Supplemental Financial Information (Exelon, Generation, ComEd, PECO and BGE)

Supplemental Statement of Operations Information

The following tables provide additional information about the Registrants’ Consolidated Statements of Operations and Comprehensive Income for the years ended December 31, 2014, 2013 and 2012.



For the year ended December 31, 2014	Exelon		Generation		ComEd		PECO		BGE
Taxes other than income
Utility ^(a)	$	456	$	89	$	238	$	128	$	86
Property	396		240		25		15		114
Payroll	200		118		28		14		18
Other	102		18		2		2		3
Total taxes other than income	$	1,154	$	465	293		$	159	$	221



For the year ended December 31, 2013	Exelon		Generation		ComEd		PECO		BGE
Taxes other than income
Utility ^(a)	$	449	$	79	$	241	$	129	$	82
Property	302		205		24		14		112
Payroll	159		89		27		13		15
Other	185		16		7		2		4
Total taxes other than income	$	1,095	$	389	$	299	$	158	$	213



For the year ended December 31, 2012	Exelon		Generation		ComEd		PECO			BGE
Taxes other than income
Utility ^(a)	$	463	$	82	$	239	$	141		$	75
Property	227		189		22		13			111
Payroll	131		78		26		12			18
Other	198		20		8		(4		)	4
Total taxes other than income	$	1,019	$	369	$	295	$	162		$	208

_____________________

(a)

Generation’s utility tax represents gross receipts tax related to its retail operations and ComEd’s, PECO’s and BGE’s utility taxes represent municipal and state utility taxes and gross receipts taxes related to their operating revenues, respectively. The offsetting collection of utility taxes from customers is recorded in revenues on the Registrants’ Consolidated Statements of Operations and Comprehensive Income.



For the year ended December 31, 2014	Exelon			Generation			ComEd		PECO			BGE
Other, Net
Decommissioning-related activities:
Net realized income on decommissioning trust funds ^(a)—
Regulatory agreement units	$	216		$	216		$	—	$	—		$	—
Non-regulatory agreement units	159			159			—		—			—
Net unrealized gains on decommissioning trust funds—
Regulatory agreement units	180			180			—		—			—
Non-regulatory agreement units	134			134			—		—			—
Net unrealized gains on pledged assets—
Zion Station decommissioning	29			29			—		—			—
Regulatory offset to decommissioning trust fund-related activities ^(b)	(358		)	(358		)	—		—			—
Total decommissioning-related activities	360			360			—		—			—
Investment income	1			1			—		(1		)	7			^(c)
Long-term lease income	24			—			—		—			—
Interest income related to uncertain income tax positions	40			54			—		—			—
AFUDC—Equity	21			—			3		6			12
Other	9			(9		)	14		2			(1		)
Other, net	$	455		$	406		$	17	$	7		$	18



For the year ended December 31, 2013	Exelon			Generation			ComEd		PECO			BGE
Other, Net
Decommissioning-related activities:
Net realized income on decommissioning trust funds ^(a)—
Regulatory agreement units	$	256		$	256		$	—	$	—		$	—
Non-regulatory agreement units	77			77			—		—			—
Net unrealized gains on decommissioning trust funds—
Regulatory agreement units	406			406			—		—			—
Non-regulatory agreement units	146			146			—		—			—
Net unrealized gains on pledged assets—
Zion Station decommissioning	7			7			—		—			—
Regulatory offset to decommissioning trust fund-related activities ^(b)	(546		)	(546		)	—		—			—
Total decommissioning-related activities	346			346			—		—			—
Investment income	8			(1		)	—		(1		)	9		^(c)
Long-term lease income	28			—			—		—			—
Interest income related to uncertain income tax positions	24			4			—		—			—
AFUDC—Equity	22			—			11		4			7
Other	32			6			15		3			1
Other, net	$	460		$	355		$	26	$	6		$	17



For the year ended December 31, 2012	Exelon			Generation			ComEd		PECO		BGE
Other, Net
Decommissioning-related activities:
Net realized income on decommissioning trust funds ^(a)—
Regulatory agreement units	$	189		$	189		$	—	$	—	$	—
Non-regulatory agreement units	102			102			—		—		—
Net unrealized losses on decommissioning trust funds—
Regulatory agreement units	386			386			—		—		—
Non-regulatory agreement units	105			105			—		—		—
Net unrealized gains on pledged assets—
Zion Station decommissioning	73			73			—		—		—
Regulatory offset to decommissioning trust fund-related activities ^(b)	(530		)	(530		)	—		—		—
Total decommissioning-related activities	325			325			—		—		—
Investment income	20			3			1		2		11		^(c)
Long-term lease income	29			—			—		—		—
Interest income related to uncertain income tax positions	15			2			20		—		—
AFUDC—Equity	17			—			6		4		10
Credit Facility termination fees	(85		)	(85		)	—		—		—
Other	32			1			12		2		2
Other, net	$	353		$	246		$	39	$	8	$	23

_________________________


(a)	Includes investment income and realized gains and losses on sales of investments of the trust funds.


(b)	Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of net income taxes related to all NDT fund activity for those units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning.


(c)	Relates to the cash return on BGE’s rate stabilization deferral. See Note 3 — Regulatory Matters for additional information regarding the rate stabilization deferral.

Supplemental Cash Flow Information

The following tables provide additional information regarding the Registrants’ Consolidated Statements of Cash Flows for the years ended December 31, 2014, 2013 and 2012.



For the year ended December 31, 2014	Exelon		Generation		ComEd		PECO		BGE
Depreciation, amortization, accretion and depletion
Property, plant and equipment	$	2,080	$	922	$	588	$	227	$	288
Regulatory assets	191		—		99		9		83
Amortization of intangible assets, net	44		44		—		—		—
Amortization of energy contract assets and liabilities^(a)	135		135		—		—		—
Nuclear fuel^(b)	1,073		1,073		—		—		—
ARO accretion^(c)	345		345		—		—		—
Total depreciation, amortization, accretion and depletion	$	3,868	$	2,519	$	687	$	236	$	371



For the year ended December 31, 2013	Exelon		Generation		ComEd		PECO		BGE
Depreciation, amortization, accretion and depletion
Property, plant and equipment	$	1,893	$	813	$	545	$	219	$	264
Regulatory assets	212		—		119		9		84
Amortization of intangible assets, net	48		43		5		—		—
Amortization of energy contract assets and liabilities^(a)	430		507		—		—		—
Nuclear fuel^(b)	921		921		—		—		—
ARO accretion^(c)	275		275		—		—		—
Total depreciation, amortization, accretion and depletion	$	3,779	$	2,559	$	669	$	228	$	348



For the year ended December 31, 2012	Exelon		Generation		ComEd		PECO		BGE
Depreciation, amortization, accretion and depletion
Property, plant and equipment	$	1,712	$	733	$	525	$	207	$	245
Regulatory assets	129		—		80		10		53
Amortization of intangible assets, net	40		35		5		—		—
Amortization of energy contract assets and liabilities^(a)	1,110		1,110		—		—		—
Nuclear fuel^(b)	848		848		—		—		—
ARO accretion^(c)	240		240		—		—		—
Total depreciation, amortization and accretion	$	4,079	$	2,966	$	610	$	217	$	298

________________________


(a)	Included in Operating revenues or Purchased power and fuel on the Registrants’ Consolidated Statements of Operations and Comprehensive Income.


(b)	Included in Purchased power and fuel expense on the Registrants’ Consolidated Statements of Operations and Comprehensive Income.


(c)	Included in Operating and maintenance expense on the Registrants’ Consolidated Statements of Operations and Comprehensive Income.



For the year ended December 31, 2014	Exelon			Generation				ComEd			PECO			BGE
Cash paid (refunded) during the year:
Interest (net of amount capitalized)	$	940		$	322			$	292		$	94		$	111
Income taxes (net of refunds)	$	314		227				(6		)	85			(21		)
Other non-cash operating activities:
Pension and non-pension postretirement benefit costs	$	560		$	249			162			$	36		$	64
Loss from equity method investments	22			20				—			—			—
Provision for uncollectible accounts	156			14				26			52			64
Provision for excess and obsolete inventory	5			5				—			—			—
Stock-based compensation costs	91			—				—			—			—
Other decommissioning-related activity^(a)	(132		)	(132		)		—			—			—
Energy-related options^(b)	122			122				—			—			—
Amortization of regulatory asset related to debt costs	11			—				8			3			—
Amortization of rate stabilization deferral	65			—				—			—			65
Amortization of debt fair value adjustment	(23		)	(23		)		—			—			—
Merger-related commitments	44			44				—			—			—
Amortization of debt costs	53			12				4			2			2
Discrete impacts from EIMA^(c)	53			—				53			—			—
Lower of cost or market inventory adjustment	29			29				—			—			—
Other	(2		)	6				2			(1		)	(15		)
Total other non-cash operating activities	$	1,054		$	346			$	255		$	92		$	180
Changes in other assets and liabilities:
Under/over-recovered energy and transmission costs	$	47		$	—			$	36		$	—		$	11
Other regulatory assets and liabilities	(167		)	—				(13		)	(16		)	(121		)
Cash deposits ^(d)	(241		)	(241		)		—			—			—
Other current assets	7			81				(10		)	(2		)	(44		)
Other noncurrent assets and liabilities	(204		)	(89		)		32			1			(9		)
Total changes in other assets and liabilities	$	(558	)	$	(249	)		$	45		$	(17	)	$	(163	)
Non-cash investing and financing activities:
Change in ARC	$	72		$	72			$	—		$	—		$	—
Change in capital expenditures not paid	220			(61		)	^(e)	78			—			25
Fair value of net assets recorded upon CENG consolidation ^(f)	(3,400		)	(3,400		)		—			—			—
Issuance of equity units ^(g)	131			—				—			—			—
Nuclear fuel procurement ^(h)	70			70				—			—			—
Indemnification of like-kind exchange position ⁽ⁱ⁾	—			—				5			—			—

____________________________


(a)	Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning.


(b)	Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations.


(c)	Reflects the change in distribution rates pursuant to EIMA, which allows for the recovery of costs by a utility through a pre-established performance-based formula rate tariff. See Note 3 — Regulatory Matters for more information.


(d)	Relates primarily to cash deposits made to ISO's/RTO's.


(e)	Includes $170 million of changes in capital expenditures not paid between December 31, 2014 and 2013 related to Antelope Valley.


(f)	See Note 5 — Investment in Constellation Energy Nuclear Group, LLC for additional information.


(g)	Relates to the present value of the contract payments for the equity units issued by Exelon. See Note 19 — Common Stock for additional information.


(h)	Relates to the nuclear fuel procurement contracts for the purchase of fixed quantities of uranium, which was delivered to Generation on June 30, 2014 and September 24, 2014. Generation is required to make payments starting June 30, 2016, with the final payment being due no later than June 30, 2018.


(i)	See Note 14 — Income Taxes for discussion of the like-kind exchange tax position.



For the year ended December 31, 2013	Exelon			Generation				ComEd				PECO			BGE
Cash paid (refunded) during the year:
Interest (net of amount capitalized)	$	866		$	291			$	283			$	95		$	130
Income taxes (net of refunds)	112			(18		)		33				70			42
Other non-cash operating activities:
Pension and non-pension postretirement benefit costs	$	825		$	345			$	308			$	43		$	56
Gain from equity method investments	(10		)	(10		)		—				—			—
Provision for uncollectible accounts	101			10				(15		)		61			44
Provision for excess and obsolete inventory	9			9				—				—			—
Stock-based compensation costs	120			—				—				—			—
Other decommissioning-related activity ^(a)	(169		)	(169		)		—				—			—
Energy-related options ^(b)	104			104				—				—			—
Amortization of regulatory asset related to debt costs	12			—				9				3			—
Amortization of rate stabilization deferral	66			—				—				—			66
Amortization of debt fair value adjustment	(34		)	(34		)		—				—			—
Discrete impacts from EIMA ^(c)	(271		)	—				(271		)		—			—
Amortization of debt costs	18			10				1				2			2
Other	(53		)	5				(4		)		(1		)	(15		)
Total other non-cash operating activities	$	718		$	270			$	28			$	108		$	153
Changes in other assets and liabilities:
Under/over-recovered energy and transmission costs	$	12		$	—			$	(35	)		$	9		$	38
Other regulatory assets and liabilities	(64		)	—				(43		)		(16		)	(71		)
Other current assets	(165		)	(151		)		51				13			(8		)
Other noncurrent assets and liabilities	322			15				268			^(d)	(12		)	(23		)
Total changes in other assets and liabilities	$	105		$	(136	)		$	241			$	(6	)	$	(64	)
Non-cash investing and financing activities:
Change in ARC	$	(128	)	$	(128	)		$	—			$	—		$	4
Change in capital expenditures not paid	(38		)	(107		)	^(e)	(8		)		13			(48		)
Consolidated VIE dividend to noncontrolling interest	63			63				—				—			—
Indemnification of like-kind exchange position ^(f)	—			—				176				—			—

______________________


(a)	Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning.


(b)	Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations.


(c)	Reflects the change in distribution rates pursuant to EIMA, which allows for the recovery of costs by a utility through a pre-established performance-based formula rate tariff. See Note 3 — Regulatory Matters for more information.


(d)	Relates primarily to interest payable related to like-kind exchange tax position. See Note 14 — Income Taxes for discussion of the like-kind exchange tax position.


(e)	Includes $55 million of changes in capital expenditures not paid between December 31, 2013 and 2012 related to Antelope Valley.


(f)	See Note 14 — Income Taxes for discussion of the like-kind exchanged tax position.



For the year ended December 31, 2012	Exelon			Generation				ComEd			PECO			BGE
Cash paid (refunded) during the year:
Interest (net of amount capitalized)	$	761		$	286			$	288		$	113		$	136
Income taxes (net of refunds)	(171		)	175				(42		)	(64		)	(112		)
Other non-cash operating activities:
Pension and non-pension postretirement benefit costs	$	820		$	341			$	282		$	50		$	57
Earnings from equity method investments	91			91				—			—			—
Provision for uncollectible accounts	164			22				42			60			44
Provision for excess and obsolete inventory	6			6				1			—			—
Stock-based compensation costs	94			—				—			—			—
Other decommissioning-related activity ^(a)	(145		)	(145		)		—			—			—
Energy-related options ^(b)	160			160				—			—			—
Amortization of regulatory asset related to debt costs	18			—				13			3			2
Amortization of rate stabilization deferral	57			—				—			—			67
Amortization of debt fair value adjustment	(34		)	(34		)		—			—			—
Merger-related commitments ^(c)	141			32				—			—			27
Severance costs	99			34				—			—			—
Discrete impacts from EIMA ^(d)	(96		)	—				(96		)	—			—
Amortization of debt costs	19			11				5			3			2
Other	(30		)	—				5			9			(6		)
Total other non-cash operating activities	$	1,364		$	518			$	252		$	125		$	193
Changes in other assets and liabilities:
Under/over-recovered energy and transmission costs	$	71		$	—			$	28		$	20		$	26
Other regulatory assets and liabilities	(404		)	$	—			(68		)	18			(112		)
Other current assets	213			(30		)		33			(12		)	(7		)
Other noncurrent assets and liabilities	(248		)	(98		)		(95		)	(10		)	8
Total changes in other assets and liabilities	$	(368	)	$	(128	)		$	(102	)	$	16		$	(85	)
Non-cash investing and financing activities:
Change in ARC	$	781		$	781			$	2		$	—		$	—
Change in capital expenditures not paid	160			103			^(e)	15			26			(4		)
Consolidated VIE dividend to noncontrolling interest	7,365			5,264				—			—			—

_________________________


(a)	Includes the elimination of NDT fund activity for the Regulatory Agreement Units, including the elimination of operating revenues, ARO accretion, ARC amortization, investment income and income taxes related to all NDT fund activity for these units. See Note 15 — Asset Retirement Obligations for additional information regarding the accounting for nuclear decommissioning.


(b)	Includes option premiums reclassified to realized at the settlement of the underlying contracts and recorded to results of operations.


(c)	Relates to the integration costs to achieve distribution synergies related to the Constellation merger transaction. See Note 4 — Mergers, Acquisitions, and Dispositions for more information on Constellation merger-related commitments.


(d)	Reflects the change in distribution rates pursuant to EIMA, which allows for the recovery of costs by a utility through pre-established performance-based formula rate tariff. See Note 3 — Regulatory Matters.


(e)	Includes $127 million of changes in capital expenditures not paid between December 31, 2012 and 2011 related to Antelope Valley.

DOE Smart Grid Investment Grant (Exelon, PECO and BGE). For the year ended December 31, 2014, PECO has included in the capital expenditures line item under investing activities of the cash flow statement capital expenditures of $2 million and reimbursements of $5 million related to PECO’s DOE SGIG programs. For the year ended December 31, 2013, Exelon, PECO and BGE have included in the capital expenditures line item under investing activities of the cash flow statement capital expenditures of $74 million, $27 million and $47 million, and reimbursements of $95 million, $37 million and $58 million, related to PECO’s and BGE’s DOE SGIG programs. See Note 3 — Regulatory Matters for additional information regarding the DOE SGIG.

Supplemental Balance Sheet Information

The following tables provide additional information about assets and liabilities of the Registrants at December 31, 2014 and 2013.



December 31, 2014	Exelon		Generation		ComEd		PECO		BGE
Investments
Equity method investments:
Financing trusts^(a)	$	22	$	—	$	6	$	8	$	8
Bloom Energy	13		13		—		—		—
Net Power	9		9		—		—		—
Sunnyside	5		5		—		—		—
Other equity method investments	1		1		—		—		—
Total equity method investments	50		28		6		8		8
Other investments:
Net investment in leases	367		7		—		—		—
Employee benefit trusts and investments^(b)	85		27		—		23		4
Other investments ^(c)	42		42		—		—		—
Total investments	$	544	$	104	$	6	$	31	$	12



December 31, 2013	Exelon		Generation		ComEd		PECO		BGE
Investments
Equity method investments:
Financing trusts^(a)	$	22	$	—	$	6	$	8	$	8
Keystone Fuels, LLC	32		32		—		—		—
Conemaugh Fuels, LLC	21		21		—		—		—
CENG	1,925		1,925		—		—		—
Safe Harbor	285		285		—		—		—
Malacha	8		8		—		—		—
Other equity method investments	2		2		—		—		—
Total equity method investments	2,295		2,273		6		8		8
Other investments:
Net investment in leases	705		7		—		—		—
Employee benefit trusts and investments^(b)	90		23		5		23		5
Other investments ^(c)	22		22		—		—		—
Total investments	$	3,112	$	2,325	$	11	$	31	$	13

_________________________


(a)	Includes investments in affiliated financing trusts, which were not consolidated within the financial statements of Exelon and are shown as investments on the Consolidated Balance Sheets. See Note 1 — Significant Accounting Policies for additional information.


(b)	The Registrants’ investments in these marketable securities are recorded at fair market value.


(c)	Includes cost method and available-for-sale investments.

The following tables provide additional information about liabilities of the Registrants at December 31, 2014 and 2013.



December 31, 2014	Exelon			Generation			ComEd		PECO		BGE
Accrued expenses
Compensation-related accruals^(a)	$	832		$	447		$	153	$	50	$	58
Taxes accrued	305			248			59		3		42
Interest accrued	240			66			102		33		29
Severance accrued	49			33			2		1		2
Other accrued expenses	113		^(b)	92		^(b)	15		4		—
Total accrued expenses	$	1,539		$	886		$	331	$	91	$	131

December 31, 2013	Exelon			Generation			ComEd		PECO		BGE
Accrued expenses
Compensation-related accruals^(a)	$	683		$	337		$	135	$	47	$	55
Taxes accrued	315			212			62		24		16
Interest accrued	234			72			95		32		29
Severance accrued	66			31			3		1		4
Other accrued expenses	335		^(b)	324		^(b)	12		2		7
Total accrued expenses	$	1,633		$	976		$	307	$	106	$	111

_______________________


(a)	Primarily includes accrued payroll, bonuses and other incentives, vacation and benefits.


(b)	Includes $19 million and $228 million for amounts accrued related to Antelope Valley as of December 31, 2014 and December 31, 2013, respectively.