Total Assets	1	1
Price risk management liabilities:
Interest rate swaps	5	7
Gas Contracts	33	41
Total price risk management liabilities	38	48
Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Special Use Funds [Abstract]
Money market fund	0	0
Total special use funds	0	0
Gas Contracts	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Gas Contracts	1	19
Total price risk management liabilities	1	19
Gas Contracts, Liability, Settlements	(18)
PPL Electric Utilities Corp [Member]
Assets
Cash and cash equivalents	21	51
Price risk management assets:
Total Assets	21	51
PPL Electric Utilities Corp [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	21	51
Price risk management assets:
Total Assets	21	51
PPL Electric Utilities Corp [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
PPL Electric Utilities Corp [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Price risk management assets:
Total Assets	0	0
Louisville Gas And Electric Co [Member]
Assets
Cash and cash equivalents	8	18
Restricted cash and cash equivalents	22	26
Total Cash, Cash Equivalents and Restricted Cash	30	44
Price risk management assets:
Total Assets	30	44
Price risk management liabilities:
Interest rate swaps	5	7
Total price risk management liabilities	5	7
Louisville Gas And Electric Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	8	18
Restricted cash and cash equivalents	22	26
Total Cash, Cash Equivalents and Restricted Cash	30	44
Price risk management assets:
Total Assets	30	44
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Louisville Gas And Electric Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	5	7
Total price risk management liabilities	5	7
Louisville Gas And Electric Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Price risk management liabilities:
Interest rate swaps	0	0
Total price risk management liabilities	0	0
Kentucky Utilities Co [Member]
Assets
Cash and cash equivalents	12	14
Restricted cash and cash equivalents	22	24
Total Cash, Cash Equivalents and Restricted Cash	34	38
Price risk management assets:
Total Assets	34	38
Kentucky Utilities Co [Member] | Level 1 [Member]
Assets
Cash and cash equivalents	12	14
Restricted cash and cash equivalents	22	24
Total Cash, Cash Equivalents and Restricted Cash	34	38
Price risk management assets:
Total Assets	34	38
Kentucky Utilities Co [Member] | Level 2 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	0	0
Kentucky Utilities Co [Member] | Level 3 [Member]
Assets
Cash and cash equivalents	0	0
Restricted cash and cash equivalents	0	0
Total Cash, Cash Equivalents and Restricted Cash	0	0
Price risk management assets:
Total Assets	$ 0	$ 0

Fair Value Measurements - Finan

Fair Value Measurements - Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 15,754	$ 14,612
Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	15,016	14,031
PPL Electric Utilities Corp [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,211	4,567
PPL Electric Utilities Corp [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	5,023	4,475
Louisville Gas And Electric Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	2,469	2,469
Louisville Gas And Electric Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	2,344	2,369
Kentucky Utilities Co [Member] | Carrying Amount [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	3,064	3,064
Kentucky Utilities Co [Member] | Fair Value [Member]
Fair Value of Financial Instruments Not Recorded at Fair Value - Other
Debt Instrument, Fair Value Disclosure	$ 2,832	$ 2,861

Derivative Instruments and He_4

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

Derivative Instruments and He_5

Derivative Instruments and Hedging Activities - Risk Disclosures (Details) $ in Millions	3 Months Ended
	Mar. 31, 2024 USD ($) Bcf	Mar. 31, 2023 USD ($)	Dec. 31, 2023 USD ($)
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Gain (Loss) on Discontinuation of Interest Rate Cash Flow Hedge Due to Forecasted Transaction Probable of Not Occurring, Net	$ 0	$ 0
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	0		$ 0
Cash collateral pledged - eligible for offset	0		0
Cash collateral pledged - eligible for offset	0		0
Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	1		1
Liability value	39		67
Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	1		1
Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	31		52
Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	8		15
Interest Rate Swaps [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Interest Rate Swaps [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Interest Rate Swaps [Member] | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	1		1
Interest Rate Swaps [Member] | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	4		6
Gas Contract | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	1		1
Gas Contract | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Gas Contract | Other Current Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	30		51
Gas Contract | Other Noncurrent Liabilities | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Liability value	4		9
LGE [Member] | Economic Hedges [Member] | Interest Rate Swaps [Member]
Interest Rate Risk - Cash Flow Hedges (Numeric) [Abstract]
Derivative, Notional Amount	$ 64
Rhode Island Energy | Economic Hedges [Member] | Gas Contract
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Derivative, Nonmonetary Notional Amount, Volume | Bcf	41
Louisville Gas And Electric Co [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	$ 0		0
Cash collateral pledged - eligible for offset	0		0
Cash collateral pledged - eligible for offset	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
Liability value	5		7
Louisville Gas And Electric Co [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member] | Other Current Assets | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member] | Not Designated As Hedging Instruments [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Asset value	0		0
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
Kentucky Utilities Co [Member]
Foreign Currency Risk - Economic Activity (Numeric) [Abstract]
Cash collateral obligation under master netting arrangements	0		0
Cash collateral pledged - eligible for offset	0		0
Cash collateral pledged - eligible for offset	$ 0		$ 0

Derivative Instruments and He_6

Derivative Instruments and Hedging Activities - Fair Values (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Fair Values by Balance Sheet Location [Abstract]
Asset value	$ 1	$ 1
Liability value	39	67
Louisville Gas And Electric Co [Member]
Fair Values by Balance Sheet Location [Abstract]
Asset value	0	0
Liability value	$ 5	$ 7

Derivative Instruments and He_7

Derivative Instruments and Hedging Activities - Gains and Losses (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023	Dec. 31, 2023
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	$ 179	$ 164
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	22	30
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
Cash Flow Hedges [Member] | Interest Rate Swaps [Member] | Interest Expense [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (Loss) Reclassified from AOCI into Income	(1)	(1)
Amount of gain (loss) reclassified from AOCI to income	(1)	(1)
Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative	(16)	(1)
Gain (loss) recognized as regulatory liabilities/assets	28	20
Asset value	1		$ 1
Liability value	39		67
Not Designated As Hedging Instruments [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
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
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]		Interest Expense
Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
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	2	$ (1)
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	$ (16)
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Energy purchases
Not Designated As Hedging Instruments [Member] | Gas Contracts | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets	$ 4
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	22
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
Not Designated As Hedging Instruments [Member] | Gas Contracts | Purchased Power And Gas
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized in income on derivative		(2)
Not Designated As Hedging Instruments [Member] | Gas Contract | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
Not Designated As Hedging Instruments [Member] | Gas Contract | Regulatory Assets Noncurrent [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets		(7)
Not Designated As Hedging Instruments [Member] | Gas Contract | Regulatory Assets, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Gain (loss) recognized as regulatory liabilities/assets		28
Louisville Gas And Electric Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	26	25
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	2	2
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
Liability value	5		7
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Price risk management liabilities, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1		1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Price risk management, liabilities, noncurrent
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	4		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
Derivative, Gain (Loss), Statement of Income or Comprehensive Income [Extensible Enumeration]	Interest Expense	Interest Expense
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Other Noncurrent Assets [Member]
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Asset value	$ 0		0
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Price risk management liabilities, current
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	1		1
Louisville Gas And Electric Co [Member] | Not Designated As Hedging Instruments [Member] | Interest Rate Swaps [Member] | Price risk management, liabilities, noncurrent
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Liability value	4		$ 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	2	$ (1)
Kentucky Utilities Co [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Interest Expense	34	33
Amounts Included in Income, OCI or Regulatory Liabilities/Assets [Abstract]
Other Income (Expense) - net	$ 2	$ 2

Derivative Instruments and He_8

Derivative Instruments and Hedging Activities - Offsetting Derivative Instruments and Credit Risk-Related Features (Details) - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Assets [Abstract]
Cash collateral received - eligible for offset	$ 0	$ 0
Liabilities [Abstract]
Cash collateral pledged - eligible for offset	0	0
Credit Risk-Related Contingent Features [Abstract]
Aggregate fair value of additional collateral requirements in the event of a credit downgrade below investment grade	29
Derivative, Net Liability Position, Aggregate Fair Value	28
Treasury Derivatives [Member]
Assets [Abstract]
Gross	1	1
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	1	1
Liabilities [Abstract]
Gross	39	67
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	39	67
Louisville Gas And Electric Co [Member]
Assets [Abstract]
Cash collateral received - eligible for offset	0	0
Liabilities [Abstract]
Cash collateral pledged - eligible for offset	0	0
Louisville Gas And Electric Co [Member] | Treasury Derivatives [Member]
Assets [Abstract]
Gross	0	0
Derivative instruments - eligible for offset	0	0
Cash collateral received - eligible for offset	0	0
Net	0	0
Liabilities [Abstract]
Gross		7
Derivative instruments - eligible for offset	0	0
Cash collateral pledged - eligible for offset	0	0
Net	$ 5	$ 7

Derivative Instruments and He_9

Derivative Instruments and Hedging Activities - Commodity Purchases (Details) - Not Designated As Hedging Instruments [Member] - USD ($) $ in Millions	Mar. 31, 2024	Dec. 31, 2023
Commodity Purchases [Line Items]
Liability value	$ 39	$ 67
Asset value	1	1
Other Current Assets
Commodity Purchases [Line Items]
Asset value	1	1
Other Current Assets | Gas Contract
Commodity Purchases [Line Items]
Asset value	1	1
Other Current Assets | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Current Liabilities
Commodity Purchases [Line Items]
Liability value	31	52
Other Current Liabilities | Gas Contract
Commodity Purchases [Line Items]
Liability value	30	51
Other Current Liabilities | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Liability value	1	1
Other Noncurrent Assets [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Assets [Member] | Gas Contract
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Assets [Member] | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Asset value	0	0
Other Noncurrent Liabilities
Commodity Purchases [Line Items]
Liability value	8	15
Other Noncurrent Liabilities | Gas Contract
Commodity Purchases [Line Items]
Liability value	4	9
Other Noncurrent Liabilities | Interest Rate Swaps [Member]
Commodity Purchases [Line Items]
Liability value	$ 4	$ 6

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) $ in Millions	3 Months Ended
	Mar. 31, 2024 USD ($)
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	$ 158
Accretion	2
Obligations settled	(5)
Asset Retirement Obligations, Period Change, Miscellaneous	1
Balance at End of Period	156
Louisville Gas And Electric Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	85
Accretion	1
Obligations settled	(2)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	84
Kentucky Utilities Co [Member]
Asset Retirement Obligation [Roll Forward]
Balance at Beginning of Period	66
Accretion	1
Obligations settled	(3)
Asset Retirement Obligations, Period Change, Miscellaneous	0
Balance at End of Period	$ 64

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Income (Loss) - After-tax Changes by Component (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	$ (163)	$ (124)
Amounts arising during the period	1	1
Reclassifications from AOCI	1	0
Net OCI during the period	2	1
Balance at end of period	(161)	(123)
Unrealized gains (losses) on qualifying derivatives [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	6	3
Amounts arising during the period	0	0
Reclassifications from AOCI	1	1
Net OCI during the period	1	1
Balance at end of period	7	4
Equity Investees' OCI
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	3	2
Amounts arising during the period	1	1
Reclassifications from AOCI	0	0
Net OCI during the period	1	1
Balance at end of period	4	3
Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(168)	(124)
Amounts arising during the period	0	0
Reclassifications from AOCI	0	(1)
Net OCI during the period	0	(1)
Balance at end of period	(168)	(125)
Accumulated Defined Benefit Plans Adjustment, Net Prior Service Attributable to Parent
Accumulated Other Comprehensive Income (Loss) [Line Items]
Balance at beginning of period	(4)	(5)
Amounts arising during the period	0	0
Reclassifications from AOCI	0	0
Net OCI during the period	0	0
Balance at end of period	$ (4)	$ (5)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Income (Loss) - Income (Expense) Effect of Reclassifications (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2024	Mar. 31, 2023
Affected Line Item on the Statements of Income [Line Items]
Interest Expense	$ (179)	$ (164)
Other Income (Expense) - net	22	30
Income Tax Expense (Benefit)	(81)	(79)
Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Total After-tax	(1)	0
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	0	1
Income Tax Expense (Benefit)	0	0
Total After-tax	0	1
Defined Benefit Plans [Member] | Accumulated Defined Benefit Plans Adjustment, Net Gain (Loss) Attributable to Parent | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	0	1
Unrealized gains (losses) on qualifying derivatives [Member] | Amounts Reclassified From Accumulated Other Comprehensive Income [Member]
Affected Line Item on the Statements of Income [Line Items]
Income (Loss) from Continuing Operations before Income Taxes	(1)	(1)
Income Tax Expense (Benefit)	0	0
Total After-tax	(1)	(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)	$ (1)