RS-15-094, (EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations

(EGC) - Submittal of Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations

ML15090A537
Person / Time
Site:	Calvert Cliffs, Dresden, Peach Bottom, Salem, Nine Mile Point, Oyster Creek, Byron, Three Mile Island, Braidwood, Limerick, Ginna, Clinton, Quad Cities, LaSalle, 07201036
Issue date:	03/31/2015
From:	Simpson P Exelon Generation Co
To:	Document Control Desk, Office of Nuclear Material Safety and Safeguards, Office of Nuclear Reactor Regulation
References
RS-15-094
Download: ML15090A537 (104)

Text

4300 Winfield Road Warrenville. 60555

'on Generation 630 657 2000 Office RS-15-094 10 CFR 50.75(f) 10 CFR 72.30(b)

March 31, 2015 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001 Braidwood Station, Units 1 and 2 Facility Operating License Nos. NPF-72 and NPF-77 NRC Docket Nos. STN 50-456, STN 50-457, and 72-73 Byron Station, Units 1 and 2 Facility Operating License Nos. NPF-37 and NPF-66 NRC Docket Nos. STN 50-454, STN 50-455, and 72-68 Calvert Cliffs Nuclear Power Plant, Units 1 and 2 Renewed Facility Operating License Nos. DPR-53 and DPR-69 NRC Docket Nos. STN 50-317 and STN 50-318 Clinton Power Station, Unit 1 Facility Operating License No. NPF-62 NRC Docket No. 50-461 Dresden Nuclear Power Station, Units 1, 2 and 3 Facility Operating License No. DPR-2 Renewed Facility Operating License Nos. DPR-19 and DPR-25 NRC Docket Nos. 50-10, 50-237, 50-249, and 72-37 LaSalle County Station, Units 1 and 2 Facility Operating License Nos. NPF-11 and NPF-18 NRC Docket Nos. 50-373, 50-374, and 72-70 Limerick Generating Station, Units 1 and 2 Renewed Facility Operating License Nos. NPF-39 and NPF-85 NRC Docket Nos. 50-352, 50-353, and 72-65 Nine Mile Point Nuclear Station, Units 1 and 2 Renewed Facility Operating License Nos. DPR-63 and DPR-69 NRC Docket Nos. 50-220, 50-410, and 72-1036

March 31, 2015 U. S. Nuclear Regulatory Commission Page 2 Oyster Creek Nuclear Generating Station Renewed Facility Operating License No. DPR-16 NRC Docket No. 50-219 and 72-15 Peach Bottom Atomic Power Station, Units 1, 2, and 3 Facility Operating License No. DPR-12 Renewed Facility Operating License Nos. DPR-44 and DPR-56 NRC Docket Nos. 50-171, 50-277, 50-278, and 72-29 Quad Cities Nuclear Power Station, Units 1 and 2 Renewed Facility Operating License Nos. DPR-29 and DPR-30 NRC Docket Nos. 50-254, 50-265, and 72-53 R.E. Ginna Nuclear Power Plant Renewed Facility Operating License No. DPR-18 NRC Docket Nos. 50-244 and 72-67 Salem Generating Station, Units 1 and 2 Renewed Facility Operating License Nos. DPR-70 and DPR-75 NRC Docket Nos. 50-272, 50-311, and 72-48 Three Mile Island Nuclear Station, Unit 1 Renewed Facility Operating License No. DPR-50 NRC Docket No. 50-289 Calvert Cliffs Nuclear Power Plant, Units 1 and 2 Independent Spent Fuel Storage Installation Materials License No. SNM-2505 NRC Docket No. 72-08

Subject:

Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations

References:

1. Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem," dated December 17, 2012

2. Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Cancellation of Limerick Unit 1 Parent Company Guarantee," dated November 13, 2014

3. Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Submittal of Updated Site-Specific SAFSTOR Decommissioning Cost Estimates for Braidwood Station, Byron Station, and LaSalle County Station," dated February 19, 2015

March 31, 2015 U. S. Nuclear Regulatory Commission Page 3 In accordance with 10 CFR 50.75, "Reporting and recordkeeping for decommissioning planning," paragraph (f), Exelon Generation Company, LLC (EGC) is submitting a report on the status of decommissioning funding for the reactors owned by EGC. Additionally, in accordance with 10 CFR 72.30, "Financial assurance and recordkeeping for decommissioning," EGC is submitting a report on the status of decommissioning funding for the independent spent fuel storage installations (ISFS1s) owned by EGC. Updated decommissioning cost estimates for ISFS1 decommissioning are provided in the attached report. With respect to the other information required by 10 CFR 72.30(b) and (c), there has been no change from the information provided in Reference 1.

In accordance with 10 CFR 50.75(b)(4), 50.75(c), and 50.75(f), the estimated cost of decommissioning for financial assurance is based on either the NRC formula cost amount calculated in accordance with 10 CFR 50.75(c) or on site-specific decommissioning cost estimates. If used in this report, the site-specific decommissioning cost estimates are based on a period of safe storage that is specifically described in the estimates. Site-specific cash flows from the site specific cost estimates are included, as applicable. Unless otherwise noted, the specific cash flow analysis for the site specific decommissioning cost estimates conservatively assumes all expenses in a year are incurred at the beginning of year (i.e.,

beginning of year convention) during the decommissioning period. The cash flow analysis for Peach Bottom Atomic Power Station, Unit 1 assumes that half of the current year contributions are included in the current year earnings to estimate payment of contributions throughout the year (i.e., a mid-year convention). EGC uses a mid-year convention in this instance because the contributions are made monthly at a constant rate throughout the year.

Nine Mile Point Nuclear Station, Unit 2 is co-owned by Constellation Energy Nuclear Group, LLC an EGC subsidiary (82%), and Long Island Power Authority (LIPA) (18%). The information provided in this letter for Nine Mile Point Nuclear Station, Unit 2 includes summary statements provided and verified by LI PA.

For shutdown units, the reporting requirements of 10 CFR 50.82(a)(8)(v) and (vii) are also included in this report.

EGC has not made a final determination of the decommissioning approach for any of its nuclear units. EGC uses the formula cost amount or the site-specific decommissioning cost estimates to demonstrate adequacy of funding to meet regulatory requirements. EGC may select a different decommissioning option in the future for any of its nuclear units, recognizing that the chosen option must meet NRC requirements for decommissioning funding.

As described in Reference 2, EGC has cancelled the parent company guarantee to provide additional decommissioning funding assurance for Limerick Generating Station, Unit 1.

EGC has not obtained parent guarantees to provide financial assurance for any EGC units.

Due to increased costs, as reflected in the updated site-specific decommissioning cost estimates documented in Reference 3, Braidwood Station, Units 1 and 2, and Byron Station, Unit 2, do not currently meet the minimum funding assurance criteria under 10 CFR 50.75 as of December 31, 2014. EGC is currently evaluating the alternate funding mechanisms allowed by 10 CFR 50.75(e) and guidance provided in Regulatory Guide 1.159, "Assuring Availability of Funds for Decommissioning Nuclear Reactors," Revision 2. Consistent with

March 31, 2015 U. S. Nuclear Regulatory Commission Page 4 the guidance in Regulatory Guide 1.159, which provides that "shortfalls identified in a biennial report must be corrected by the time the next biennial report is due," EGC intends to monitor funding assurance and new developments for these units to assess the status of funding assurance and to take such actions as may be necessary to resolve any continuing funding shortfalls for these funds on or before March 31, 2017.

EGC remains confident that sufficient funds will be available to decommission all EGC sites when required. For the three units that have a funding shortfall, EGC is pursuing 20-year license extensions, which if granted would allow an additional 20 years of fund return before decommissioning commences. If license renewal had been granted as of December 31, 2014, Braidwood Units 1 and 2, and Byron Unit 2 would have met the minimum funding assurance requirements.

There were no disbursements from the decommissioning trust funds other than those for allowed administrative costs and other incidental expenses of the fund in connection with the operation of the fund per 10 CFR 50.75(h)(1)(iv).

There are no regulatory commitments contained within this letter.

If you have any questions concerning this letter, please contact Mr. Timothy A Byam at (630) 657-2818.

ectTuHy, R

Patrick R. Simpson Manager Licensing cc: Regional Administrator NRC Region I Regional Administrator NRC Region III NRC Senior Resident Inspector Braidwood Station NRC Senior Resident Inspector Byron Station NRC Senior Resident Inspector Calvert Cliffs Nuclear Power Plant NRC Senior Resident Inspector Clinton Power Station NRC Senior Resident Inspector Dresden Nuclear Power Station NRC Senior Resident Inspector LaSalle County Station NRC Senior Resident Inspector Limerick Generating Station NRC Senior Resident Inspector Nine Mile Point Nuclear Station NRC Senior Resident Inspector Oyster Creek Nuclear Generating Station NRC Senior Resident Inspector Peach Bottom Atomic Power Station NRC Senior Resident Inspector Quad Cities Nuclear Power Station NRC Senior Resident Inspector R. E. Ginna Nuclear Power Plant NRC Senior Resident Inspector Salem Generating Station NRC Senior Resident Inspector Three Mile Island Nuclear Station

March 31, 2015 U. S. Nuclear Regulatory Commission Page 5 Attachments:

1. Labor, Energy, and Burial Factors Used in Calculations (All Facilities)

2. Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1

3. Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2

4. Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1

5. Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2

6. Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 1

7. Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 2

8. Annual Radiological Decommissioning Funding Assurance Report for Clinton Power Station, Unit 1

9. Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1

10. Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 2

11. Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 3

12. Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1

13. Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2

14. Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 1

15. Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 2

16. Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 1

17. Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2 EGC Portion

18. Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2 LIPA Portion

19. Annual Radiological Decommissioning Funding Assurance Report for Oyster Creek Nuclear Generating Station

20. Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1

21. Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 2

22. Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 3

23. Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 1

24. Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 2

25. Annual Radiological Decommissioning Funding Assurance Report for R.E. Ginna Nuclear Power Plant

March 31, 2015 U. S. Nuclear Regulatory Commission Page 6

26. Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 1

27. Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 2

28. Annual Radiological Decommissioning Funding Assurance Report for Three Mile Island Nuclear Station, Unit 1

29. ISFSI Decommissioning Funding Estimates

Attachment 1 Labor, Energy, and Burial Factors Used in Calculations (All Facilities)

ATTACHMENT 1 Labor, Energy, and Burial Factors Used in Calculations (All Facilities)

The labor, energy, and burial indexes used are consistent with those described in NUREG-1307, Revision 15, issued January 2013.

The current labor cost indexes used are obtained from the Employment Cost Index, published by the U.S. Department of Labor, Bureau of Labor Statistics (BLS).

Specifically, EGC used the Employment Cost Index for total compensation for private industry workers by region. The labor adjustment factors were calculated according to Section 3.1 of NUREG-1307, Revision 15, using fourth quarter 2014 data. Table 1 shows the data used for this calculation.

Table 1: Labor Adjustment Factors 4Q2014 Base Labor Index L., Adjustment Region Applicable Sites Series ID Number Factor (Lx)

Northeast Limerick CIU20100000002101 123.2 2.16 2.661 Nine Mile Point Oyster Creek Peach Bottom R.E. Ginna Salem TMI South Calvert Cliffs CIU20100000002201 122.7 1.98 2.429 Midwest Braidwood CIU20100000002301 120.3 2.08 2.502 Byron Clinton Dresden LaSalle Quad Cities The current energy cost indexes used are obtained from Producer Price Indexes (PPI)

Commodities, published by the U.S. Department of Labor, BLS. Specifically, EGC used the PPI for industrial electric power (WPU0543) and light fuel oils (WPU0573). The energy adjustment factors were calculated according to Section 3.2 of NUREG-1307, Revision 15, using December 2014 data. Table 2 shows the data used for this calculation.

Table 2: Energy Adjustment Factors WPU0543 January 1986 (base value) 114.2 WPU0573 January 1986 (base value) 82.0 WPU0543 December 2014 (preliminary value) 214.7 WPU0573 December 2014 (preliminary value) 221.0 Industrial electric power adjustment factor - P, 1.880 Light fuel oil adjustment factor - F, 2.695 Energy Adjustment Factor (PWR) Ex(PWR) 2.222 Energy Adjustment Factor (BWR) Ex(BWR) 2.255 Page 1 of 2

ATTACHMENT 1 (Continued)

Labor, Energy, and Burial Factors Used in Calculations (All Facilities)

The waste burial adjustment factors used are taken from Table 2-1 of NUREG-1307, Revision 15, based on 2012 data. The adjustment factors EGC used assume a combination of compact-affiliated and non-compact facilities, consistent with current waste disposal practices at EGG and consistent with typical waste disposal practices during decommissioning. Table 3 summarizes the data used for the calculation of the waste adjustment factors.

Table 3: Waste Adjustment Factors Combination of Reactor Applicable Compact-LLW Burial Site Type Site Affiliated and Non-Compact Facility Waste Adjustment Factor (Br)

South Carolina site BWR Oyster Creek 14.160 Atlantic Compact South Carolina site PWR Salem 13.885 Atlantic Compact Generic LLW BWR Clinton 14.160 Disposal Site Dresden LaSalle Limerick Nine Mile Point Peach Bottom Quad Cities Generic LLW PWR Braidwood 13.885 Disposal Site Byron Calvert Cliffs R.E. Ginna TM)

The calculation methodology used for all adjustment factors is consistent with NUREG-1307, Revision 15.

Page 2 of 2

Attachment 2 Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1

ATTACHMENT 2 Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $ 521,857 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $ 780,166 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) $4,728 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $ 306,300 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR (e) 50.75(e)(1)(1) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-009, Revision 1, "Decommissioning Cost Analysis for the Braidwood Nuclear Power Station," September 2014). The costs have been escalated from the mid-year 2014 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-009, Revision 1, "Decommissioning Cost Analysis for the Braidwood Nuclear Power Station," September 2014). The costs have been escalated from mid-year 2014 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

Page 1 of 4

ATTACHMENT 2 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1 (December 31,2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) As discussed in the cover letter, EGG is currently evaluating the alternate funding mechanisms, as allowed by 10 CFR 50.75, to address the Braidwood Station, Unit 1 funding shortfall, and meet 10 CFR 50.75 funding assurance requirements consistent with the guidance in Regulatory Guide 1.159, "Assuring Availability of Funds for Decommissioning Nuclear Reactors," Revision 2.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on October 17, 2026.

Page 2 of 4

ATTACHMENT 2 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2026 $10,587 $386,544 $375,956 $1,880 $377,836 2027 $59,386 $377,836 $318,450 $6,369 $324,819 2028 $26,247 $324,819 $298,572 $5,971 $304,543 2029 $7,395 $304,543 $297,149 $5,943 $303,092 2030 $7,395 $303,092 $295,697 $5,914 $301,611 2031 $7,395 $301,611 $294,217 $5,884 $300,101 2032 $7,415 $300,101 $292,686 $5,854 $298,540 2033 $5,787 $298,540 $292,753 $5,855 $298,608 2034 $4,417 $298,608 $294,191 $5,884 $300,074 2035 $4,417 $300,074 $295,658 $5,913 $301,571 2036 $4,429 $301,571 $297,142 $5,943 $303,084 2037 $4,417 $303,084 $298,668 $5,973 $304,641 2038 $4,417 $304,641 $300,224 $6,004 $306,228 2039 $4,417 $306,228 $301,812 $6,036 $307,848 2040 $4,429 $307,848 $303,419 $6,068 $309,487 2041 $4,417 $309,487 $305,070 $6,101 $311,172 2042 $4,417 $311,172 $306,755 $6,135 $312,890 2043 $4,417 $312,890 $308,473 $6,169 $314,642 2044 $4,429 $314,642 $310,213 $6,204 $316,417 2045 $4,417 $316,417 $312,001 $6,240 $318,241 2046 $4,417 $318,241 $313,824 $6,276 $320,100 2047 $4,417 $320,100 $315,683 $6,314 $321,997 2048 $4,429 $321,997 $317,568 $6,351 $323,919 2049 $4,417 $323,919 $319,502 $6,390 $325,892 2050 $4,417 $325,892 $321,475 $6,430 $327,905 2051 $4,417 $327,905 $323,488 $6,470 $329,958 2052 $4,429 $329,958 $325,529 $6,511 $332,039 2053 $4,417 $332,039 $327,622 $6,552 $334,175 2054 $4,417 $334,175 $329,758 $6,595 $336,353 2055 $4,417 $336,353 $331,936 $6,639 $338,575 2056 $4,429 $338,575 $334,146 $6,683 $340,829 2057 $4,417 $340,829 $336,412 $6,728 $343,140 2058 $4,417 $343,140 $338,723 $6,774 $345,497 2059 $4,388 $345,497 $341,110 $6,822 $347,932 2060 $4,400 $347,932 $343,532 $6,871 $350,403 2061 $4,388 $350,403 $346,015 $6,920 $352,935 2062 $4,388 $352,935 $348,547 $6,971 $355,518 2063 $4,388 $355,518 $351,131 $7,023 $358,153 2064 $4,400 $358,153 $353,753 $7,075 $360,829 2065 $4,388 $360,829 $356,441 $7,129 $363,570 Page 3 of 4

ATTACHMENT 2 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2066 $4,388 $363,570 $359,182 $7,184 $366,366 2067 $4,388 $366,366 $361,978 $7,240 $369,217 2068 $4,400 $369,217 $364,818 $7,296 $372,114 2069 $4,388 $372,114 $367,726 $7,355 $375,081 2070 $4,388 $375,081 $370,693 $7,414 $378,107 2071 $4,388 $378,107 $373,719 $7,474 $381,193 2072 $4,400 $381,193 $376,794 $7,536 $384,329 2073 $4,388 $384,329 $379,942 $7,599 $387,541 2074 $4,388 $387,541 $383,153 $7,663 $390,816 2075 $4,388 $390,816 $386,428 $7,729 $394,157 2076 $4,400 $394,157 $389,757 $7,795 $397,552 2077 $4,388 $397,552 $393,164 $7,863 $401,028 2078 $4,388 $401,028 $396,640 $7,933 $404,573 2079 $33,613 $404,573 $370,960 $7,419 $378,379 2080 $77,868 $378,379 $300,511 $6,010 $306,521 2081 $143,743 $306,521 $162,778 $3,256 $166,034 2082 $83,433 $1,420 $166,034 $81,180 $1,624 $82,804 2083 $53,154 $2,133 $82,804 $27,517 $550 $28,067 2084 $30,567 $1,174 $28,067 $(3,675) $(3,675) 2085 $2,868 $(3,675) $(6,542) $(6,542) 2086 $24,797 $(6,542) $(31,339) $(31,339) 2087 $91 $(31,339) $(31,430) $(31,430) 2088 $91 $(31,430) $(31,521) $(31,521) 2089 $24 $(31,521) $(31,545) $(31,545)

Total* $780,166 $4,728

• Columns may not add due to rounding Page 4 of 4

Attachment 3 Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2

ATTACHMENT 3 Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $521,857 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $849,702 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) $4,728 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $330,908 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR (e) 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGG) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-009, Revision 1, "Decommissioning Cost Analysis for the Braidwood Nuclear Power Station," September 2014). The costs have been escalated from the mid-year 2014 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGG) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from Patrick R. Simpson (EGG) to U.S. NRC dated February 19, 2015, (TLG Report E16-1640-009, Revision 1, "Decommissioning Cost Analysis for the Braidwood Nuclear Power Station," September 2014). The costs have been escalated from mid-year 2014 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

Page 1 of 4

ATTACHMENT 3 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2 (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) As discussed in the cover letter, EGC is currently evaluating the alternate funding mechanisms, as allowed by 10 CFR 50.75, to address the Braidwood Station, Unit 2 funding shortfall, and meet 10 CFR 50.75 funding assurance requirements consistent with the guidance in Regulatory Guide 1.159, "Assuring Availability of Funds for Decommissioning Nuclear Reactors," Revision 2.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on December 18, 2027.

Page 2 of 4

ATTACHMENT 3 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2027 $2,191 $427,359 $425,168 $709 $425,876 2028 $59,339 $425,876 $366,538 $7,331 $373,869 2029 $61,358 $373,869 $312,511 $6,250 $318,761 2030 $9,839 $318,761 $308,922 $6,178 $315,100 2031 $9,839 $315,100 $305,261 $6,105 $311,366 2032 $9,866 $311,366 $301,499 $6,030 $307,529 2033 $6,942 $307,529 $300,587 $6,012 $306,599 2034 $4,472 $306,599 $302,127 $6,043 $308,170 2035 $4,472 $308,170 $303,698 $6,074 $309,772 2036 $4,484 $309,772 $305,288 $6,106 $311,394 2037 $4,472 $311,394 $306,922 $6,138 $313,060 2038 $4,472 $313,060 $308,589 $6,172 $314,760 2039 $4,472 $314,760 $310,289 $6,206 $316,495 2040 $4,484 $316,495 $312,011 $6,240 $318,251 2041 $4,472 $318,251 $313,779 $6,276 $320,055 2042 $4,472 $320,055 $315,583 $6,312 $321,895 2043 $4,472 $321,895 $317,423 $6,348 $323,771 2044 $4,484 $323,771 $319,287 $6,386 $325,673 2045 $4,472 $325,673 $321,201 $6,424 $327,625 2046 $4,472 $327,625 $323,154 $6,463 $329,617 2047 $4,472 $329,617 $325,145 $6,503 $331,648 2048 $4,484 $331,648 $327,164 $6,543 $333,707 2049 $4,472 $333,707 $329,236 $6,585 $335,820 2050 $4,472 $335,820 $331,349 $6,627 $337,976 2051 $4,472 $337,976 $333,504 $6,670 $340,174 2052 $4,484 $340,174 $335,690 $6,714 $342,404 2053 $4,472 $342,404 $337,932 $6,759 $344,691 2054 $4,472 $344,691 $340,219 $6,804 $347,023 2055 $4,472 $347,023 $342,552 $6,851 $349,403 2056 $4,484 $349,403 $344,919 $6,898 $351,817 2057 $4,472 $351,817 $347,345 $6,947 $354,292 2058 $4,472 $354,292 $349,821 $6,996 $356,817 2059 $4,457 $356,817 $352,360 $7,047 $359,407 2060 $4,469 $359,407 $354,938 $7,099 $362,037 2061 $4,457 $362,037 $357,580 $7,152 $364,732 2062 $4,457 $364,732 $360,275 $7,206 $367,481 2063 $4,457 $367,481 $363,024 $7,260 $370,285 2064 $4,469 $370,285 $365,816 $7,316 $373,132 2065 $4,457 $373,132 $368,675 $7,374 $376,049 2066 $4,457 $376,049 $371,592 $7,432 $379,024 Page 3 of 4

ATTACHMENT 3 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2067 $4,457 $379,024 $374,567 $7,491 $382,058 2068 $4,469 $382,058 $377,589 $7,552 $385,141 2069 $4,457 $385,141 $380,685 $7,614 $388,298 2070 $4,457 $388,298 $383,841 $7,677 $391,518 2071 $4,457 $391,518 $387,062 $7,741 $394,803 2072 $4,469 $394,803 $390,334 $7,807 $398,141 2073 $4,457 $398,141 $393,684 $7,874 $401,557 2074 $4,457 $401,557 $397,101 $7,942 $405,043 2075 $4,457 $405,043 $400,586 $8,012 $408,598 2076 $4,469 $408,598 $404,129 $8,083 $412,211 2077 $4,457 $412,211 $407,755 $8,155 $415,910 2078 $4,457 $415,910 $411,453 $8,229 $419,682 2079 $4,457 $419,682 $415,225 $8,305 $423,530 2080 $23,018 $423,530 $400,511 $8,010 $408,522 2081 $55,896 $408,522 $352,626 $7,053 $359,678 2082 $130,092 $359,678 $229,586 $4,592 $234,178 2083 $93,873 $1,159 $234,178 $139,145 $2,783 $141,928 2084 $75,671 $1,753 $141,928 $64,504 $1,290 $65,794 2085 $75,464 $1,749 $65,794 $(11,419) $(11,419) 2086 $30,706 $67 $(11,419) $(42,192) $(42,192) 2087 $39 $(42,192) $(42,231) $(42,231) 2088 $39 $(42,231) $(42,270) $(42,270) 2089 $10 $(42,270) $(42,280) $(42,280)

Total* $849,702 $4,728

• Columns may not add due to rounding Page 4 of 4

Attachment 4 Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1

ATTACHMENT 4 Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $521,857 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $780,504 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) $4,604 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $336,095 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-012, Revision 1, "Decommissioning Cost Analysis for the Byron Nuclear Power Station," September 2014). The costs have been escalated from the mid-year 2014 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-012, Revision 1, "Decommissioning Cost Analysis for the Byron Nuclear Power Station," September 2014). The costs have been escalated from mid-year 2014 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

Page 1 of 4

ATTACHMENT 4 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1 (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on October 31, 2024.

Page 2 of 4

ATTACHMENT 4 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2024 $8,696 $407,675 $398,979 $1,995 $400,974 2025 $58,354 $400,974 $342,620 $6,852 $349,473 2026 $31,217 $349,473 $318,255 $6,365 $324,621 2027 $8,119 $324,621 $316,502 $6,330 $322,832 2028 $8,141 $322,832 $314,691 $6,294 $320,984 2029 $8,119 $320,984 $312,865 $6,257 $319,123 2030 $8,119 $319,123 $311,004 $6,220 $317,224 2031 $8,119 $317,224 $309,105 $6,182 $315,287 2032 $5,693 $315,287 $309,594 $6,192 $315,786 2033 $4,395 $315,786 $311,391 $6,228 $317,619 2034 $4,395 $317,619 $313,223 $6,264 $319,487 2035 $4,395 $319,487 $315,092 $6,302 $321,394 2036 $4,408 $321,394 $316,986 $6,340 $323,326 2037 $4,395 $323,326 $318,931 $6,379 $325,309 2038 $4,395 $325,309 $320,914 $6,418 $327,332 2039 $4,395 $327,332 $322,936 $6,459 $329,395 2040 $4,408 $329,395 $324,988 $6,500 $331,487 2041 $4,395 $331,487 $327,092 $6,542 $333,634 2042 $4,395 $333,634 $329,238 $6,585 $335,823 2043 $4,395 $335,823 $331,428 $6,629 $338,056 2044 $4,408 $338,056 $333,649 $6,673 $340,322 2045 $4,395 $340,322 $335,926 $6,719 $342,645 2046 $4,395 $342,645 $338,249 $6,765 $345,014 2047 $4,395 $345,014 $340,619 $6,812 $347,431 2048 $4,408 $347,431 $343,023 $6,860 $349,884 2049 $4,395 $349,884 $345,488 $6,910 $352,398 2050 $4,395 $352,398 $348,003 $6,960 $354,963 2051 $4,367 $354,963 $350,596 $7,012 $357,608 2052 $4,379 $357,608 $353,230 $7,065 $360,294 2053 $4,367 $360,294 $355,928 $7,119 $363,046 2054 $4,367 $363,046 $358,680 $7,174 $365,853 2055 $4,367 $365,853 $361,487 $7,230 $368,716 2056 $4,379 $368,716 $364,338 $7,287 $371,625 2057 $4,367 $371,625 $367,258 $7,345 $374,603 2058 $4,367 $374,603 $370,237 $7,405 $377,641 2059 $4,367 $377,641 $373,275 $7,465 $380,740 2060 $4,379 $380,740 $376,362 $7,527 $383,889 2061 $4,367 $383,889 $379,522 $7,590 $387,113 2062 $4,367 $387,113 $382,746 $7,655 $390,401 2063 $4,367 $390,401 $386,035 $7,721 $393,755 Page 3 of 4

ATTACHMENT 4 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2064 $4,379 $393,755 $389,377 $7,788 $397,164 2065 $4,367 $397,164 $392,798 $7,856 $400,654 2066 $4,367 $400,654 $396,287 $7,926 $404,213 2067 $4,367 $404,213 $399,846 $7,997 $407,843 2068 $4,379 $407,843 $403,465 $8,069 $411,534 2069 $4,367 $411,534 $407,168 $8,143 $415,311 2070 $4,367 $415,311 $410,944 $8,219 $419,163 2071 $4,367 $419,163 $414,797 $8,296 $423,093 2072 $4,379 $423,093 $418,714 $8,374 $427,088 2073 $4,367 $427,088 $422,722 $8,454 $431,176 2074 $4,367 $431,176 $426,810 $8,536 $435,346 2075 $4,367 $435,346 $430,979 $8,620 $439,599 2076 $4,379 $439,599 $435,220 $8,704 $443,925 2077 $32,042 $443,925 $411,883 $8,238 $420,120 2078 $74,011 $420,120 $346,109 $6,922 $353,031 2079 $142,093 $353,031 $210,939 $4,219 $215,158 2080 $85,249 $1,303 $215,158 $128,605 $2,572 $131,177 2081 $51,491 $2,077 $131,177 $77,608 $1,552 $79,161 2082 $31,523 $1,224 $79,161 $46,414 $928 $47,342 2083 $2,902 $47,342 $44,440 $889 $45,329 2084 $23,619 $45,329 $21,709 $434 $22,143 2085 $93 $22,143 $22,050 $441 $22,491 2086 $93 $22,491 $22,398 $448 $22,846 2087 $29 $22,846 $22,817 $456 $23,273 Total* $780,504 $4,604

• Columns may not add due to rounding Page 4 of 4

Attachment 5 Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2

ATTACHMENT 5 Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $521,857 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $839,566 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) $4,604 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $323,772 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR (e) 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-012, Revision 1, "Decommissioning Cost Analysis for the Byron Nuclear Power Station," September 2014). The costs have been escalated from the mid-year 2014 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report El 6-1640-012, Revision 1, "Decommissioning Cost Analysis for the Byron Nuclear Power Station," September 2014). The costs have been escalated from mid-year 2014 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

Page 1 of 4

ATTACHMENT 5 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2 (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) As discussed in the cover letter, EGC is currently evaluating the alternate funding mechanisms, as allowed by 10 CFR 50.75, to address the Byron Station, Unit 2 funding shortfall, and meet 10 CFR 50.75 funding assurance requirements consistent with the guidance in Regulatory Guide 1.159, "Assuring Availability of Funds for Decommissioning Nuclear Reactors," Revision 2.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on November 6, 2026.

Page 2 of 4

ATTACHMENT 5 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2026 $8,737 $409,268 $400,532 $1,335 $401,867 2027 $65,169 $401,867 $336,698 $6,734 $343,432 2028 $52,270 $343,432 $291,161 $5,823 $296,985 2029 $11,616 $296,985 $285,369 $5,707 $291,076 2030 $11,616 $291,076 $279,460 $5,589 $285,050 2031 $11,616 $285,050 $273,434 $5,469 $278,903 2032 $6,894 $278,903 $272,008 $5,440 $277,448 2033 $4,387 $277,448 $273,062 $5,461 $278,523 2034 $4,387 $278,523 $274,136 $5,483 $279,619 2035 $4,387 $279,619 $275,232 $5,505 $280,737 2036 $4,399 $280,737 $276,338 $5,527 $281,865 2037 $4,387 $281,865 $277,478 $5,550 $283,027 2038 $4,387 $283,027 $278,640 $5,573 $284,213 2039 $4,387 $284,213 $279,826 $5,597 $285,423 2040 $4,399 $285,423 $281,024 $5,620 $286,645 2041 $4,387 $286,645 $282,258 $5,645 $287,903 2042 $4,387 $287,903 $283,516 $5,670 $289,187 2043 $4,387 $289,187 $284,800 $5,696 $290,496 2044 $4,399 $290,496 $286,097 $5,722 $291,819 2045 $4,387 $291,819 $287,432 $5,749 $293,181 2046 $4,387 $293,181 $288,794 $5,776 $294,570 2047 $4,387 $294,570 $290,183 $5,804 $295,987 2048 $4,399 $295,987 $291,588 $5,832 $297,420 2049 $4,387 $297,420 $293,033 $5,861 $298,893 2050 $4,387 $298,893 $294,507 $5,890 $300,397 2051 $4,372 $300,397 $296,025 $5,920 $301,945 2052 $4,384 $301,945 $297,561 $5,951 $303,512 2053 $4,372 $303,512 $299,140 $5,983 $305,123 2054 $4,372 $305,123 $300,751 $6,015 $306,766 2055 $4,372 $306,766 $302,394 $6,048 $308,442 2056 $4,384 $308,442 $304,058 $6,081 $310,139 2057 $4,372 $310,139 $305,767 $6,115 $311,882 2058 $4,372 $311,882 $307,510 $6,150 $313,660 2059 $4,372 $313,660 $309,288 $6,186 $315,474 2060 $4,384 $315,474 $311,090 $6,222 $317,312 2061 $4,372 $317,312 $312,939 $6,259 $319,198 2062 $4,372 $319,198 $314,826 $6,297 $321,123 2063 $4,372 $321,123 $316,751 $6,335 $323,086 2064 $4,384 $323,086 $318,702 $6,374 $325,076 2065 $4,372 $325,076 $320,704 $6,414 $327,118 Page 3 of 4

ATTACHMENT 5 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2066 $4,372 $327,118 $322,746 $6,455 $329,200 2067 $4,372 $329,200 $324,828 $6,497 $331,325 2068 $4,384 $331,325 $326,941 $6,539 $333,480 2069 $4,372 $333,480 $329,108 $6,582 $335,690 2070 $4,372 $335,690 $331,318 $6,626 $337,944 2071 $4,372 $337,944 $333,572 $6,671 $340,243 2072 $4,384 $340,243 $335,859 $6,717 $342,576 2073 $4,372 $342,576 $338,204 $6,764 $344,968 2074 $4,372 $344,968 $340,596 $6,812 $347,408 2075 $4,372 $347,408 $343,036 $6,861 $349,897 2076 $4,384 $349,897 $345,513 $6,910 $352,423 2077 $4,372 $352,423 $348,051 $6,961 $355,012 2078 $22,011 $355,012 $333,001 $6,660 $339,661 2079 $51,953 $339,661 $287,708 $5,754 $293,462 2080 $128,622 $293,462 $164,840 $3,297 $168,137 2081 $93,813 $1,064 $168,137 $73,261 $1,465 $74,726 2082 $72,897 $1,703 $74,726 $126 $3 $129 2083 $72,897 $1,703 $129 $(74,471) $(74,471) 2084 $32,223 $135 $(74,471) $(106,829) $(106,829) 2085 $40 $(106,829) $(106,869) $(106,869) 2086 $40 $(106,869) $(106,909) $(106,909) 2087 $12 $(106,909) $(106,921) $(106,921)

Total* $839,556 $4,604

• Columns may not add due to rounding Page 4 of 4

Attachment 6 Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 1

ATTACHMENT 6 Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $487,775 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $4,486 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $341,609 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 There are no material changes to the trust fund agreements.

(a) The site-specific decommissioning funding plan was previously provided in a letter from Stephen A. Mormann (Constellation Energy Nuclear Group, LLC) to U. S. NRC, dated December 17, 2012 ("ISFSI Decommissioning Funding Plans"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a site specific escalation rate.

Excluding the site-specific cost and escalation of the cost, the decommissioning funding plan is consistent with the decommissioning funding plan for the other EGC sites as detailed in the previously provided letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem").

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on July 31, 2034.

Page 1 of 1

Attachment 7 Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 2

ATTACHMENT 7 Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $487,775 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $4,486 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $437,386 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 There are no material changes to the trust fund agreements.

(a) The site-specific decommissioning funding plan was previously provided in a letter from Stephen A. Mormann (Constellation Energy Nuclear Group, LLC) to U. S. NRC, dated December 17, 2012 ("ISFSI Decommissioning Funding Plans"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a site specific escalation rate.

Excluding the site-specific cost and escalation of the cost, the decommissioning funding plan is consistent with the decommissioning funding plan for the other EGC sites as detailed in the previously provided letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem").

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on August 13, 2036.

Page 1 of 1

Attachment 8 Annual Radiological Decommissioning Funding Assurance Report for Clinton Power Station, Unit 1

ATTACHMENT 8 Annual Radiological Decommissioning Funding Assurance Report for Clinton Power Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $679,698 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $996,672 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) N/A (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $500,932 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated March 1, 2013 (TLG Report E16-1640-006, Revision 0, "Decommissioning Cost Analysis for the Clinton Power Station," December 2012). The costs have been escalated from 2012 dollars in the decommissioning cost estimate to December 31, 2014.

(b) Clinton, Unit 1 does not have an ISFSI. Therefore, 10 CFR 72 does not apply to Clinton, Unit 1.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on September 29, 2026.

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ATTACHMENT 8 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Clinton Power Station, Unit 1 (December 31, 2014 dollars, thousands)

Site BOY BOY EOY Radiological Trust Trust Fund Trust Trust Decommissioning Fund Value Fund Fund Year Cost Value Less Cost Earnings Value 2026 $16,626 $631,123 $614,496 $4,097 $618,593 2027 $98,213 $618,593 $520,380 $10,408 $530,787 2028 $25,592 $530,787 $505,196 $10,104 $515,300 2029 $7,197 $515,300 $508,102 $10,162 $518,264 2030 $7,197 $518,264 $511,067 $10,221 $521,288 2031 $7,197 $521,288 $514,091 $10,282 $524,373 2032 $4,883 $524,373 $519,490 $10,390 $529,879 2033 $4,133 $529,879 $525,746 $10,515 $536,261 2034 $4,133 $536,261 $532,128 $10,643 $542,771 2035 $4,133 $542,771 $538,638 $10,773 $549,410 2036 $4,144 $549,410 $545,266 $10,905 $556,171 2037 $4,133 $556,171 $552,038 $11,041 $563,079 2038 $4,133 $563,079 $558,946 $11,179 $570,125 2039 $4,133 $570,125 $565,992 $11,320 $577,312 2040 $4,144 $577,312 $573,167 $11,463 $584,630 2041 $4,133 $584,630 $580,497 $11,610 $592,107 2042 $4,133 $592,107 $587,974 $11,759 $599,734 2043 $4,133 $599,734 $595,601 $11,912 $607,513 2044 $4,152 $607,513 $603,360 $12,067 $615,428 2045 $7,018 $615,428 $608,410 $12,168 $620,578 2046 $7,018 $620,578 $613,560 $12,271 $625,831 2047 $7,018 $625,831 $618,813 $12,376 $631,189 2048 $7,037 $631,189 $624,152 $12,483 $636,635 2049 $7,018 $636,635 $629,617 $12,592 $642,209 2050 $7,018 $642,209 $635,191 $12,704 $647,895 2051 $7,018 $647,895 $640,877 $12,818 $653,695 2052 $7,037 $653,695 $646,657 $12,933 $659,590 2053 $7,018 $659,590 $652,572 $13,051 $665,624 2054 $7,018 $665,624 $658,606 $13,172 $671,778 2055 $7,018 $671,778 $664,760 $13,295 $678,055 2056 $7,037 $678,055 $671,018 $13,420 $684,438 2057 $7,018 $684,438 $677,420 $13,548 $690,969 2058 $7,018 $690,969 $683,951 $13,679 $697,630 2059 $7,018 $697,630 $690,612 $13,812 $704,424 2060 $7,037 $704,424 $697,387 $13,948 $711,334 2061 $7,018 $711,334 $704,316 $14,086 $718,403 2062 $7,018 $718,403 $711,385 $14,228 $725,612 2063 $7,018 $725,612 $718,594 $14,372 $732,966 2064 $7,037 $732,966 $725,929 $14,519 $740,448 2065 $7,018 $740,448 $733,430 $14,669 $748,098 Page 2 of 3

ATTACHMENT 8 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Clinton Power Station, Unit 1 (December 31, 2014 dollars, thousands)

Site BOY BOY EOY Radiological Trust Trust Fund Trust Trust Decommissioning Fund Value Fund Fund Year Cost Value Less Cost Earnings Value 2066 $7,018 $748,098 $741,080 $14,822 $755,902 2067 $7,018 $755,902 $748,884 $14,978 $763,861 2068 $7,037 $763,861 $756,824 $15,136 $771,961 2069 $7,018 $771,961 $764,943 $15,299 $780,241 2070 $7,018 $780,241 $773,223 $15,464 $788,688 2071 $7,018 $788,688 $781,670 $15,633 $797,303 2072 $7,037 $797,303 $790,266 $15,805 $806,071 2073 $7,018 $806,071 $799,053 $15,981 $815,034 2074 $7,018 $815,034 $808,016 $16,160 $824,177 2075 $7,018 $824,177 $817,159 $16,343 $833,502 2076 $7,037 $833,502 $826,465 $16,529 $842,994 2077 $7,018 $842,994 $835,976 $16,720 $852,695 2078 $7,018 $852,695 $845,677 $16,914 $862,591 2079 $7,018 $862,591 $855,573 $17,111 $872,684 2080 $21,714 $872,684 $850,971 $17,019 $867,990 2081 $62,618 $867,990 $805,372 $16,107 $821,479 2082 $123,258 $821,479 $698,222 $13,964 $712,186 2083 $114,762 $712,186 $597,424 $11,948 $609,373 2084 $86,362 $609,373 $523,011 $10,460 $533,471 2085 $86,035 $533,471 $447,435 $8,949 $456,384 2086 $39,384 $456,384 $417,000 $8,340 $425,340 2087 $104 $425,340 $425,236 $8,505 $433,741 2088 $104 $433,741 $433,636 $8,673 $442,309 2089 $1 $442,309 $442,309 $8,846 $451,155 Total* $996,672

• Column may not add due to rounding Page 3 of 3

Attachment 9 Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1

ATTACHMENT 9 Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) N/A (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) and 50.75(f) $398,668 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) N/A (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $354,697 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation for decommissioning costs, earnings on funds, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) .

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

10 2014 annual amount spent on decommissioning in $5,225 (e) accordance with 10 CFR 50.82(a)(8)(v)(A).

11 Cumulative amount spent on decommissioning in $114,481 (f) accordance with 10 CFR 50.82(a)(8)(v)(A).

Reimbursed from the decommissioning trust fund $86,848 (f)

Not yet reimbursed from the decommissioning trust fund $27,633 12 Amount of funds accumulated to cover the cost of managing $12,963 irradiated fuel pursuant to 10 CFR 50.82(a)(8)(vii)(A) as of December 31, 2014.

13 Projected cost of managing irradiated fuel based on site- $14,569(a) specific estimate per 10 CFR 50.82(a)(8)(vii)(B).

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ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2014 dollars, thousands)

(a) A formula cost amount using the formula in 10 CFR 50.75(c) is not applicable because Dresden Unit 1 has been shutdown since October 31, 1978 and some decommissioning activities have already occurred on this unit. However, the amount to decommission Dresden Unit 1 was calculated pursuant to 10 CFR 50.75(c) to be

$578.0 million (as of December 31, 2014). Dresden Unit 1 was a BWR reactor that operated at a maximum power level of 700 MWt (< 1200 MWt as specified in 10 CFR 50.75(c)). This amount assumes Dresden Unit 1 was a BWR reactor type rated at a power capacity of 1200 MWt as required by the formula in 10 CFR 50.75(c). The calculation of this value assumes the labor, energy, and burial factors described in Attachment 1 and does not account for decommissioning activities that have occurred for Dresden Unit 1.

In accordance with the regulatory requirements, the site-specific amount is reported per 10 CFR 50.75(b)(4), 50.75(f), 50.82(a)(8)(iii), and 50.82(a)(8)(v)(B) and assumes a DECON scenario as described in the site-specific cost estimate (SSCE) (TLG Report E16-1640-004, Revision 0, "Decommissioning Cost Analysis for the Dresden Nuclear Power Station Unit 1," August 2012). The decommissioning cost estimate has been adjusted consistent with the description of planned decommissioning activities in the Dresden Nuclear Power Station, Unit 1, Post-Shutdown Decommissioning Activities Report (PSDAR), as most recently updated in a letter from K.R. Jury (EGC) to U.S. NRC on January 5, 2007. The costs have been escalated from the 2012 dollars reflected in the 2012 decommissioning cost estimate to estimated costs as of December 31, 2014.

Decommissioning expenditures prior to the year the SSCE updates were prepared (historical expenditures) are not included in the estimated total cost of decommissioning in the final SSCE reports. Also, the amount reported does not include cash flows from the SSCE estimate for the 2012, 2013, and 2014 annual radiological cost because EGC considers the SSCE estimated cost for 2012, 2013, and 2014 decommissioning activities to be historical expenditures at the time the 2015 decommissioning funding assurance report is generated.

Decontamination and dismantlement of Dresden Nuclear Power Station, Unit 1, will take place beginning in 2029, coinciding with the decommissioning of Dresden Nuclear Power Station, Unit 2.

(b) ISFSI decommissioning cost is included in the Dresden Nuclear Power Station, Unit 2 and Unit 3 site-specific cost estimates.

Page 2 of 5

ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGG has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) The amount spent on decommissioning in 2014 is consistent with the amount budgeted at the station. Even though the amount exceeds the projected 2014 expense total of $2,975 (December 31, 2013 thousands of dollars) from the site-specific cost estimate, it is immaterial to the overall funding assurance analysis. The

$2,250 (thousands of dollars) difference between actual and projected is the result of two major projects to remove the DAW pit (completed) and to remove T-104 NB tank and pump house concrete (partial demolition occurred in 2013, demolition was completed in 2014) that were scoped in and approved above baseline budget. These costs are accounted for in the SSCE but projected to occur later in the SSCE and will be removed during the next update so costs will only be over predicted in the short-term.

(f) Not all historical data was available, and therefore, the cumulative amounts spent on decommissioning are estimates based on the best information obtainable at this time.

Page 3 of 5

ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2014 dollars, thousands)

BOY BOY EOY Radiological Trust Trust Fund Trust Trust Decommissioning Fund Value Fund Fund Year Cost Value Less Cost Earnings Value 2015 $3,031 $354,697 $351,666 $7,033 $358,700 2016 $3,039 $358,700 $355,660 $7,113 $362,774 2017 $3,031 $362,774 $359,743 $7,195 $366,938 2018 $3,031 $366,938 $363,907 $7,278 $371,185 2019 $3,031 $371,185 $368,154 $7,363 $375,517 2020 $3,039 $375,517 $372,478 $7,450 $379,928 2021 $3,031 $379,928 $376,897 $7,538 $384,435 2022 $3,031 $384,435 $381,404 $7,628 $389,032 2023 $3,031 $389,032 $386,001 $7,720 $393,721 2024 $3,039 $393,721 $390,682 $7,814 $398,495 2025 $3,031 $398,495 $395,465 $7,909 $403,374 2026 $3,031 $403,374 $400,343 $8,007 $408,350 2027 $3,031 $408,350 $405,319 $8,106 $413,425 2028 $3,039 $413,425 $410,386 $8,208 $418,594 2029 $38,103 $418,594 $380,491 $7,610 $388,101 2030 $81,035 $388,101 $307,066 $6,141 $313,207 2031 $88,082 $313,207 $225,125 $4,503 $229,628 2032 $64,116 $229,628 $165,512 $3,310 $168,822 2033 $48,220 $168,822 $120,602 $2,412 $123,014 2034 $2,240 $123,014 $120,774 $2,415 $123,189 2035 $2,240 $123,189 $120,949 $2,419 $123,368 2036 $2,246 $123,368 $121,122 $2,422 $123,544 2037 $18,228 $123,544 $105,317 $2,106 $107,423 2038 $6,645 $107,423 $100,777 $2,016 $102,793 2039 $92 $102,793 $102,701 $2,054 $104,755 2040 $52 $104,755 $104,702 $2,094 $106,797 2041 $106,797 $106,797 $2,136 $108,932 2042 $4,903 $108,932 $104,030 $2,081 $106,110 Total* $398,668

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ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2014 dollars, thousands)

BOY BOY EOY Irradiated Irradiated Irradiated Irradiated Irradiated Fuel Fuel Fuel Fuel Fuel Trust Fund Trust Fund Trust Fund Trust Fund Year Cost Value Less Cost Earnings Value 2015 $12,963 $12,963 $259 $13,222 2016 $13,222 $13,222 $264 $13,486 2017 $13,486 $13,486 $270 $13,756 2018 $13,756 $13,756 $275 $14,031 2019 $14,031 $14,031 $281 $14,312 2020 $14,312 $14,312 $286 $14,598 2021 $14,598 $14,598 $292 $14,890 2022 $14,890 $14,890 $298 $15,188 2023 $15,188 $15,188 $304 $15,491 2024 $15,491 $15,491 $310 $15,801 2025 $15,801 $15,801 $316 $16,117 2026 $16,117 $16,117 $322 $16,440 2027 $16,440 $16,440 $329 $16,768 2028 $16,768 $16,768 $335 $17,104 2029 $815 $17,104 $16,288 $326 $16,614 2030 $581 $16,614 $16,033 $321 $16,354 2031 $499 $16,354 $15,854 $317 $16,172 2032 $501 $16,172 $15,671 $313 $15,984 2033 $499 $15,984 $15,485 $310 $15,795 2034 $499 $15,795 $15,296 $306 $15,602 2035 $499 $15,602 $15,103 $302 $15,405 2036 $501 $15,405 $14,904 $298 $15,202 2037 $2,008 $15,202 $13,194 $264 $13,458 2038 $683 $13,458 $12,775 $255 $13,030 2039 $731 $13,030 $12,299 $246 $12,545 2040 $1,453 $12,545 $11,092 $222 $11,314 2041 $2,373 $11,314 $8,941 $179 $9,120 2042 $2,370 $9,120 $6,751 $135 $6,886 2043 $557 $6,886 $6,328 $127 $6,455 Total* $14,569

• Column may not add due to rounding Page 5 of 5

Attachment 10 Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 2

ATTACHMENT 10 Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $657,611 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $2,291 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $619,880 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on December 22, 2029.

Page 1 of 1

Attachment 11 Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 3

ATTACHMENT 11 Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 3 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $657,611 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $2,290 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $633,769 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on January 12, 2031.

Page 1 of 1

Attachment 12 Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1

ATTACHMENT 12 Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $679,698 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $910,428 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) $6,253 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $453,349 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-014, Revision 0, "Decommissioning Cost Analysis for the LaSalle County Station Units 1 and 2," December 2014). The costs have been escalated from the mid-year 2014 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-014, Revision 0, "Decommissioning Cost Analysis for the LaSalle County Station Units 1 and 2," December 2014). The costs have been escalated from mid-year 2014 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

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ATTACHMENT 12 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1 (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGO has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on April 17, 2022.

Page 2 of 4

ATTACHMENT 12 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2022 $48,323 $523,340 $475,017 $7,125 $482,142 2023 $68,988 $482,142 $413,154 $8,263 $421,417 2024 $9,904 $421,417 $411,513 $8,230 $419,743 2025 $9,877 $419,743 $409,866 $8,197 $418,063 2026 $9,877 $418,063 $408,186 $8,164 $416,350 2027 $8,794 $416,350 $407,556 $8,151 $415,707 2028 $4,687 $415,707 $411,020 $8,220 $419,240 2029 $4,675 $419,240 $414,565 $8,291 $422,857 2030 $4,675 $422,857 $418,182 $8,364 $426,546 2031 $4,675 $426,546 $421,871 $8,437 $430,308 2032 $4,687 $430,308 $425,621 $8,512 $434,133 2033 $4,675 $434,133 $429,459 $8,589 $438,048 2034 $4,675 $438,048 $433,373 $8,667 $442,041 2035 $4,675 $442,041 $437,366 $8,747 $446,113 2036 $4,687 $446,113 $441,426 $8,829 $450,254 2037 $4,675 $450,254 $445,580 $8,912 $454,491 2038 $4,675 $454,491 $449,817 $8,996 $458,813 2039 $4,675 $458,813 $454,138 $9,083 $463,221 2040 $4,687 $463,221 $458,534 $9,171 $467,704 2041 $4,675 $467,704 $463,030 $9,261 $472,290 2042 $4,646 $472,290 $467,645 $9,353 $476,998 2043 $4,646 $476,998 $472,352 $9,447 $481,799 2044 $4,658 $481,799 $477,140 $9,543 $486,683 2045 $4,646 $486,683 $482,037 $9,641 $491,678 2046 $4,646 $491,678 $487,032 $9,741 $496,773 2047 $4,646 $496,773 $492,127 $9,843 $501,970 2048 $4,658 $501,970 $497,311 $9,946 $507,258 2049 $4,646 $507,258 $502,612 $10,052 $512,664 2050 $4,646 $512,664 $508,019 $10,160 $518,179 2051 $4,646 $518,179 $513,533 $10,271 $523,804 2052 $4,658 $523,804 $519,145 $10,383 $529,528 2053 $4,646 $529,528 $524,883 $10,498 $535,380 2054 $4,646 $535,380 $530,734 $10,615 $541,349 2055 $4,646 $541,349 $536,703 $10,734 $547,437 2056 $4,658 $547,437 $542,779 $10,856 $553,635 2057 $4,646 $553,635 $548,989 $10,980 $559,969 2058 $4,646 $559,969 $555,323 $11,106 $566,429 2059 $4,646 $566,429 $561,784 $11,236 $573,019 2060 $4,658 $573,019 $568,361 $11,367 $579,728 2061 $4,646 $579,728 $575,082 $11,502 $586,584 Page 3 of 4

ATTACHMENT 12 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2062 $4,646 $586,584 $581,938 $11,639 $593,577 2063 $4,646 $593,577 $588,931 $11,779 $600,710 2064 $4,658 $600,710 $596,051 $11,921 $607,972 2065 $4,646 $607,972 $603,327 $12,067 $615,393 2066 $4,646 $615,393 $610,748 $12,215 $622,962 2067 $4,646 $622,962 $618,317 $12,366 $630,683 2068 $4,658 $630,683 $626,025 $12,520 $638,545 2069 $4,646 $638,545 $633,899 $12,678 $646,577 2070 $4,646 $646,577 $641,932 $12,839 $654,770 2071 $4,646 $654,770 $650,125 $13,002 $663,127 2072 $4,658 $663,127 $658,469 $13,169 $671,638 2073 $4,646 $671,638 $666,992 $13,340 $680,332 2074 $25,911 $680,332 $654,421 $13,088 $667,510 2075 $64,958 $667,510 $602,551 $12,051 $614,602 2076 $147,936 $4,121 $614,602 $462,546 $9,251 $471,797 2077 $111,833 $2,132 $471,797 $357,832 $7,157 $364,989 2078 $73,759 $364,989 $291,229 $5,825 $297,054 2079 $73,759 $297,054 $223,294 $4,466 $227,760 2080 $7,617 $227,760 $220,143 $4,403 $224,546 2081 $21,956 $224,546 $202,590 $4,052 $206,642 2082 $12,518 $206,642 $194,124 $3,882 $198,007 2083 $121 $198,007 $197,886 $3,958 $201,843 2084 $35 $201,843 $201,808 $4,036 $205,845 Total* $910,428 $6,253

• Columns may not add due to rounding Page 4 of 4

Attachment 13 Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2

ATTACHMENT 13 Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $679,698 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $954,631 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) $6,253 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $453,726 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-014, Revision 0, "Decommissioning Cost Analysis for the LaSalle County Station Units 1 and 2," December 2014). The costs have been escalated from the mid-year 2014 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC dated February 19, 2015, (TLG Report E16-1640-014, Revision 0, "Decommissioning Cost Analysis for the LaSalle County Station Units 1 and 2," December 2014). The costs have been escalated from mid-year 2014 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

Page 1 of 4

ATTACHMENT 13 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2 (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on December 16, 2023.

Page 2 of 4

ATTACHMENT 13 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2023 $3,031 $541,350 $538,319 $897 $539,217 2024 $72,454 $539,217 $466,763 $9,335 $476,098 2025 $53,542 $476,098 $422,556 $8,451 $431,007 2026 $10,012 $431,007 $420,995 $8,420 $429,415 2027 $10,012 $429,415 $419,404 $8,388 $427,792 2028 $10,039 $427,792 $417,753 $8,355 $426,108 2029 $7,177 $426,108 $418,930 $8,379 $427,309 2030 $4,813 $427,309 $422,495 $8,450 $430,945 2031 $4,813 $430,945 $426,132 $8,523 $434,655 2032 $4,826 $434,655 $429,828 $8,597 $438,425 2033 $4,813 $438,425 $433,612 $8,672 $442,284 2034 $4,813 $442,284 $437,471 $8,749 $446,220 2035 $4,813 *

$446,220 $441,407 $8,828 $450,235 2036 $4,826 $450,235 $445,409 $8,908 $454,317 2037 $4,813 $454,317 $449,503 $8,990 $458,494 2038 $4,813 $458,494 $453,680 $9,074 $462,754 2039 $4,813 $462,754 $457,941 $9,159 $467,099 2040 $4,826 $467,099 $462,273 $9,245 $471,519 2041 $4,813 $471,519 $466,705 $9,334 $476,039 2042 $4,799 $476,039 $471,241 $9,425 $480,666 2043 $4,799 $480,666 $475,867 $9,517 $485,384 2044 $4,812 $485,384 $480,573 $9,611 $490,184 2045 $4,799 $490,184 $485,386 $9,708 $495,093 2046 $4,799 $495,093 $490,295 $9,806 $500,101 2047 $4,799 $500,101 $495,302 $9,906 $505,208 2048 $4,812 $505,208 $500,397 $10,008 $510,405 2049 $4,799 $510,405 $505,606 $10,112 $515,718 2050 $4,799 $515,718 $510,920 $10,218 $521,138 2051 $4,799 $521,138 $516,339 $10,327 $526,666 2052 $4,812 $526,666 $521,855 $10,437 $532,292 2053 $4,799 $532,292 $527,493 $10,550 $538,043 2054 $4,799 $538,043 $533,244 $10,665 $543,909 2055 $4,799 $543,909 $539,111 $10,782 $549,893 2056 $4,812 $549,893 $545,081 $10,902 $555,983 2057 $4,799 $555,983 $551,184 $11,024 $562,208 2058 $4,799 $562,208 $557,410 $11,148 $568,558 2059 $4,799 $568,558 $563,759 $11,275 $575,034 2060 $4,812 $575,034 $570,223 $11,404 $581,627 2061 $4,799 $581,627 $576,829 $11,537 $588,365 2062 $4,799 $588,365 $583,567 $11,671 $595,238 Page 3 of 4

ATTACHMENT 13 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2 (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2063 $4,799 $595,238 $590,440 $11,809 $602,248 2064 $4,812 $602,248 $597,437 $11,949 $609,385 2065 $4,799 $609,385 $604,587 $12,092 $616,679 2066 $4,799 $616,679 $611,880 $12,238 $624,118 2067 $4,799 $624,118 $619,319 $12,386 $631,706 2068 $4,812 $631,706 $626,894 $12,538 $639,432 2069 $4,799 $639,432 $634,633 $12,693 $647,326 2070 $4,799 $647,326 $642,527 $12,851 $655,378 2071 $4,799 $655,378 $650,579 $13,012 $663,591 2072 $4,812 $663,591 $658,779 $13,176 $671,955 2073 $4,799 $671,955 $667,156 $13,343 $680,499 2074 $4,799 $680,499 $675,701 $13,514 $689,215 2075 $5,047 $689,215 $684,168 $13,683 $697,851 2076 $35,329 $697,851 $662,522 $13,250 $675,772 2077 $106,472 $675,772 $569,300 $11,386 $580,686 2078 $155,637 $152 $580,686 $424,897 $8,498 $433,395 2079 $92,858 $2,413 $433,395 $338,124 $6,762 $344,887 2080 $92,858 $2,413 $344,887 $249,616 $4,992 $254,609 2081 $70,573 $1,276 $254,609 $182,760 $3,655 $186,415 2082 $13,269 - $186,415 $173,146 $3,463 $176,609 2083 $51 $176,609 $176,558 $3,531 $180,089 2084 $15 $180,089 $180,075 $3,601 $183,676 Total* $954,631 $6,253

• Columns may not add due to rounding Page 4 of 4

Attachment 14 Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 1

ATTACHMENT 14 Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $693,640 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $3,572 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $372,731 (b) 5 Schedule of the annual amounts remaining to be collected. $8,232 (c) 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 3% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii) and 10 CFR 72.30(e)(3).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGO has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

Page 1 of 2

ATTACHMENT 14 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 1 (December 31, 2014 dollars, thousands)

(c) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013 and allows for the collection of annual payments from ratepayers of $8,232K through 2023. It is possible that when the impact of the recently approved license renewal is factored into the PaPUC's next cost adjustment calculation (effective January 1, 2018), the collections will be adjusted downward, and potentially could go to $0, beginning in 2018 through 2043.

(d) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RAI #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on October 26, 2044.

Page 2 of 2

Attachment 15 Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 2

ATTACHMENT 15 Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $693,640 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) 83,572 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $384,612 (b) 5 Schedule of the annual amounts remaining to be collected. 813,105 (c) 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 3% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii) and 10 CFR 72.30(e)(3).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGG) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

Page 1 of 2

ATTACHMENT 15 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 2 (December 31, 2014 dollars, thousands)

(c) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013, and allows for the collection of annual payments from ratepayers of

$13,105K through 2028. It is possible that when the impact of the recently approved license renewal is factored into the PaPUC's next cost adjustment calculation (effective January 1, 2018), the collections will be adjusted downward, and potentially could go to $0, beginning in 2018 through 2048.

(d) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RAI #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on June 22, 2049.

Page 2 of 2

Attachment 16 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 1

ATTACHMENT 16 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $619,909 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $6,126 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $561,708 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 There are no material changes to the trust fund agreements.

(a) The site-specific decommissioning funding plan was previously provided in a letter from Stephen A. Mormann (Constellation Energy Nuclear Group, LLC) to U.S.NRC, dated December 17, 2012 ("ISFSI Decommissioning Funding Plans"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a site specific escalation rate.

Excluding the site-specific cost and escalation of the cost, the decommissioning funding plan is consistent with the decommissioning funding plan for the other EGG sites as detailed in the previously provided letter from Patrick R. Simpson (EGG) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem").

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGG has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on August 22, 2029.

Page 1 of 1

Attachment 17 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2 EGC Portion

ATTACHMENT 17 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2, EGC Portion (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $568,785 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $5,024 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $352,797 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 There are no material changes to the trust fund agreements.

(a) Value is based on the Exelon Generation Company, LLC (EGC) ownership share of Nine Mile Point Nuclear Station, Unit 2 of 82%.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Stephen A. Mormann (Constellation Energy Nuclear Group, LLC) to U. S. NRC, dated December 17, 2012 ("ISFSI Decommissioning Funding Plans"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a site specific escalation rate.

Excluding the site-specific cost and escalation of the cost, the decommissioning funding plan is consistent with the decommissioning funding plan for the other EGC sites as detailed in the previously provided letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem").

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on October 31, 2046.

Page 1 of 1

Attachment 18 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2 LIPA Portion

ATTACHMENT 18 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2, LIPA Portion (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $124,855 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $1,103 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $89,986 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 There are no material changes to the trust fund agreements.

(a) Value is based on the Long Island Power Authority (LIPA) ownership share of Nine Mile Point Nuclear Station, Unit 2 of 18%.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Stephen A. Mormann (Constellation Energy Nuclear Group, LLC) to U. S. NRC, dated December 17, 2012 ("ISFSI Decommissioning Funding Plans"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a site specific escalation rate.

Excluding the site-specific cost and escalation of the cost, the decommissioning funding plan is consistent with the decommissioning funding plan for the other EGC sites as detailed in the previously provided letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem").

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. This amount was provided by the Nine Mile Point Nuclear Station, Unit 2 co-owner LIPA. LIPA has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014. EGC has not independently verified or assessed the trust fund amount.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on October 31, 2046.

Page 1 of 1

Attachment 19 Annual Radiological Decommissioning Funding Assurance Report for Oyster Creek Nuclear Generating Station

ATTACHMENT 19 Annual Radiological Decommissioning Funding Assurance Report for Oyster Creek Nuclear Generating Station (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $623,608 2 Site-specific cost amount per 10 CFR 50.75(b)(4) $939,447(a) 3 Site-specific cost amount per 10 CFR 72.30(b) $7,340 (b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $861,564 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) This is based on the SAFSTOR scenario from the site-specific cost estimate, and is greater than the formula cost amount under 10 CFR 50.75(c), as required by 10 CFR 50.75(b)(1). The site-specific estimate has been previously provided in a letter from James Barstow (EGC) to U. S. NRC, dated December 30, 2014 (TLG Report E16-1640-002, Revision 4, "Decommissioning Cost Analysis for the Oyster Creek Nuclear Generating Station," December 2014). The costs have been escalated from the 2011 dollars in the decommissioning cost estimate to December 31, 2014.

(b) The site-specific decommissioning funding plan was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated and provided in a letter from James Barstow (EGC) to U. S. NRC, dated December 30, 2014 (TLG Report E16-1640-002, Revision 4, "Decommissioning Cost Analysis for the Oyster Creek Nuclear Generating Station," December 2014). The costs have been escalated from 2011 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate consistent with that used for the plant cost estimate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

Page 1 of 4

ATTACHMENT 19 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Oyster Creek Nuclear Generating Station (December 31, 2014 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on December 31, 2019. This date is based on the State of New Jersey Administrative Consent Order, dated December 9, 2010.

Page 2 of 4

ATTACHMENT 19 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Oyster Creek Nuclear Generating Station (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2019 $177 $949,668 $949,490 $1,582 $951,073 2020 $65,511 $951,073 $885,562 $17,711 $903,273 2021 $62,943 $903,273 $840,330 $16,807 $857,136 2022 $7,318 $857,136 $849,818 $16,996 $866,815 2023 $7,318 $866,815 $859,497 $17,190 $876,687 2024 $7,338 $876,687 $869,349 $17,387 $886,736 2025 $7,245 $886,736 $879,491 $17,590 $897,081 2026 $7,173 $897,081 $889,908 $17,798 $907,706 2027 $7,173 $907,706 $900,533 $18,011 $918,544 2028 $7,193 $918,544 $911,351 $18,227 $929,578 2029 $7,173 $929,578 $922,405 $18,448 $940,853 2030 $7,173 $940,853 $933,680 $18,674 $952,354 2031 $7,173 $952,354 $945,181 $18,904 $964,085 2032 $7,193 $964,085 $956,892 $19,138 $976,030 2033 $7,173 $976,030 $968,857 $19,377 $988,234 2034 $7,173 $988,234 $981,061 $19,621 $1,000,683 2035 $7,173 $1,000,683 $993,510 $19,870 $1,013,380 2036 $7,192 $1,013,380 $1,006,187 $20,124 $1,026,311 2037 $7,140 $1,026,311 $1,019,171 $20,383 $1,039,555 2038 $7,140 $1,039,555 $1,032,415 $20,648 $1,053,063 2039 $7,140 $1,053,063 $1,045,923 $20,918 $1,066,841 2040 $7,160 $1,066,841 $1,059,682 $21,194 $1,080,875 2041 $7,140 $1,080,875 $1,073,735 $21,475 $1,095,210 2042 $7,140 $1,095,210 $1,088,070 $21,761 $1,109,831 2043 $7,140 $1,109,831 $1,102,691 $22,054 $1,124,745 2044 $7,160 $1,124,745 $1,117,585 $22,352 $1,139,937 2045 $7,140 $1,139,937 $1,132,797 $22,656 $1,155,453 2046 $7,140 $1,155,453 $1,148,313 $22,966 $1,171,279 2047 $7,140 $1,171,279 $1,164,139 $23,283 $1,187,422 2048 $7,160 $1,187,422 $1,180,262 $23,605 $1,203,868 2049 $7,140 $1,203,868 $1,196,728 $23,935 $1,220,662 2050 $7,140 $1,220,662 $1,213,522 $24,270 $1,237,793 2051 $7,140 $1,237,793 $1,230,653 $24,613 $1,255,266 2052 $7,160 $1,255,266 $1,248,106 $24,962 $1,273,068 2053 $7,140 $1,273,068 $1,265,928 $25,319 $1,291,247 2054 $7,140 $1,291,247 $1,284,107 $25,682 $1,309,789 2055 $7,140 $1,309,789 $1,302,649 $26,053 $1,328,702 2056 $7,160 $1,328,702 $1,321,542 $26,431 $1,347,973 2057 $7,140 $1,347,973 $1,340,833 $26,817 $1,367,649 2058 $7,140 $1,367,649 $1,360,509 $27,210 $1,387,720 Page 3 of 4

ATTACHMENT 19 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Oyster Creek Nuclear Generating Station (December 31, 2014 dollars, thousands)

Site ISFSI BOY BOY EOY Radiological Radiological Trust Trust Fund Trust Trust Decommissioning Decommissioning Fund Value Fund Fund Year Cost Cost Value Less Cost Earnings Value 2059 $7,140 $1,387,720 $1,380,580 $27,612 $1,408,191 2060 $7,160 $1,408,191 $1,401,032 $28,021 $1,429,052 2061 $7,140 $1,429,052 $1,421,912 $28,438 $1,450,350 2062 $7,140 $1,450,350 $1,443,210 $28,864 $1,472,075 2063 $7,140 $1,472,075 $1,464,935 $29,299 $1,494,233 2064 $7,160 $1,494,233 $1,487,074 $29,741 $1,516,815 2065 $7,140 $1,516,815 $1,509,675 $30,194 $1,539,869 2066 $7,140 $1,539,869 $1,532,728 $30,655 $1,563,383 2067 $7,140 $1,563,383 $1,556,243 $31,125 $1,587,368 2068 $7,160 $1,587,368 $1,580,208 $31,604 $1,611,812 2069 $7,140 $1,611,812 $1,604,672 $32,093 $1,636,766 2070 $7,140 $1,636,766 $1,629,626 $32,593 $1,662,218 2071 $7,140 $1,662,218 $1,655,078 $33,102 $1,688,180 2072 $7,160 $1,688,180 $1,681,020 $33,620 $1,714,641 2073 $7,140 $1,714,641 $1,707,501 $34,150 $1,741,651 2074 $7,140 $1,741,651 $1,734,511 $34,690 $1,769,201 2075 $38,187 $1,769,201 $1,731,014 $34,620 $1,765,634 2076 $104,068 $1,765,634 $1,661,566 $33,231 $1,694,798 2077 $122,889 $1,180 $1,694,798 $1,570,728 $31,415 $1,602,142 2078 $107,199 $4,952 $1,602,142 $1,489,992 $29,800 $1,519,792 2079 $58,565 $1,207 $1,519,792 $1,460,020 $29,200 $1,489,220 2080 $149 - $1,489,220 $1,489,071 $29,781 $1,518,852 2081 $81 $1,518,852 $1,518,771 $30,375 $1,549,146 Total* $939,447 $7,340

• Columns may not add due to rounding Page 4 of 4

Attachment 20 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1

ATTACHMENT 20 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) N/A (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) and 50.75(f) $209,824 (a) 3 Site-specific cost amount per 10 CFR 72.30(b) N/A (f) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $91,417 (b) 5 Schedule of the annual amounts remaining to be collected. $2,118 (c) 6 Assumptions used regarding rates of escalation for decommissioning costs, earnings on funds, and other factors used in funding projections 3% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

10 2014 annual amount spent on decommissioning in $1,169 (e) accordance with 10 CFR 50.82(a)(8)(v)(A).

11 Cumulative amount spent on decommissioning in accordance $2,559 with 10 CFR 50.82(a)(8)(v)(A).

Reimbursed from the decommissioning trust fund $0 Not yet reimbursed from the decommissioning trust fund $2,559 12 Amount of funds accumulated to cover the cost of managing N/A (f) irradiated fuel pursuant to 10 CFR 50.82(a)(8)(vii)(A) as of December 31, 2014.

13 Projected cost of managing irradiated fuel based on site- N/A (f) specific estimate per 10 CFR 50.82(a)(8)(vii)(B).

Page 1 of 4

ATTACHMENT 20 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2014 dollars, thousands)

(a) A formula cost amount using the formula in 10 CFR 50.75(c) is not applicable because Peach Bottom Unit 1 has been shutdown since October 31, 1974 and some decommissioning activities have already occurred on this unit. Furthermore, Peach Bottom Unit 1 was a High Temperature Gas Cooled Reactor (HTGR), which does not translate to a BWR or PWR as specified in the formula for calculating the formula cost amount, and hence a formula cost amount per 10 CFR 50.75(c) cannot be calculated for Peach Bottom Unit 1.

In accordance with the regulatory requirements, the site-specific amount is reported per 10 CFR 50.75(b)(4), 50.75(f), 50.82(a)(8)(ii), and 50.82(a)(8)(v)(B) and assumes a DECON scenario as described in the site-specific cost estimate (SSCE) (TLG Report E16-1555-015, Revision 0, "Decommissioning Cost Analysis for the Peach Bottom Atomic Power Station Unit 1," June 2010). The decommissioning cost estimate has been adjusted consistent with the description of planned decommissioning activities in the Peach Bottom, Unit 1, Decommissioning Plan. The costs have been escalated from the 2010 dollars reflected in the 2010 decommissioning cost estimate to estimated costs as of December 31, 2014.

Decommissioning expenditures prior to the year the SSCE updates were prepared (historical expenditures) are not included in the estimated total cost of decommissioning in the final SSCE reports. The Peach Bottom Unit 1 SSCE estimated the annual radiological costs for years 2010 through 2032 to be $0.

Decontamination and dismantlement of Peach Bottom Atomic Power Station, Unit 1, will take place beginning in 2033, coinciding with the decommissioning of Peach Bottom Atomic Power Station, Unit 2.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013, and allows for the collection of annual payments from ratepayers of $2,118K through 2032.

Page 2 of 4

ATTACHMENT 20 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2014 dollars, thousands)

(d) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RAI #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(e) The most recent Peach Bottom Unit 1 SSCE estimated the 2014 cost (radiological decommissioning costs only) to be $0. The $1,169 (thousands of dollars) difference between actual and projected is the result of two major projects, roof repair/replacement and discharge pipe removal, that were scoped in and approved above baseline budget. This amount is considered to be immaterial to the overall funding assurance analysis.

(f) Peach Bottom Atomic Power Station, Unit 1 was shut down in October of 1974, with defueling of the core completed by the following June. Starting in 1975, the spent fuel was shipped by truck to Idaho. The final of 44 shipments was completed in February of 1977. Consequently, no irradiated fuel for Peach Bottom Unit 1 remains on-site, and therefore 10 CFR 50.82(a)(8)(vii) and 10 CFR 72.30(b) do not apply.

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ATTACHMENT 20 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2014 dollars, thousands)

BOY BOY EOY Radiological Trust Trust Fund First Trust Second Trust Decommissioning Fund Value Half Fund Half Fund Year Cost Value Less Cost** Contributions Earnings Contributions Value 2015 $91,417 $91,417 $1,059 $2,774 $1,059 $96,309 2016 $96,309 $96,309 $1,059 $2,921 $1,059 $101,348 2017 $101,348 $101,348 $1,059 $3,072 $1,059 $106,538 2018 $106,538 $106,538 $1,059 $3,228 $1,059 $111,884 2019 $111,884 $111,884 $1,059 $3,388 $1,059 $117,390 2020 $117,390 $117,390 $1,059 $3,553 $1,059 $123,061 2021 $123,061 $123,061 $1,059 $3,724 $1,059 $128,903 2022 $128,903 $128,903 $1,059 $3,899 $1,059 $134,919 2023 $134,919 $134,919 $1,059 $4,079 $1,059 $141,116 2024 $141,116 $141,116 $1,059 $4,265 $1,059 $147,499 2025 $147,499 $147,499 $1,059 $4,457 $1,059 $154,074 2026 $154,074 $154,074 $1,059 $4,654 $1,059 $160,846 2027 $160,846 $160,846 $1,059 $4,857 $1,059 $167,821 2028 $167,821 $167,821 $1,059 $5,066 $1,059 $175,005 2029 $175,005 $175,005 $1,059 $5,282 $1,059 $182,405 2030 $182,405 $182,405 $1,059 $5,504 $1,059 $190,026 2031 $190,026 $190,026 $1,059 $5,733 $1,059 $197,877 2032 $197,877 $197,877 $1,059 $5,968 $1,059 $205,962 2033 $35,334 $205,962 $170,628 $5,119 $175,747 2034 $53,853 $175,747 $121,895 $3,657 $125,552 2035 $53,858 $125,552 $71,694 $2,151 $73,844 2036 $42,409 $73,844 $31,435 $943 $32,378 2037 $24,370 $32,378 $8,008 $240 $8,248 Total* $209,824

• Column may not add due to rounding

• • Annual contributions added to individual years - Earnings of half of contributions are included in current year to estimate payment of contributions throughout the year Page 4 of 4

Attachment 21 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 2

ATTACHMENT 21 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $346,820 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $879 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $241,999 (c) 5 Schedule of the annual amounts remaining to be collected. $0 (d) 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 3% (e) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii) and 10 CFR 72.30(e)(3).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) Value is based on the Exelon Generation Company, LLC (EGC) ownership share of Peach Bottom Atomic Power Station, Unit 2 of 50%.

(b) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

Page 1 of 2

ATTACHMENT 21 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 2 (December 31, 2014 dollars, thousands)

(d) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013, and allows for the collection of annual payments from ratepayers of $0 through 2032.

(e) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RAI #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on August 8, 2033.

Page 2 of 2

Attachment 22 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 3

ATTACHMENT 22 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 3 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $346,820 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $878 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $261,861 (c) 5 Schedule of the annual amounts remaining to be collected. $0 (d) 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 3% (e) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii) and 10 CFR 72.30(e)(3).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) Value is based on the Exelon Generation Company, LLC (EGC) ownership share of Peach Bottom Atomic Power Station, Unit 3 of 50%.

(b) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

Page 1 of 2

ATTACHMENT 22 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 3 (December 31, 2014 dollars, thousands)

(d) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013, and allows for the collection of annual payments from ratepayers of $0 through 2033.

(e) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RA1 #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on July 2, 2034.

Page 2 of 2

Attachment 23 Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 1

ATTACHMENT 23 Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $493,208 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $1,408 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $392,769 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) Value is based on the Exelon Generation Company, LLC (EGC) ownership share of Quad Cities Nuclear Power Station, Unit 1 of 75%.

(b) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on December 14, 2032.

Page 1 of 1

Attachment 24 Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 2

ATTACHMENT 24 Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $493,208 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $1,408 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $440,141 (c) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (d) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) Value is based on the Exelon Generation Company, LLC (EGC) ownership share of Quad Cities Nuclear Power Station, Unit 2 of 75%.

(b) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(d) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(e) For purposes of this report, permanent termination of operations (shutdown) is expected on December 14, 2032.

Page 1 of 1

Attachment 25 Annual Radiological Decommissioning Funding Assurance Report for R.E. Ginna Nuclear Power Plant

ATTACHMENT 25 Annual Radiological Decommissioning Funding Assurance Report for R.E. Ginna Nuclear Power Plant (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $459,746 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $5,264 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $403,940 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i) and 10 CFR 72.30(e)(1).

9 There are no material changes to the trust fund agreements.

(a) The site-specific decommissioning funding plan was previously provided in a letter from Stephen A. Mormann (Constellation Energy Nuclear Group, LLC) to U. S. NRC, dated December 17, 2012 ("ISFSI Decommissioning Funding Plans"). The site-specific cost estimate for ISFSI radiological decommissioning contained in this letter has been updated. The detailed site-specific cost estimate for ISFSI radiological decommissioning is provided in Attachment 29. The costs have been escalated and provided in December 31, 2014 dollars using a unit specific escalation rate.

Excluding the site-specific cost and escalation of the cost, the decommissioning funding plan is consistent with the decommissioning funding plan for the other EGC sites as detailed in the previously provided letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem").

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on September 18, 2029.

Page 1 of 1

Attachment 26 Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 1

ATTACHMENT 26 Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $226,877 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $955 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $223,329 (c) 5 Schedule of the annual amounts remaining to be collected. $0 (d) 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 3% (e) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii) and 10 CFR 72.30(e)(3).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) Value is based on the Exelon Generation Company, LLC (EGG) ownership share of Salem Generating Station, Unit 1 of 42.59%.

(b) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGG) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGG has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

Page 1 of 2

ATTACHMENT 26 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 1 (December 31, 2014 dollars, thousands)

(d) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013, and allows for the collection of annual payments from ratepayers of $0 through 2035.

(e) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RAI #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on August 13, 2036.

Page 2 of 2

Attachment 27 Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 2

ATTACHMENT 27 Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 2 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $226,877 (a) 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) $954 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $185,837 (c) 5 Schedule of the annual amounts remaining to be collected. $0 (d) 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 3% (e) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the external sinking fund method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(ii) and 10 CFR 72.30(e)(3).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) All values are based on the Exelon Generation Company, LLC (EGC) ownership share of Salem Generating Station, Unit 2 of 42.59%.

(b) This is the site-specific cost estimate for ISFSI radiological decommissioning that was previously provided in a letter from Patrick R. Simpson (EGC) to U. S. NRC, dated December 17, 2012 ("Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Braidwood, Byron, Dresden, LaSalle, Limerick, Oyster Creek, Peach Bottom, Quad Cities, and Salem"). The costs have been escalated from 2012 dollars in the cost estimate to December 31, 2014 using a unit specific escalation rate. No other changes have been made to the decommissioning funding plan in the December 17, 2012 letter.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

Page 1 of 2

ATTACHMENT 27 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 2 (December 31, 2014 dollars, thousands)

(d) The funding mechanism being used as the source of revenues for the external sinking funds is a non-bypassable charge approved by the Pennsylvania Public Utilities Commission (PaPUC) authorizing PECO Energy Company to continue to collect decommissioning funds for EGC. Any needed adjustments to the amount collected will be made in the next filing of the Nuclear Decommissioning Cost Adjustment (NDCA) to the PaPUC. This cost adjustment is made every five years pursuant to PaPUC Electric Tariff No. 4. The last adjustment was effective January 1, 2013, and allows for the collection of annual payments from ratepayers of $0 through 2039.

(e) 10 CFR 50.75(e)(1)(ii) allows licensees to use a rate of return higher than 2% if the applicable rate-setting authority has specifically authorized a higher rate. The PaPUC approved a 3% real rate of return as part of the approval of the restructuring plan for PECO Energy Company (Letter from J. J. McNulty (PaPUC) to B. D. Crowe (PECO Energy Company), "Approval of Restructuring Plan for PECO Energy Company under Section 2806 of the Public Utility Code; Docket No. R-00973953," dated May 3, 2001). Accordingly, EGC uses a 3% real rate of return. The 3% is applicable through the decommissioning period as described in RAI #1 response provided in the Letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S.

NRC, "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(f) For purposes of this report, permanent termination of operations (shutdown) is expected on April 18, 2040.

Page 2 of 2

Attachment 28 Annual Radiological Decommissioning Funding Assurance Report for Three Mile Island Nuclear Station, Unit 1

ATTACHMENT 28 Annual Radiological Decommissioning Funding Assurance Report for Three Mile Island Nuclear Station, Unit 1 (December 31, 2014 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $495,150 2 Site-specific cost amount per 10 CFR 50.75(b)(4) N/A 3 Site-specific cost amount per 10 CFR 72.30(b) N/A (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2014 $604,856 (b) 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and other factors used in funding projections 2% (c) 7 There are no contracts relied upon pursuant to 10 CFR 50.75(e)(1)(v).

8 Financial assurance for decommissioning is provided by the prepayment method, coupled with an external trust fund, in accordance with 10 CFR 50.75(e)(1)(i).

9 Effective October 29, 2013, the existing trust fund agreements were consolidated and a Subordinate Trust Agreement established that creates a "trustee" relationship between Northern Trust Company and The Bank of New York Mellon (BNYM), as detailed in letter from Patrick R. Simpson (Exelon Generation Company, LLC) to U. S. NRC, "Executed Trust Fund Agreement Amendments and Subordinate Trust Agreement," dated October 29, 2013.

(a) Three Mile Island does not have an ISFSI. Therefore, 10CFR72 does not apply to Three Mile Island.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. EGC has no past-due tax payments related to decommissioning trust fund activities as of December 31, 2014. Periodic payments of estimated income taxes are made during the year on a quarterly basis. The trust fund amounts comply with the reporting requirements of 10 CFR 50.75(f) in that the amount of funds reported are those that were accumulated as of December 31, 2014.

(c) A 2% annual real rate of return is used as allowed by 10 CFR 50.75(e)(1)(i).

(d) For purposes of this report, permanent termination of operations (shutdown) is expected on April 19, 2034.

Page 1 of 1

Attachment 29 ISFSI Decommissioning Funding Estimates

0 Removal Packaging Transport Oversight and Activity Description 0 To Burial Volume Craft Other Costs Total Costs Contractor Costs Costs Costs 441 .44 LJ Class A (ft3) Manhours Manhours Decommissioning Contractor I

Planning (characterization, e-i in ci d 01<I- to N

specs and procedures) in. .-Z Decontamination (activated e-I ni N N N ai .zi o o to m N

en "4:

V} N 01 VI. co to -i te at m

liner and concrete remova l) in $3,808.0 N rei" License Termination LO

$1,604.8 e-i' 4.4 8 CO 12,950 (radiological surveys) el N cn al N

in o en to Subtotal $372.1 $4.71 N CO 14 CO $2,549.5 N di N to (Li.

.-1 g N V} le A' Supporting Costs I

NRC and NRC Contractor Fees NCO

$388.2 CO 01 and Costs in. 7776 1.0 ai Property taxes $329.6 CO ,...

411.

0 tei 0 Lc; Security Staff Cost to m tD en h m

in. V} 4. 01

.4- +-I

.-i Oversight Sta ff en in .-.1 ect en V} 3,740I 4-0 N 01 4.,

40 in str .0:

N en 0 .6. i-i- cr; .4.

ri" in V} V} eV irl r4 N 0.1 rt NN co m Total (w/o contingency) N en V V} $977.2I VI. CO N 01 to

'4, a m cs*N

...4 m

V} N f4 w N tei

.-t N I N N t-e as Total (w/25% contingency) P: cci V} V}

Costs for ISFSI decommissioning are equally sp lit between units at dual-unit sites.

Co ...I

.0 Burial Utility and Removal ba 42 10 ,0 Transport Total Craft Activity Description u 4J co TO Other Costs Total Costs Volume Costs 01 (1. Costs Contractor 4 4..) Contingency Manhours Class A (ft3) Manhours N

c4 01 tO ti1 ISFSILicense Termination $762 4" 44 cr Ln '0 4" CO in CO 01 0 r.i 4.4 $4,785 1-4 z

e01 41,194 N tD Insurance $124 e-4 In 1" in* t-i Property Taxes U1 d' U1 ih m 4-I IA $584

• I' 4-I 01 NRC ISFSI Fees $138 4" in. L11 I-1 PA DEPFees N N 01 t" co 01 $43 01 i"

CY N tD Security Staff Cost $489I N 4.4 t/1 i" 7,800I N tD 01 Co Utility StaffCosts u) 14 t-I N 14 in 44 c 0 CO 01 Li N tio M 1.4 Total 4.4 er Rr Off N

4" g 01 Co. 4" 4-1. 2,310 ttr r.1 Co0 I ,..i. ,II%

Costs for ISFSI decommissioning are equally split between units at dual-unit sites.

fa .A 00 LLRW Oversight and cc F 75' o. 72-0 C Transport BurialVolume Craft

> 22 -le 0 Activity Description I./ U Disposal Other Costs TotalCosts Contractor e o , fa 4 Costs Class A (ft3) Manhours Costs Manhours Decommissioning Contractor Planning (characterization, W M 01 4" cr) AlW 1,360 specs and procedures)

Deconta mination (activated ID N N 01 N ID

$517 Kh

.-.1. N IN1 lA IA cs. cn in 1"

$787  ?

1" 4" 4,565 HSMdisposition)

License Termination W til W IA N N fsi. N N.

111. LA C A' IA al (radiological surveys )

Ill N As 0 tn el. CA n 1.0 Al Subtotal An* lelN 4" 14 1"

$2,779 $3,440 $8,214 R IA M 4.4 in 44 Supporting Costs NRC and NRCContractor Fees CO ID

$388 00 (11 N N

and Costs N

.0*

Insurance 4-1 4"

$ 147 0

Al Property taxes Al $330 1/1.

W ID N Al Security StaffCost 1" m CO CO ell 01

..4?

N N 0

.0.

Oversight Staff Cost m 1/1. AI rf1 Al A.

Ill' N

CO N 03 Subtotal IA 4:4^ IA vl IA 4" 4" cri 111 Ls, 14 N N 0

4-I 10 V' D3. 01 ci IA Total (w/o contingency) Aft n IA N CI1 R N 4 N v-I

$ 2,779 IA

$5,028 1." v-i Total (w/25% contingency) $ 12,253

To 4 LLRW Oversight and Removal ro ... C 00 ro U t Activity Description _y 0 Disposal Burial Volume Craft to

0. It 0 Other Costs Total Costs Contractor Costs Class A (ft3) Man hours Costs Man hours Decommissioning Contractor I

Pla nning (characterization,

$188 4A 00

-., oo 1,024 specs and procedures)

Decontam ination (activated $238 , N 411.fq $381 en Tt rti ,40 N HSMdisposition ) 14.

$449 4.4 O r 8,722 eil S

.-1 License Term ina tion

$747 $747 ID CO (radiologica l surveys) u-i. tr.

-o

= 2 2 N N en en gt ul $238 4A

$381 rn

.4A Tr 4.14 4A a $2,739 8,722 41 N r: CO .-i. 0 Supporting Costs I

NRC a ndNRC Contractor Fees cri en 4.4 co en in CO 776 andCosts Insurance $147 $147 1 Property taxes en en lA en $333I Security Staff Cost 1-1 AArii to .-1 e....

In ID m.-i si" N 01 Oversight Staff Cost en I-1 rn 4.4 *ct m 4" cr en ft-I' N N

Subtotal ,et N . .4. N Crt 4-I 4.4 4 N N oi IA tA

$238 [ N 14 ID I-1 Tota l (w/o contingency) 4" 4A $734 V1. co In a 1-1 is

.-i en N. 8,7221 7,813I cis" Tota l(w/ 25% contingency) trn; N 3