RS-21-030, Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations

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

ML21055A776
Person / Time
Site:	Calvert Cliffs, Dresden, Peach Bottom, Salem, Nine Mile Point, Byron, Three Mile Island, Braidwood, Limerick, Ginna, Clinton, Quad Cities, FitzPatrick, LaSalle, 07201036, 05000001
Issue date:	02/24/2021
From:	Simpson P Exelon Generation Co
To:	Document Control Desk, Office of Nuclear Material Safety and Safeguards, Office of Nuclear Reactor Regulation
References
RS-21-030
Download: ML21055A776 (73)

Text

Exelon Generation 4300 Winfield Road Warrenville, IL 60555 630 657 2000 Office RS-21-030 10 CFR 50.75(f) 10 CFR 72.30(b) 10 CFR 50.82(a)

February 24, 2021 U.S . Nuclear Regulatory Commission ATTN : Document Control Desk Washington, DC 20555-0001 Braidwood Station , Units 1 and 2 Renewed 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 Renewed 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 and 72-1046 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 James. A FitzPatrick Nuclear Power Plant Renewed Facility Operating License No. DPR-59 NRC Docket Nos. 50-333 and 72-012 LaSalle County Station, Units 1 and 2 Renewed 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

February 24, 2021 U.S. Nuclear Regulatory Commission Page 2 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 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 or co-owned by EGC. Additionally, in accordance with 10 CFR 72.30 , "Financial assurance and record keeping for decommissioning,"

EGC is submitting updates to the decommissioning funding plans for the independent spent fuel storage installations (ISFSls) owned or co-owned by EGC .1 Updated decommissioning cost estimates for ISFSI decommissioning are provided in the attached report in Attachments 29 and 30. With respect to the other information required by 10 CFR 72.30(b) and (c), unless otherwise noted in Attachment 30, there have been no changes from the information provided in the initial ISFSI decommissioning funding plans (see Attachment 30, References 1, 2, 3, and 5).

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 site-specific decommissioning cost estimates.

1 EGG currently has ISFSls at each of its sites, with the exception of Three Mile Island, Unit 1, where an ISFSI is under construction .

February 24, 2021 U.S. Nuclear Regulatory Commission Page 3 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 (PBAPS), 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 Nine Mile Point Nuclear Station , LLC (82%), an indirect EGC co-owned subsidiary, 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 LIPA.

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 option for any of its operating nuclear units. EGC uses the formula cost amount or the site-specific decommissioning cost estimates to demonstrate adequacy of funding to meet regulatory requirements. To the extent the site-specific cost estimates assume a decommissioning option, 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.

Financial assurance for decommissioning has been provided for all units except for Bryon Units 1 and 2. Due to the decision to prematurely retire Byron Station , Units 1 and 2 by September 30, 2021, Byron Station, Units 1 and 2 did not meet the minimum funding assurance criteria under 10 CFR 50.75, 10 CFR 50.82 , and 10 CFR 72 .30 as of December 31, 2020, using the NRC formula in 10 CFR 50.75(c) to calculate costs and based solely on the trust fund balance (see Attachments 4 and 5). EGC is in the process of preparing a site specific decommissioning cost estimate (DCE) and post-shutdown decommissioning activities report (PSDAR) which will provide more detailed and comprehensive cost information for decommissioning of Byron Station , Units 1 and 2. EGC intends to submit its DCE and PSDAR on or before July 1, 2021.

At that time , EGC will evaluate the status of funding assurance using the DCE and updated trust fund values . If additional sources of funds are required , EGC will evaluate 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, to provide the required minimum funding assurance for Byron Station , Units 1 and 2 by no later than shutdown.

Disbursements made through December 31, 2020, from the decommissioning trust funds since the last report, 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), were in support of decommissioning planning. Dresden 1, Peach Bottom 1, and Three Mile Island 1 disbursements contained additional costs in support of decommissioning activities as outlined in their respective attachments.

February 24, 2021 U.S. Nuclear Regulatory Commission Page4 There are no regulatory commitments contained within this submittal.

If you have any questions concerning this letter, please contact me at (630) 657-2823.

Patrick R. Simpson Senior Manager - Licensing Exelon Generation Company, LLC cc: Regional Administrator - NRC Region I Regional Administrator - NRC Region Ill 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 - James A. FitzPatrick 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 - 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

February 24, 2021 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 James A. FitzPatrick Nuclear Power Station

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

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

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

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

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

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

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

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

February 24, 2021 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 and Spent Fuel Management Report for Three Mile Island Nuclear Station , Unit 1

29. ISFSI Decommissioning Funding Estimates 30 . Independent Spent Fuel Storage Installation Decommissioning Funding Plan Updates

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 18, issued January 2021.

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, Exelon Generation Company, LLC (EGC) used the Employment Cost Index for total compensation for private industry workers by region . The labor adjustment factors were calculated according to Section 3.2 of NUREG-1307, Revision 18, using fourth quarter 2020 data. Table 1 shows the data used for this calculation.

Table 1: Labor Adjustment Factors 4Q2020 Base Labor Index Lx Adjustment ReQion Aoolicable Sites Series ID Number Factor (Lx)

Northeast James A. CIU20100000002101 144.0 2.16 3.110 FitzPatrick Limerick Nine Mile Point Peach Bottom R.E. Ginna Salem TMI South Calvert Cliffs CIU20100000002201 139.3 1.98 2.758 Midwest Braidwood CIU20100000002301 139.1 2.08 2.893 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 3.3 of NUREG-1307 ,

Revision 18, using December 2020 data. Table 2 shows the data used for this calculation .

Table 2: Energy Adjustment Factors WPU0543 - Januar 114.2 WPU0573 - Januar 82.0 WPU0543 - December 2020 232.7 WPU0573 - December 2020 209.8 2.038 2.559 Ener 2.256 Ener 2.277 Page 1 of 2

ATTACHMENT 1 (Continued)

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

The waste burial adj ustment factors used are taken from Table 2-1 of NUREG-1307, Revision 18, based on 2020 data. The adjustment factors EGC used assume a combination of compact-affiliated and non-compact facilities for sites affiliated with a compact. This is consistent with current waste disposal practices at EGC and consistent with typical waste disposal practices during decommissioning . For sites not affiliated with a compact, the values for generators located in unaffiliated states were used.

Table 3 summarizes the data used for the calcu lation of the waste adjustment factors.

Table 3: Waste Adjustment Factors Combination of Generators Reactor Applicable Site Compact- Located in the LLW Burial Site Type Affiliated and Unaffiliated States Non-Compact and those Located Disposal in Compact-Facilities Waste Affiliated States Adjustment having no Factor (Bx) Disposal Facility Waste Adjustment Factor {Bx)

South Carolina site PWR Salem 11 .679 N/A Atlantic Compact Generic LLW BWR Clinton N/A 12.837 Disposal Site Dresden James A. FitzPatrick LaSalle Limerick Nine Mile Point Peach Bottom Quad Cities Generic LLW PWR Braidwood N/A 12.793 Disposal Site Byron Calvert Cliffs R.E. Ginna TMI The calculation methodology used for all adjustment factors is consistent with NUREG-1307, Revision 18.

Page 2 of 2

ATTACHMENT 2 Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $ 523,785 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) $5,691 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $ 433,424 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 October 17, 2046.

Page 1 of 1

ATTACHMENT 3 Annual Radiological Decommissioning Funding Assurance Report for Braidwood Station, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $523,785 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) $5,691 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $467,982 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 18, 2047.

Page 1 of 1

ATTACHMENT 4 Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $523,785 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) $5,503 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $475,341 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 30, 2021 .

Page 1 of 1

ATTACHMENT 5 Annual Radiological Decommissioning Funding Assurance Report for Byron Station, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $523,785 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) $5,503(a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $458,906 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 30 , 2021 .

Page 1 of 1

ATTACHMENT 6 Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $485,578 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) $5,583 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $491,849 (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 January 1, 2021 , the direct owners of the trusts for Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, transferred the trusts from Mellon Bank as Trustee to Northern Trust as Trustee . In conjunction with that change, each direct owner and Northern Trust entered into new qualified trust agreements and non-qualified trust agreements, with a common set of Master Terms for Trust Agreements . These new trust agreements are substantively the same as the agreements with Northern Trust for Exelon Generation's other nuclear units. As a result of the change in Trustee, there is now one Trustee for all of the decommissioning trusts for Exelon Generation's directly and indirectly owned nuclear units. The change in Trustee is intended to result in cost savings for the Calvert Cliffs, Nine Mile Point, and Ginna trusts and improve trust administration and the investment processes. The NRC was notified of the planned change in Trustee, along with changes in the trust agreements, by letter dated October 30, 2020 .

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 6 {continued)

Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 1 (December 31, 2020 dollars, thousands)

(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 2 of 2

ATTACHMENT 7 Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $485,578 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) $5,454 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $636,843 (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 January 1, 2021 , the direct owners of the trusts for Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, transferred the trusts from Mellon Bank as Trustee to Northern Trust as Trustee . In conjunction with that change, each direct owner and Northern Trust entered into new qualified trust agreements and non-qualified trust agreements, with a common set of Master Terms for Trust Agreements . These new trust agreements are substantively the same as the agreements with Northern Trust for Exelon Generation's other nuclear units. As a result of the change in Trustee, there is now one Trustee for all of the decommissioning trusts for Exelon Generation's directly and indirectly owned nuclear units. The change in Trustee is intended to result in cost savings for the Calvert Cliffs, Nine Mile Point, and Ginna trusts and improve trust administration and the investment processes. The NRC was notified of the planned change in Trustee, along with changes in the trust agreements, by letter dated October 30, 2020 .

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 7 {continued)

Annual Radiological Decommissioning Funding Assurance Report for Calvert Cliffs Nuclear Power Plant, Unit 2 (December 31, 2020 dollars, thousands)

(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 2 of 2

ATTACHMENT 8 Annual Radiological Decommissioning Funding Assurance Report for Clinton Power Station, Unit 1 (December 31, 2020 dollars, thousands)

Formula cost amount per 10 CFR 50.75(c) $675, 110 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) $9,293 (a) 4 The amount of decommissioning trust funds accumulated as of $650,757 (b)

December 31, 2020 5 Schedule of the annual amounts remaining to be collected. $0 6 Assumptions used regarding rates of escalation, earnings, and 2% (c) other factors used in funding projections 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 The trust fund agreements were amended effective September 30 , 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021 .

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 17, 2027.

Page 1 of 1

ATTACHMENT 9 Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2020 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) $458,956 (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, 2020 $421,075 (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 January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC . In addition , the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

10 2020 annual amount spent on decommissioning in $1,663 (e) accordance with 10 CFR 50.82(a)(8)(v)(A).

11 Cumulative amount spent on decommissioning in $130,821 (f) accordance with 10 CFR 50.82(a)(8)(v)(A).

Reimbursed from the decommissioning trust fund $129, 158 (g)

Not yet reimbursed from the decommissioning trust $1,663 (h) fund 12 Amount of funds accumulated to cover the cost of $44,356 (i) managing irradiated fuel pursuant to 10 CFR 50.82(a)(8)(vii)(A) as of December 31, 2020.

13 Projected cost of managing irradiated fuel based on $48,715(a) site-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 , 2020 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

$574.1 million (as of December 31, 2020). 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 DEGON scenario as described in the site-specific cost estimate (SSCE) (TLG Report E16-1726-009, Revision 0, "Decommissioning Cost Analysis for the Dresden Nuclear Power Station Unit 1," December 2017). 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 Michael P. Gallagher (EGC) to U.S. NRC on March 19, 2018. The costs have been escalated from the 2017 dollars reflected in the 2017 decommissioning cost estimate to estimated costs as of December 31, 2020.

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 2017 through 2020 annual radiological cost because EGC considers the SSCE estimated cost for 2017 through 2020 decommissioning activities to be historical expenditures at the time the 2021 decommissioning funding assurance report is generated .

Decontamination and dismantlement of Dresden Nuclear Power Station, Unit 1, will take place no earlier than 2029.

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

Page 2 of 6

ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31 , 2020 dollars, thousands)

(c) The trust fund amount is the amount allocated for radiological decommissioning only.

The allocation of funds for radiological decommissioning is based on the fraction of radiological decommissioning costs to radiological decommissioning costs plus spent fuel management costs identified in the DECON scenario as described in the site-specific cost estimate (SSCE) (TLG Report E16-1726-009, Revision 0, "Decommissioning Cost Analysis for the Dresden Nuclear Power Station Unit 1,"

December 2017). This allocation is for purposes of demonstrating adequate decommissioning funding assurance only and is adjusted, as necessary, to provide adequate funding assurance for radiological decommissioning and spent fuel management. No spent fuel management costs are planned to be incurred until 2029.

There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds . The reported 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, 2020.

(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 2020 is consistent with the projected 2020 expense total of $3,632 (December 31 , 2020 thousands of dollars) from the site-specific cost estimate. The delta of $1,969 can be attributed to lower dormancy costs in 2020 than projected in the site specific cost estimate.

The amount spent on decommissioning in 2020 represents the 2020 charges to the Dresden Unit 1 project. Prior to reimbursement from the decommissioning trust fund, these charges will be validated to confi rm they are legitimate decommissioning expenses. Consequently, the amount reimbursed may differ from the value provided.

(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 .

(g) Not all historical data was available, and therefore , the amount reimbursed is an estimate based on the best information obtainable at this time.

(h) The amount not yet reimbursed is an estimate based on the best information obtainable at this time .

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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, 2020 dollars, thousands)

(i) The allocation of funds accumulated for managing irradiated fuel is based on the fraction of spent fuel management costs to radiological decommissioning costs plus spent fuel management costs identified in the DECON scenario as described in the site-specific cost estimate (SSCE) (TLG Report E16-1726-009, Revision 0, "Decommissioning Cost Analysis for the Dresden Nuclear Power Station Unit 1,"

December 2017). This allocation is for purposes of demonstrating adequate decommissioning funding assurance only and is adjusted, as necessary, to provide adequate funding assurance for radiological decommissioning and spent fuel management. No spent fuel management costs are planned to be incurred until 2029.

Page 4 of 6

ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2020 dollars, thousands)

BOY BOY EOY Radiological Trust Trust Fund Trust Trust Decommissioning Fund Value Fund Fund Year Cost Value Less Cost Earnings Value 2021 $3,622 $421,075 $417,453 $8,349 $425,802 2022 $3,622 $425,802 $422,180 $8,444 $430,623 2023 $3,622 $430,623 $427,001 $8,540 $435,541 2024 $3,632 $435,541 $431,908 $8,638 $440,547 2025 $3,622 $440,547 $436,924 $8,738 $445,663 2026 $3,622 $445,663 $442,040 $8,841 $450,881 2027 $3,622 $450,881 $447,259 $8,945 $456,204 2028 $3,662 $456,204 $452,581 $9,052 $461,633 2029 $44,699 $461,633 $416,934 $8,339 $425,272 2030 $93,483 $425,272 $331,789 $6,636 $338,425 2031 $106,851 $338,425 $231,574 $4,631 $236,205 2032 $73,947 $236,205 $162,259 $3,245 $165,504 2033 $65,346 $165,504 $100,157 $2,003 $102,160 2034 $2,547 $102,160 $99,614 $1,992 $101,606 2035 $2,547 $101,606 $99,059 $1,981 $101,040 2036 $2,547 $101,040 $98,494 $1,970 $100,464 2037 $20,270 $100,464 $80,193 $1,604 $81,797 2038 $7,777 $81,797 $74,020 $1,480 $75,501 2039 $108 $75,501 $75,392 $1,508 $76,900 2040 $62 $76,900 $76,838 $1,537 $78,375 2041 $0 $78,375 $78,375 $1,567 $79,942 2042 $0 $79,942 $79,942 $1,599 $81,541 2043 $0 $81,541 $81,541 $1,631 $83,172 2044 $0 $83,172 $83,172 $1,663 $84,835 2045 $0 $84,835 $84,835 $1,697 $86,532 2046 $0 $86,532 $86,532 $1,731 $88,262 2047 $0 $88,262 $88,262 $1,765 $90,028 2048 $0 $90,028 $90,028 $1,801 $91,828 2049 $0 $91,828 $91,828 $1,837 $93,665 2050 $9,316 $93,665 $84,348 $1,687 $86,035 2051 $465 $86,035 $85,570 $1,711 $87,282 Total* $458,956

• Column may not add due to rounding Page 5 of 6

ATTACHMENT 9 (Continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Dresden Nuclear Power Station, Unit 1 (December 31, 2020 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 2021 $0 $44,356 $44,356 $ 887 $45,243 2022 $0 $45,243 $45,243 $ 905 $46,148 2023 $0 $46 ,148 $46,148 $ 923 $47,070 2024 $0 $47,070 $47,070 $ 941 $48,012 2025 $0 $48,012 $48,012 $ 960 $48,972 2026 $0 $48,972 $48,972 $ 979 $49,952 2027 $0 $49,952 $49,952 $ 999 $50,951 2028 $0 $50,951 $50,951 $ 1,019 $51,970 2029 $449 $51,970 $51,520 $ 1,030 $52,551 2030 $527 $52,551 $52,024 $ 1,040 $53,064 2031 $527 $53,064 $52,537 $ 1,051 $53,588 2032 $527 $53,588 $53,060 $ 1,061 $54,122 2033 $655 $54,122 $53,467 $ 1,069 $54,536 2034 $1,550 $54 ,536 $52,986 $ 1,060 $54,046 2035 $1,550 $54,046 $52,496 $ 1,050 $53,546 2036 $1,550 $53,546 $51,995 $ 1,040 $53,035 2037 $1,958 $53,035 $51,077 $ 1,022 $52,099 2038 $2,559 $52,099 $49,540 $ 991 $50,530 2039 $2,630 $50,530 $47,901 $ 958 $48,859 2040 $2,688 $48,859 $46, 171 $ 923 $47,094 2041 $2,773 $47,094 $44,321 $ 886 $45,208 2042 $2,765 $45,208 $42,443 $ 849 $43,291 2043 $2,765 $43,291 $40,526 $ 811 $41,337 2044 $5,288 $41,337 $36,048 $ 721 $36,769 2045 $4,036 $36,769 $32,733 $ 655 $33,388 2046 $2,765 $33,388 $30,623 $ 612 $31,235 2047 $2,765 $31,235 $28,470 $ 569 $29,039 2048 $2,765 $29,039 $26,274 $ 525 $26,800 2049 $2,773 $26,800 $24,027 $ 481 $24,507 2050 $2,848 $24,507 $21,659 $ 433 $22,093 2051 $0 $22,093 $22,093 $ 442 $22,534 Total* $48,715

• Column may not add due to rounding Page 6 of 6

ATTACHMENT 10 Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $653, 172 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) $10,442 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $876,248 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 November 30, 2021 .

Page 1 of 1

ATTACHMENT 11 Annual Radiological Decommissioning Funding Assurance Report for Dresden Nuclear Power Station, Unit 3 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $653, 172 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) $10,442 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $895,711(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 The trust fund agreements were amended effective September 30 , 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021 .

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 November 30, 2021 .

Page 1 of 1

ATTACHMENT 12 Annual Radiological Decommissioning Funding Assurance Report for James A. FitzPatrick Nuclear Power Station (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $652, 122 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) $10,491 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $918,408 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 October 17, 2034.

Page 1 of 1

ATTACHMENT 13 Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $675, 110 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) $7,385 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $641,347 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 17, 2042.

Page 1 of 1

ATTACHMENT 14 Annual Radiological Decommissioning Funding Assurance Report for LaSalle County Station, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $675, 110 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) $7,385 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $640,703 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 16, 2043.

Page 1 of 1

ATTACHMENT 15 Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $694,162 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) $7,519 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $562,780 (b) 5 Schedule of the annual amounts remaining to be collected. $0 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 15 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 1 (December 31, 2020 dollars, thousands)

(c) The fund ing 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, 2018, and allows for the collection of annual payments from ratepayers of

$0 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 16 Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $694,162 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) $7,519 (a) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $601,050 (b) 5 Schedule of the annual amounts remaining to be collected. $0 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 16 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Limerick Generating Station, Unit 2 (December 31, 2020 dollars, thousands)

(c) The fund ing 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, 2018, and allows for the collection of annual payments from ratepayers of

$0 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 17 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $620,376 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) $7,048 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $788,530 (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 January 1, 2021, the direct owners of the trusts for Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, transferred the trusts from Mellon Bank as Trustee to Northern Trust as Trustee . In conjunction with that change, each direct owner and Northern Trust entered into new qualified trust agreements and non-qualified trust agreements, with a common set of Master Terms for Trust Agreements . These new trust agreements are substantively the same as the agreements with Northern Trust for Exelon Generation's other nuclear units. As a result of the change in Trustee, there is now one Trustee for all of the decommissioning trusts for Exelon Generation's directly and indirectly owned nuclear units. The change in Trustee is intended to result in cost savings for the Calvert Cliffs, Nine Mile Point, and Ginna trusts and improve trust administration and the investment processes. The NRC was notified of the planned change in Trustee, along with changes in the trust agreements, by letter dated October 30, 2020.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 17 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands)

(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 2 of 2

ATTACHMENT 18 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2, EGC Portion (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $569,213 (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) $5,780 (a)(b) 4 The amount of decommissioning trust funds accumu lated as of December 31 , 2020 $499,352 (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 January 1, 2021 , the direct owners of the trusts for Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, transferred the trusts from Mellon Bank as Trustee to Northern Trust as Trustee . In conjunction with that change , each direct owner and Northern Trust entered into new qualified trust agreements and non-qualified trust agreements, with a common set of Master Terms for Trust Agreements . These new trust agreements are substantively the same as the agreements with Northern Trust for Exelon Generation's other nuclear units. As a result of the change in Trustee, there is now one Trustee for all of the decommissioning trusts for Exelon Generation's directly and indirectly owned nuclear units. The change in Trustee is intended to result in cost savings for the Calvert Cliffs, Nine Mile Point, and Ginna trusts and improve trust administration and the investment processes. The NRC was notified of the planned change in Trustee, along with changes in the trust agreements, by letter dated October 30, 2020 .

(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 costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

Page 1 of 2

ATTACHMENT 18 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2, EGC Portion (December 31, 2020 dollars, thousands)

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

(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 2 of 2

ATTACHMENT 19 Annual Radiological Decommissioning Funding Assurance Report for Nine Mile Point Nuclear Station, Unit 2, LIPA Portion (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $124,949 (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) $1,267 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $130,564 (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 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 costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The total trust fund amount is $164,085 with a portion allocated to contaminated (radiological) decommissioning and a portion allocated to non-contaminated decommissioning . The amount allocated to contaminated decommissioning is

$130,564 . These amounts were 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, 2020 . 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 ,

2020. 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 20 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2020 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) $276,849(a) 3 Site-specific cost amount per 10 CFR 72.30(b) N/A (h) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $148,815 (b) 5 Schedule of the annual amounts remaining to be collected . $3,860 (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 January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

10 2020 annual amount spent on decommissioning in $1 ,999 (e) accordance with 10 CFR 50.82(a)(8)(v)(A).

11 Cumulative amount spent on decommissioning in $13,592 (f) accordance with 10 CFR 50.82(a)(8)(v)(A).

Reimbursed from the decommissioning trust fund $4,094 Not yet reimbursed from the decommissioning trust fund $9,497 (g) 12 Amount of funds accumulated to cover the cost of managing N/A (h) irradiated fuel pursuant to 10 CFR 50.82(a)(8)(vii)(A) as of December 31 , 2020 .

13 Projected cost of managing irradiated fuel based on site- N/A (h) 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, 2020 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)(iii), and 50.82(a)(8)(v)(B) and assumes a DEGON scenario as described in the site-specific cost estimate (SSCE) (DECOM-2020-DCE-PEA 1, Revision 0, "Decommissioning Cost Analysis Report Peach Bottom Atomic Power Station Unit 1"). The decommissioning cost estimate is consistent with the description of planned decommissioning activities in the Peach Bottom Unit 1 Decommissioning Plan. The costs have been escalated from the mid-year 2020 dollars reflected in the SSCE to estimated costs as of December 31, 2020.

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 for the annual radiological decommissioning costs for 2020. EGC considers the SSCE estimated costs for 2020 decommissioning activities to be historical expenditures at the time the 2021 decommissioning funding assurance report is generated.

It is EGCs intention to delay the start of decontamination and dismantlement (D&D) of Peach Bottom, Unit 1 until 2053 to coincide with the license expiration of Peach Bottom, Unit 2. Per 10 CFR 50.82(a)(3), D&D of a unit can extend beyond 60 years after permanent cessation of operation if approved by the NRC. Because there will be two operating nuclear units at the Peach Bottom site, EGC concludes delaying the D&D of Peach Bottom, Unit 1 is prudent, as comtemplated in 10 CFR 50.82(a)(3). However, the 2053 start of D&D for Peach Bottom, Unit 1 will not be reflected in the funding adequacy analysis for the unit until an exemption to 10 CFR 50.83(a)(3) is requested and approved . As in prior submission reports, this submission uses 2033 as the start, and 2038 as the end, date of D&D of Peach Bottom, Unit 1.

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 2 of 4

ATTACHMENT 20 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2020 dollars, thousands)

(c) The fund ing 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, 2018, and allows for the collection of annual payments from ratepayers of

$3,860K through 2032.

(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 Pa PUC 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. Nuclear Regulatory Commission , "Response to Request for Additional Information Related to 2013 Report on Status of Decommissioning Funding for Reactors," dated August 15, 2013.

(e) The amount spent on decommissioning in 2020 is consistent with the projected 2020 expense total of $1,066 (December 31, 2020 thousands of dollars) from the site-specific cost estimate. The delta of $933 can be attributed to decommissioning work performed in 2020 that was planned to occur later in the site specific cost estimate.

This work included asbestos abatement and hazardous waste removal.

The amount spent on decommissioning in 2020 represents the 2020 charges to the Peach Bottom Unit 1 project. Prior to reimbursement from the decommissioning trust fund , these charges will be validated to confirm they are legitimate decommissioning expenses. Consequently, the amount reimbursed may differ from the value provided.

(f) The cumulative amount spent on decommissioning is an estimate based on the best information obtainable at this time.

(g) The amount not yet reimbursed is an estimate based on the best information obtainable at this time .

(h) 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)(vi i) and 10 CFR 72.30(b) do not apply.

Page 3 of 4

ATTACHMENT 20 (Continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 1 (December 31, 2020 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 2021 $228 $148,815 $148,586 $1,930 $4,515 $1,930 $156,962 2022 $228 $156,962 $156,733 $1,930 $4,760 $1,930 $165,353 2023 $228 $165,353 $165,125 $1,930 $5,012 $1,930 $173,997 2024 $229 $173,997 $173,767 $1,930 $5,271 $1,930 $182,898 2025 $228 $182,898 $182,670 $1,930 $5,538 $1,930 $192,068 2026 $228 $192,068 $191,840 $1,930 $5,813 $1,930 $201,513 2027 $228 $201,513 $201,284 $1,930 $6,096 $1,930 $211,241 2028 $229 $211,241 $211,012 $1,930 $6,388 $1,930 $221,260 2029 $228 $221,260 $221,031 $1,930 $6,689 $1,930 $231,580 2030 $228 $231,580 $231,352 $1,930 $6,998 $1,930 $242,210 2031 $228 $242,210 $241,982 $1,930 $7,317 $1,930 $253,159 2032 $229 $253,159 $252,930 $1,930 $7,646 $1,930 $264,436 2033 $40,896 $264,436 $223,539 $- $6,706 $- $230,246 2034 $61,602 $230,246 $168,644 $- $5,059 $- $173, 703 2035 $71,095 $173,703 $102,608 $- $3,078 $- $105,687 2036 $51,918 $105,687 $53,768 $- $1,613 $- $55,381 2037 $46,068 $55,381 $9,313 $- $279 $- $9,593 2038 $2,526 $9,593 $7,066 $- $212 $- $7,278 Total* $276,849

• Columns 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 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $347,081 (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) $3,135 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $340,962 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

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

(b) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 21 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 2 (December 31, 2020 dollars, thousands)

(d) The fund ing 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 Adj ustment (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, 2018 , 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 Pa PUC 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, 2053.

Page 2 of 2

ATTACHMENT 22 Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 3 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $347,081 (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) $3,135 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $369,267 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition , the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station , Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

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

(b) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31 , 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 22 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Peach Bottom Atomic Power Station, Unit 3 (December 31, 2020 dollars, thousands)

(d) The fund ing 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 Adj ustment (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, 2018 , 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 Pa PUC 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 July 2, 2054.

Page 2 of 2

ATTACHMENT 23 Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $489,879 (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) $6,345 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $553,072 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021, the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRG. In addition , the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

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

(b) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGG during the year on a quarterly basis. EGG then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 23 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 1 (December 31, 2020 dollars, thousands)

(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 2 of 2

ATTACHMENT 24 Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 2 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $489,879(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) $6,345 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $621,761 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021 .

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

(b) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 24 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Quad Cities Nuclear Power Station, Unit 2 (December 31, 2020 dollars, thousands)

(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 2 of 2

ATTACHMENT 25 Annual Radiological Decommissioning Funding Assurance Report for R.E. Ginna Nuclear Power Plant (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $464,840 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) $7,055 (a) 4 The amount of decommissioning trust funds accumulated as of December 31, 2020 $575,950 (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 January 1, 2021, the direct owners of the trusts for Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, transferred the trusts from Mellon Bank as Trustee to Northern Trust as Trustee . In conjunction with that change, each direct owner and Northern Trust entered into new qualified trust agreements and non-qualified trust agreements, with a common set of Master Terms for Trust Agreements . These new trust agreements are substantively the same as the agreements with Northern Trust for Exelon Generation's other nuclear units. As a result of the change in Trustee, there is now one Trustee for all of the decommissioning trusts for Exelon Generation's directly and indirectly owned nuclear units. The change in Trustee is intended to result in cost savings for the Calvert Cliffs, Nine Mile Point, and Ginna trusts and improve trust administration and the investment processes. The NRC was notified of the planned change in Trustee, along with changes in the trust agreements, by letter dated October 30, 2020.

(a) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(b) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 25 (continued)

Annual Radiological Decommissioning Funding Assurance Report for R.E. Ginna Nuclear Power Plant (December 31, 2020 dollars, thousands)

(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 2 of 2

ATTACHMENT 26 Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $218,431 (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) $2,277 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $315,827 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

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

(b) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31, 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 26 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 1 (December 31, 2020 dollars, thousands)

(d) The fund ing 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 Adj ustment (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, 2018 , 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 Pa PUC 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 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $218,431 (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) $2,277 (a)(b) 4 The amount of decommissioning trust funds accumulated as of December 31 , 2020 $262,384 (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 The trust fund agreements were amended effective September 30, 2019 to reflect a change of the company holding the trusts from a Nevada LLC to an Illinois LLC.

Effective January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station, Units 1 and 2, and R.E . Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

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

(b) The costs from the current detailed site-specific ISFSI decommissioning cost estimate have been escalated to December 31 , 2020 dollars using published escalation indices. Attachments 29 and 30 provide information on the detailed decommissioning funding plan, detailed site-specific ISFSI decommissioning cost estimate, and the occurrence and the effect on the ISFSI decommissioning costs of the events listed in 10 CFR 72.30 (c)(1 )-(4).

(c) The trust fund amount is the amount allocated for Radiological Decommissioning only. There are no past-due tax payments owed on the decommissioning trust fund activities as of December 31, 2020. Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis. EGC then obtains reimbursement from the trust funds. The reported 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, 2020.

Page 1 of 2

ATTACHMENT 27 (continued)

Annual Radiological Decommissioning Funding Assurance Report for Salem Generating Station, Unit 2 (December 31, 2020 dollars, thousands)

(d) The fund ing 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 Adj ustment (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, 2018 , 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 Pa PUC 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 and Spent Fuel Management Report for Three Mile Island Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands) 1 Formula cost amount per 10 CFR 50.75(c) $500,636 2 Site-specific cost amount per 10 CFR 50.75(b)(4) and $955, 103 (a) 50.75(f) 3 Site-specific cost amount per 10 CFR 72 .30(b) N/A (b) 4 The amount of decommissioning trust funds accumulated as $742,497 (c) of December 31, 2020 5 Schedule of the annual amounts remaining to be collected $0 6 Assumptions used regarding rates of escalation, earnings, 2% (d) and other factors used in funding projections 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 January 1, 2021 , the non-qualified trust agreement, qualified trust agreement, and Master Terms for Trust Agreements were updated to incorporate amendments previously provided to the NRC. In addition, the Master Terms for Trust Agreements were updated to include the non-qualified trust agreements and qualified trust agreements between the direct owners of Calvert Cliffs Nuclear Power Plant, Units 1 and 2, Nine Mile Point Nuclear Station , Units 1 and 2, and R.E. Ginna Nuclear Power Plant, Unit 1, and Northern Trust as Trustee that became effective January 1, 2021.

10 2020 annual amount spent on decommissioning in accordance with 10 CFR 50.82(a)(8)(v)(A) $57,338 (e) 11 Cumulative amount spent on decommissioning in accordance with 10 CFR 50.82(a)(8)(v)(A) $84,234 (g)

Reimbursed from the decommissioning trust fund $69,651 Not yet reimbursed from the decommissioning trust fund $14,583 (f) 12 Amount of funds accumulated to cover the cost of managing irradiated fuel pursuant to 10 CFR 50.82(a)(8)(vii)(A) as of December 31, 2020 (c) 13 Projected cost of managing irradiated fuel based on site-specific estimate per 10 CFR 50.82(a)(8)(vii)(B) $105,467 (a) 14 2020 annual amount spent on irradiated fuel management $30,906 (e) 15 Cumulative amount spent on irradiated fuel management $61,465 (g)

Reimbursed $8,579 (h)

Not yet reimbursed $52,886 (f)

Page 1 of 5

ATTACHMENT 28 (continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Three Mile Island Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands)

(a) 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 SAFSTOR scenario as described in the site-specific cost estimate (SSCE) ("Site-Specific Decommissioning Cost Estimate for Three Mile Island Nuclear Station, Unit 1," April 5, 2019). The costs have been escalated from the 2018 dollars reflected in the decommissioning cost estimate to estimated costs as of December 31, 2020.

The amount reported does not include cash flows from the SSCE estimate for the 2019 and 2020 annual radiological and spent fuel costs because EGC considers the SSCE estimated costs for 2019 and 2020 decommissioning activities to be historical expenditures at the time the 2021 decommissioning funding assurance report is generated.

(b) Three Mile Island does not have an ISFSI. Therefore, 10 CFR 72 does not apply to Three Mile Island.

(c) The trust fund amount is the amount allocated for Radiological Decommissioning and Spent Fuel Management. There are no past-due tax payments related to decommissioning trust fund activities as of December 31, 2020 . Periodic payments of estimated income taxes are made by EGC during the year on a quarterly basis.

EGC then obtains reimbursements from the trust funds . The reported 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, 2020.

(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 2020 is less than the projected 2020 expense total of $70,026 (December 31, 2020 thousands of dollars) from the site-specific cost estimate. The decrease of $12,688 can be attributed to the actual costs being lower than estimated for labor, energy, modifications, insurance, and regulatory fees .

The amount spent on irradiated fuel management in 2020 is consistent with the projected 2020 expense total of $32,607 (December 31, 2020 thousands of dollars) from the site-specific cost estimate (SSCE).

The amount spent on radiological decommissioning and irradiated fuel management in 2020 represents the 2020 charges to the TMI, Unit 1, project. Prior to reimbursement from the decommissioning trust fund, these charges will be validated to confirm they are legitimate decommissioning expenses. Consequently, the amount reimbursed may differ from the value provided .

(f) The amount not yet reimbursed is an estimate based on the best information obtainable at this time.

Page 2 of 5

ATTACHMENT 28 (continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Three Mile Island Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands)

(g) The cumulative amount spent is an estimate based on the best information obtainable at this time .

(h) The amount of irradiated fuel management reimbursed is the amount reimbursed by the decommissioning trust fund or the Department of Energy.

Page 3 of 5

ATTACHMENT 28 (continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Three Mile Island Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands)

Radiological BOY BOY EOY Decommisioning Trust Trust Fund Trust Trust and Spent Fuel Fund Value Fund Fund Year Cost Value Less Cost Earnings Value 2021 $74,789 $742,497 $667,709 $13,354 $681,063 2022 $55,784 $681,063 $625,280 $12,506 $637,785 2023 $10,748 $637,785 $627,038 $12,541 $639,578 2024 $10,778 $639,578 $628,800 $12,576 $641,376 2025 $10,748 $641,376 $630,629 $12,613 $643,241 2026 $10,748 $643,241 $632,494 $12,650 $645,144 2027 $10,748 $645,144 $634,396 $12,688 $647,084 2028 $10,777 $647,084 $636,307 $12,726 $649,033 2029 $10,748 $649,033 $638,285 $12,766 $651,051 2030 $10,748 $651,051 $640,303 $12,806 $653,110 2031 $10,748 $653,110 $642,362 $12,847 $655,209 2032 $10,777 $655,209 $644,432 $12,889 $657,321 2033 $10,748 $657,321 $646,573 $12,931 $659,505 2034 $14,146 $659,505 $645,359 $12,907 $658,266 2035 $20,870 $658,266 $637,396 $12,748 $650,144 2036 $6,003 $650,144 $644,142 $12,883 $657,025 2037 $5,986 $657,025 $651,038 $13,021 $664,059 2038 $5,986 $664,059 $658,073 $13,161 $671,234 2039 $5,986 $671,234 $665,248 $13,305 $678,553 2040 $6,003 $678,553 $672,550 $13,451 $686,001 2041 $5,986 $686,001 $680,015 $13,600 $693,615 2042 $5,986 $693,615 $687,629 $13,753 $701,381 2043 $5,986 $701,381 $695,395 $13,908 $709,303 2044 $6,003 $709,303 $703,300 $14,066 $717,366 2045 $5,986 $717,366 $711,380 $14,228 $725,608 2046 $5,986 $725,608 $719,621 $14,392 $734,014 2047 $5,986 $734,014 $728,027 $14,561 $742,588 2048 $6,003 $742,588 $736,585 $14,732 $751,317 2049 $5,986 $751,317 $745,331 $14,907 $760,237 2050 $5,986 $760,237 $754,251 $15,085 $769,336 2051 $5,986 $769,336 $763,350 $15,267 $778,617 Page 4 of 5

ATTACHMENT 28 (continued)

Annual Radiological Decommissioning Funding Assurance and Spent Fuel Management Report for Three Mile Island Nuclear Station, Unit 1 (December 31, 2020 dollars, thousands)

Radiological BOY BOY EOY Decommisioning Trust Trust Fund Trust Trust and Spent Fuel Fund Value Fund Fund Year Cost Value Less Cost Earnings Value 2052 $6,003 $778,617 $772,614 $15,452 $788,066 2053 $5,986 $788,066 $782,080 $15,642 $797,722 2054 $5,986 $797,722 $791,735 $15,835 $807,570 2055 $5,986 $807,570 $801,584 $16,032 $817,616 2056 $6,003 $817,616 $811,613 $16,232 $827,845 2057 $ 5,986 $827,845 $821,859 $16,437 $838,296 2058 $5,986 $838,296 $832,310 $16,646 $848,956 2059 $5,986 $848,956 $842,970 $16,859 $859,829 2060 $6,003 $859,829 $853,826 $ 17,077 $870,903 2061 $5,986 $870,903 $864,917 $ 17,298 $882,215 2062 $5,986 $882,215 $876,229 $ 17,525 $893,753 2063 $5,986 $893,753 $887,767 $17,755 $905,522 2064 $6,003 $905,522 $899,520 $17,990 $917,510 2065 $5,986 $917,510 $911,524 $18,230 $929,754 2066 $5,986 $929,754 $923,768 $18,475 $942,243 2067 $5,986 $942,243 $936,257 $18,725 $954,982 2068 $6,003 $954,982 $948,979 $18,980 $967,959 2069 $5,986 $967,959 $961,973 $19,239 $981,212 2070 $5,986 $981,212 $975,226 $19,505 $994,730 2071 $5,986 $994,730 $988,744 $19,775 $ 1,008,519 2072 $6,003 $1,008,519 $1,002,516 $20,050 $ 1,022,566 2073 $26,013 $1,022,566 $996,554 $19,931 $ 1,016,485 2074 $64,456 $1,016,485 $952,029 $19,041 $971,069 2075 $158,231 $971,069 $812,838 $16,257 $829,095 2076 $118,027 $829,095 $711,068 $14,221 $725,290 2077 $76,834 $725,290 $648,455 $12,969 $661,424 2078 $76,667 $661,424 $584,757 $11,695 $596,452 2079 $34,545 $596,452 $561,907 $11,238 $573,146 2080 $140 $573,146 $573,006 $11,460 $584,466 2081 $100 $584,466 $584,366 $11,687 $596,054 Total* $1,060,570

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

ATTACHMENT 29 ISFSI Decommissioning Funding Estimates Braidwood Station (December 31, 2020 dollars, thousands)

Burial Removal Packaging Transport LLRW Activity Description Other Costs Total Costs Volume Class Costs Costs Costs Disposal Costs A(ft3)

Decommissioning Contractor Decontamination (activated disposition) $466 $483 $754 $1,933 $3,636 29,098 Licen se Termination (radiological surveys) $3,702 $3,702 Subtotal $466 $483 $754 $1,933 $3,702 $7,339 29,098 Supporting Costs Utility Staff Cost

$348 $348 Security Staff Cost $261 $261 Insurance and NRC Fees $429 $429 Property Taxes $347 $347 Plant Energy Budget

$61 $61 Heavy Equipment Rental

$320 $320 Subtotal $320 $0 $0 $0 $1,447 $1,766 Total (w/o contingency) $786 $483 $754 $1,933 $5,149 $9,105 29,098 Total (w/25% contingency) $982 $603 $943 $2,416 $6,436 $11,381 Note: Values may not add due to rounding.

Costs for ISFSI decommissioning are split equally between the two units.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates Byron Station (December 31, 2020 dollars, thousands)

Removal Packaging Transport LLRW Burial Volume Activity Description Other Costs Total Costs Costs Costs Costs Disposal Costs Class A (ft3)

Decommissioning Contractor Decontamination (activated 29,099 disposition) $482 $459 $749 $1,933 $3,622 License Termination (radiological surveys) $3,497 $3,497 Subtotal $482 $459 $749 $1,933 $3,497 $7,119 29,099 Supporting Costs Utility Staff Cost

$348 $348 Security Staff Cost $259 $259 Insurance and NRC Fees $358 $358 Property Taxes $345 $345 Plant Energy Budget

$61 $61 Heavy Equipment Rental

$317 $317 Subtotal $317 $0 $0 $0 $1,369 $1,686 Total (w/o contingency) $799 $459 $749 $1,933 $4,866 $8,805 29,099 Total (w/25% contingency) $998 $573 $937 $2,416 $6,083 $11,007 Note: Values may not add due to rounding .

Costs for ISFSI decommissioning are split equally between the two units.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates Dresden Nuclear Power Station (December 31, 2020 dollars, thousands)

Burial LLRW Removal Packaging Transport Volume Activity Description Disposal Other Costs Total Costs Costs Costs Costs Class A Costs (ft3)

Decommissioning Contractor Decontamination (activated 110,477 disposition) $702 $484 $1,957 $6,875 $10,017 License Termination (radiological surveys) $4,782 $4,782 Subtotal $702 $484 $1,957 $6,875 $4,782 $14,800 110,477 Supporting Costs Utility Staff Cost

$351 $351 Security Staff Cost $251 $251 Insurance and NRC Fees $412 $412 Property Taxes $345 $345 Plant Energy Budget

$126 $126 Heavy Equipment Rental

$423 $423 Subtotal $423 $0 $0 $0 $1,484 $1,907 Total (w/o contingency) $1,124 $484 $1,957 $6,875 $6,267 $16,707 110,477 Total (w/25% contingency) $1,405 $605 $2,447 $8,593 $7,833 $20,883 Note: Values may not add due to rounding .

Costs for ISFSI decommissioning are split equally between units 2 and 3.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates LaSalle County Station Station (December 31, 2020 dollars, thousands)

Burial Removal Packaging Transport LLRW Activity Description Other Costs Total Costs Volume Class Costs Costs Costs Disposal Costs A (ft3)

Decommissioning Contractor Decontamination 49,274 (activated disposition) $702 $781 $1,167 $3,251 $5,901 License Termination (radiological surveys) $4,148 $4,148 Subtotal $702 $781 $1,167 $3,251 $4,148 $10,049 49,274 Supporting Costs Utility Staff Cost

$345 $345 Security Staff Cost $263 $263 Insurance and NRC Fees $439 $439 Property Taxes $345 $345 Plant Energy Budget

$58 $58 Heavy Equipment Rental

$317 $317 Subtotal $317 $0 $0 $0 $1,450 $1,767 Total (w/o contingency) $1019 $781 $1,167 $3,2Sl $5,598 $11,816 49,274 Total (w/25% contingency) $1,273 $977 $1,458 $4,063 $6,998 $14,770 Note: Values may not add due to rounding .

Costs for ISFSI decommissioning are split equally between the units.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates Limerick Generation Station (December 31, 2020 dollars, thousands)

Burial LLRW Removal Packaging Transport Other Volume Activity Description Disposal Total Costs Costs Costs Costs Costs Class A Costs (ft3)

Decommissioning Contractor Decontamination (activated 60,639 disposition) $826 $228 $1,049 $1,944 $4,047 Characterization and Licensing Surveys $5,355 $5,355 Subtotal $826 $228 $1,049 $1,944 $5,355 $9,402 60,639 Supporting Costs Utility Staff Cost

$557 $557 Security Staff Cost $677 $677 Insurance $1,205 $1,205 Property Taxes $113 $113 Plant Energy Budget

$33 $33 Equipment and Supplies

$44 $44 Subtotal $44 $0 $0 $0 $2,584 $2,628 Total (w/o contingency) $869 $228 $1,049 $1,944 $7,939 $12,030 60,639 Total (w/25% contingency) $1,087 $285 $1,312 $2,430 $9,924 $15,037 Note: Values may not add due to rounding.

Costs for ISFSI decommissioning are split equally between the units.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates Nine Mile Point Nuclear Station (December 31, 2020 dollars, thousands)

LLRW Burial Removal Packaging Transport Activity Description Disposal Other Costs Total Costs Volume Costs Costs Costs Costs Class A (ft3)

Decommissioning Contractor Decontamination 40,659 (activated disposition) $600 $7 $1,696 $2,798 $5,101 License Termination (radiological surveys) $4,453 $4,453 Subtotal $600 $7 $1,696 $2,798 $4,453 $9,554 40,659 Supporting Costs Utility Staff Cost

$351 $351 Security Staff Cost $301 $301 Insurance and NRC Fees $348 $348 Property Taxes $345 $345 Pl ant Energy Budget

$47 $47 Heavy Equipment Rental

$331 $331 Subtotal $331 $0 $0 $0 $1,393 $1, 723 Total (w/o contingency) $931 $7 $1,696 $2,798 $5,845 $11,277 40,659 Total (w/25% contingency) $1,164 $9 $2,120 $3,497 $7,306 $14,096 Note: Values may not add due to rounding .

Costs for ISFSI decommissioning are split equally between the units.$7,031 is the total cost for Nine Mile Point Unit 2. Exelon is responsible for 82% of this cost and LIPA is responsible for 18% of this cost.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates Peach Bottom Atomic Power Station (December 31, 2020 dollars, thousands)

LLRW Burial Removal Packaging Transport Activity Description Disposal Other Costs Total Costs Volume Costs Costs Costs Costs Class A (ft3)

Decommissioning Contractor Decontamination (activated 60,639 disposition) $653 $186 $919 $1,944 $3,702 Characterization and Licensing Surveys $3,939 $3,939 Subtotal $653 $186 $919 $1,944 $3,939 $7,641 60,639 Supporting Costs Utility Staff Cost

$548 $548 Security Staff Cost $640 $640 Insurance and NRC Fees $1,066 $1,066 Property Taxes $75 $75 Plant Energy Budget

$33 $33 Equipment and Supplies

$29 $29 Subtotal $29 $0 $0 $0 $2,362 $2,391 Total (w/o contingency) $682 $186 $919 $1,944 $6,301 $10,032 60,639 Total (w/25% contingency) $852 $233 $1,149 $2,430 $7,876 $12,540 Note: Values may not add due to rounding .

Costs for ISFSI decommissioning are split equally between units 2 and 3.

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ATTACHMENT 29 {Continued)

ISFSI Decommissioning Funding Estimates R.E. Ginna Nuclear Power Plant (December 31, 2020 dollars, thousands)

LLRW Burial Removal Packaging Transport Activity Description Disposal Other Costs Total Costs Volume Costs Costs Costs Costs Class A (ft3)

Decommissioning Contractor Decontamination 8,731 (activated disposition) $398 $3 $516 $738 $1,654 License Termination (radiological su rveys) $2,531 $2,531 Subtotal $398 $3 $516 $738 $2,531 $4,186 8,731 Supporting Costs Utility Staff Cost

$341 $341 Security Staff Cost $226 $226 Insurance and NRC Fees $196 $196 Property Taxes $345 $345 Pl ant Energy Budget

$34 $34 Heavy Equipment Rental

$317 $317 Subtotal $317 $0 $0 $0 $1,141 $1,458 Total (w/o contingency) $715 $3 $516 $738 $3,672 $5,644 8,731 Total (w/25% contingency) $893 $3 $645 $923 $4,591 $7,055 Note: Values may not add due to rounding.

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ATTACHMENT 30 fndependent Spent Fuel Storage fnstallation Decommissioning Funding Plan Updates Pursuant to 10 CFR 72.30(b), decommissioning funding plans (DFPs) are required for all independent spent fuel storage installations (ISFSls). One piece of the DFP is a detailed ISFSI decommissioning estimate. The detailed cost estimate is periodically revised based on the schedule for refreshing the full decommissioning cost estimate for the site.

In accordance with 10 CFR 72 .30(c), "At the time of license renewal and at intervals not to exceed 3 years, the decommissioning funding plan must be resubmitted with adjustments as necessary to account for changes in costs and the extent of contamination." To update it's DFPs, EGC either makes a full update to the DFP, updates the detailed ISFSI decommissioning cost estimate and affirms that the remainder of the DFP has not changed, or escalates the ISFSI decommissioning cost estimate and affirms that the remainder of the DFP has not changed.

Along with each DFP update for each ISFSI, information on the occurrence, and the effect on decommissioning costs , of each of the events listed in 10 CFR 72.30(c)(1 )-(4 ):

(1) spills of radioactive material producing additional residual radioactivity in onsite subsurface material, (2) facility modifications, (3) changes in authorized possession limits, and (4) actual remediation costs that exceed the previous cost estimate must be included.

The table below specifies the current detailed DFP and current detailed decommissioning cost estimate for each Exelon Generation Company, LLC (EGC) ISFSI. The current detailed DFP is unchanged as of December 31 , 2020 for all EGC ISFSls. For Calvert Cliffs, Clinton , Fitzpatrick, Quad Cities, and Salem ISFSls, the current detailed ISFSI decommissioning cost estimate is unchanged as of December 31 , 2020. The ISFSI decommissioning cost escalated to December 31, 2020 dollars is contained in the attachment to this letter indicated in the table below. For Braidwood, Byron , Dresden, LaSalle, Limerick, Nine Mile Point, Peach Bottom , and Ginna ISFSls, a new detailed ISFSI decommissioning cost estimate is provided in Attachment 29 of this letter.

Page 1 of 5

ATTACHMENT 30 (Continued)

.,dependent Spent Fuel Storage .,stallation Decommissioning Funding Plan Updates Current Detailed Current Detailed Current Dollar Cost ISFSI Facility DFP Cost Estimate Estimate Braidwood Station Reference 1 Attachment 29 Attachment 29 Byron Station Reference 1 Attachment 29 Attachment 29 Calvert Cliffs Nuclear Reference 2 Reference 7 Attachments 6/7 Power Plant Clinton Power Station References 3 and 4 Reference 7 Attachment 8 Dresden Nuclear Reference 1 Attachment 29 Attachment 29 Power Station James A. Fitzpatrick Reference 5 Reference 7 Attachment 12 Nuclear Power Station LaSalle County Station Reference 1 Attachment 29 Attachment 29 Limerick Generating Reference 1 Attachment 29 Attachment 29 Station Nine Mile Point Reference 2 Attachment 29 Attachment 29 Nuclear Station Peach Bottom Atomic Reference 1 Attachment 29 Attachment 29 Power Station Quad Cities Nuclear Reference 1 Reference 7 Attachments 23/24 Power Station R.E. Ginna Nuclear Reference 2 Attachment 29 Attachment 29 Power Plant Salem Generating Reference 1 Reference 7 Attachments 26/27 Station The effect of each of the events listed in 10 CFR 72.30(c)(1) through (4) on the detailed cost estimates provided in Reference 7 for the ISFSls at Calvert Cliffs, Clinton , Fitzpatrick, Quad Cities, and Salem is listed below. For these ISFSls, the most recent DFP update prior to the one contained herein is contained in Reference 7. Reference 7 provides the effect of the events listed in 10 CFR 72.30(c)(1) through (4) as of December 31 , 2018.

Consequently, the effect of the events from December 31, 2018 through December 31 ,

2020 is provided below.

Page 2 of 5

ATTACHMENT 30 (Continued)

.,dependent Spent Fuel Storage .,stallation Decommissioning Funding Plan Updates (1) Spills of radioactive material producing additional residua l radioactivity in onsite subsurface material :

No impact. There have not been any spills of radioactive material producing additional residual radioactivity in onsite subsurface material in 2019 or 2020 at any of the ISFSls at the facilities listed above.

(2) Facility modifications:

No impact. There have not been any modifications to the ISFSls at the facilities listed above in 2019 or 2020 that would materially change the latest decommissioning cost estimate.

The ISFSI facility design at the time the cost estimate was prepared was incorporated in the estimate for the facilities listed above. Also, any ISFSI modifications (i.e. , ISFSI pad expansions) required to accommodate spent fuel storage after permanent shutdown were incorporated in the cost estimate.

(3) Changes in authorized possession limits:

No impact. There have not been any changes in authorized possession limits at the ISFSls at the facilities listed above during 2019 or 2020 that would materially change the decommissioning cost estimate.

The capacity of the cask used at the ISFSI at the time the cost estimate was performed was incorporated in the estimate for the facilities listed above. Additionally, in anticipation of a change in cask size at Calvert Cliffs, a larger cask size was incorporated in the cost estimate for this ISFSI.

(4) Actual remediation costs that exceed the previous cost estimate:

No impact. As of December 31 , 2020, decommissioning had not begun at any of the ISFSls listed above. Consequently, there have been no actual remediation costs that exceed the latest cost estimate.

In Attachment 29 of this letter, decommissioning cost estimates are provided for the ISFSls at Braidwood, Byron, Dresden, LaSalle, Limerick, Nine Mile Point, Peach Bottom, and Ginna. The detailed cost estimates for Braidwood , Byron, Dresden , LaSalle, Nine Mile Point, and Ginna ISFSls were prepared in 2019. The detailed cost estimates for Limerick and Peach Bottom ISFSls were prepared in 2020. Each of the items listed in 10 CFR 72.30(c)(1) through (4) was considered in preparation of the updated cost estimate. Additionally, the effect of the items in 10 CFR72.30(c) from cost estimate completion to December 31, 2020 were reviewed. A discussion of each item is included below.

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ATTACHMENT 30 (Continued)

.,dependent Spent Fuel Storage .,stallation Decommissioning Funding Plan Updates (1) Spills of radioactive material producing additional residua l radioactivity in onsite subsurface material :

No impact. There were no spills of radioactive material producing additional residual radioactivity in onsite subsurface material at any of the ISFSls at the facilities listed above through December 31, 2020.

(2) Facility modifications:

No impact. There have not been any modifications to the ISFSls at the facil ities listed above during 2020 that would materially change the latest decommissioning cost estimate.

The ISFSI facility design at the time the updated cost estimate was prepared was incorporated in the estimate for the facilities listed above. Also, any ISFSI modifications (i.e. , ISFSI pad expansions) required to accommodate spent fuel storage after permanent shutdown were incorporated in the updated cost estimate .

(3) Changes in authorized possession limits:

No impact. There have not been any changes in authorized possession limits at the ISFSls at the facilities listed above during 2020 that would materially change the latest decommissioning cost estimate.

The capacity of the cask used at the ISFSI at the time the updated cost estimate was performed was incorporated in the estimate for the facilities listed above. In anticipation of a change in cask size at Nine Mile Point and Limerick, a larger cask size was incorporated in the updated estimate for these ISFSls. A larger cask was used for the first time in 2020 at Peach Bottom , the larger cask size was incorporated in the updated cost estimate. The cask size did not change in the updated estimate relative to the previous estimate for the other ISFSls.

(4) Actual remediation costs that exceed the previous cost estimate:

No impact. As of December 31 , 2020, decommissioning had not begun at any of the ISFSls listed above. Consequently, there have been no actual remediation costs that exceed the costs included in the latest cost estimate.

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ATTACHMENT 30 (Continued)

.,dependent Spent Fuel Storage .,stallation Decommissioning Funding Plan Updates References

1. Letter from Patrick R. Simpson (EGC) to U.S. Nuclear Regulatory Commission, "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 Stephen A Mormann (Constellation Energy Nuclear Group, LLC) to U.S. Nuclear Regulatory Commission , "ISFSI Decommissioning Funding Plans,"

dated December 17, 2012

3. Letter from David M. Gullett (EGC) to U.S. Nuclear Regulatory Commission, "Proposed Independent Spent Fuel Storage Installation (ISFSI) Decommissioning Funding Plans for Clinton Power Station," dated September 6, 2016

4. Letter from Patrick R. Simpson (EGC) to U.S. Nuclear Regulatory Commission ,

"Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installations," dated March 30, 2017

5. Letter from Patrick R. Simpson (EGC) to U.S. Nuclear Regulatory Commission, "Report on the Status of Decommissioning Funding for James A Fitzpatrick Nuclear Power Plant Independent Spent Fuel Storage Installation," dated December 10, 2018

6. Letter from Patrick R. Simpson (EGC) to U.S. Nuclear Regulatory Commission, "Response to Request for Additional Information Regarding Decommissioning Funding Plans for Independent Spent Fuel Storage Installations (ISFSls)," dated May 2, 2018

7. Letter from Patrick R. Simpson (EGC) to U.S. Nuclear Regulatory Commission, "Report on Status of Decommissioning Funding for Reactors and Independent Spent Fuel Storage Installation," dated April 1, 2019 Page 5 of 5