L-2011-058, Units 1 & 2 - Status Reports Decommissioning Funding Status Report for the Listed Units
| ML110840036 | |
| Person / Time | |
|---|---|
| Site: | Saint Lucie, Point Beach, Seabrook, Turkey Point, Duane Arnold  |
| Issue date: | 03/23/2011 |
| From: | Larry Nicholson Florida Power & Light Co, NextEra Energy Duane Arnold, Point Beach, NextEra Energy Seabrook |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| L-2011-058 | |
| Download: ML110840036 (43) | |
Text
0 Florida Power & Light Company, 700 Universe Boulevard, Juno Beach, FL 33408 F=PL.
MAR 2 3 2011 L-2011-058 U.S. Nuclear Regulatory Commission 10 CFR 50.75(f)(1)
Attn: Document Control Desk Washington, DC 20555-0001 RE:
Florida Power and Light Company St. Lucie Units 1 and 2 Docket Nos. 50-335 and 50-389 Turkey Point Units 3 and 4 Docket Nos. 50-250 and 50-251 NextEra Energy Seabrook, LLC Seabrook Station Docket No. 50-443 NextEra Energy Duane Arnold, LLC Duane Arnold Energy Center Docket No. 50-331 NextEra Energy Point Beach, LLC Point Beach Units 1 and 2 Docket Nos. 50-266, 50-301 Decommissioning Funding Status Reports Pursuant to 10 CFR 50.75(f)(1), enclosed are the Decommissioning Funding Status Reports for the following units:
- 1. St. Lucie Units 1 and 2
- 2.
Turkey Point Units 3 and 4
- 3. Seabrook Station
- 4.
Duane Arnold Energy Center
- 5.
Point Beach Units 1 and 2 Florida Power and Light Company (FPL) is the sole owner of Turkey Point Units 3 and 4 and St. Lucie Unit 1. FPL, Florida Municipal Power Agency, and Orlando Utilities Commission own St. Lucie Unit 2. The report for St. Lucie Unit 2 provides the status of decommissioning funding for all three owners of that unit.
NextEra Energy Seabrook, LLC (Seabrook), Hudson Light and Power Department, Massachusetts Municipal Wholesale Electric Company, and Taunton Municipal Lighting Plant own Seabrook Station. The report for Seabrook Station provides the status of decommissioning funding for all four owners of that unit.
NextEra Energy Duane Arnold, LLC (Duane Arnold), Central Iowa Power Cooperative, and Corn Belt Power Cooperative own Duane Arnold Energy Center. The report for Duane Arnold Energy Center provides the status of decommissioning funding for all three owners of that unit.
NextEra Energy Point Beach, LLC is the sole owner of Point Beach Units 1 and 2.
an FPL Group company
L-2011-058 In light of NRC letter, St. Lucie Plant, Unit Nos. 1 and 2 - Biennial Decommissioning Funding Report, dated November 26, 2008, (TAC Nos. MD9354 and MD9355), FPL and Seabrook will be reporting all funds within the external trust to the NRC as designated for radiological decommissioning purposes since FPL and Seabrook do not earmark each cost component of decommissioning within the trust. FPL and Seabrook provide a schedule that allocates each category of costs based on the most recent decommissioning cost study. Additionally, all units used NUREG 1307, Rev. 14, "Report on Waste Burial Charges," in determining decommissioning funding requirements.
This letter contains no new commitments and no revisions to existing commitments.
Should there be any questions, please contact Pamela Metz at (561) 691-2654.
Larry E. Nicholson Director of Licensing Enclosures (5)
L-2011-058 St. Lucie Nuclear Plant - Unit 1 Florida Power and Light Company (FPL),
Decommissioning Funding Status Report
- 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
Plant Owner (% Ownership)
NRC Minimum (a)
FPL (100%)
439,235,100 (a) Refer to Attachment I for calculation assumptions
- 2.
The amount accumulated at the end of the calendar year preceding the date of the reoort.
I I
Total' FPL 100%
696,049,692 Schedule of the projected amounts remaining to be collected.
FPL (100%) (see note (b))
I None 3.
(b) Pursuant to Florida Public Service Commission (FPSC) Order No. PSC-05-0902-S-El, customer contributions to the decommissioning trust were suspended effective September 1, 2005.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
FPL (100%)
3.9%
2.84%
1.06%
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
- 7.
Any material changes to trust agreements.
None None None 1 NRC letter dated November 26, 2008, St. Lucie Plant, Unit Nos. 1 and 2 - Biennial Decommissioning Funding Report (TAC Nos. MD9354 and MD9355), provides FPL should report all funds within the external trust to the NRC as designated for radiological decommissioning purposes since FPL does not earmark each cost component of decommissioning within the trust. Attachment 2 segregates the trust account amounts by license termination, spent fuel management and site restoration costs based on assumptions from the decommissioning cost study filed in December 2010 with the Florida Public Service Commission.
L-2011-058 ATTACHMENT I ST. LUCIE NUCLEAR PLANT - UNIT 1 NRC Minimum Decommissioning Cost Determination NRC Minimum = $98.76 million X (0.65L + 0.13E + 0.22B)
Where:
$98.76 million is value for reference PWR2 in 1986 dollars L = Labor escalation factor to current year3 E = Energy escalation factor to current year' B = LLRW escalation factor to current year5 Item Description Value 1
Labor escalation factor for Quarter 4, 20102 112.8 2
Base adjustment factor from NUREG-1 307 1 1.98 3
Escalation factor from NUREG-1 307 100 4
L = #1 times #2 divided by #3 2.23 5
Electric power escalation factor, 201 06 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1 307 114.2 7
Fuel escalation factor for 20107 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1 307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#1 0) per NUREG-1 307 2.26 12 Value of B from Table 2.1 of NUREG-1307 5 12.28 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.45 14 1986 minimum-millions of dollars for PWR 98.76 15 2010 minimum-millions of dollars: #13 times #14 439.2 2 NUREG 1307, Rev 14, Table 3.2 3 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002201 (South Region).
4 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
5 NUREG 1307 provides a value for B in Table 2.1.
In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
6 December 2010 value is 191.3. (See note #4) Information was preliminary as of 01/18/11.
7 December 2010 value is 252.1 (See note #4) Information was preliminary as of 01/18/11.
L-2011-058 ATTACHMENT 2 ST. LUCIE NUCLEAR PLANT - UNIT 1 Florida Power and Light Company Decommissioning Trust Fund - License Termination Funds As of December 31, 2010 TLG December 2010 Cost Study (millions)
License Termination Spent Fuel Management Site Restoration Total Category %
License Termination Spent Fuel Management Site Restoration Total Total Decommissioning Trust Fund Balance as of 12/31110 10 CFR 50.2 Decommissioning Trust Fund Allocation based on TLG Study 10 CFR 50.75(c) NRC Minimum Amount as of 12/31/10 St. Lucie Unit I 534,825 188,629 43,670 767,124 69.72%
24.59%
5.69%
100%
696,049,692 485,273,276 439,235,100
L-2011-058 St. Lucie Nuclear Plant - Unit 2 Florida Power and Light Company (FPL),
Florida Municipal Power Agency (FMPA),
Orlando Utilities Commission (OUC)
Decommissioning Funding Status Report
- 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
Plant Owner (% Ownership)
NRC Minimum (a)8 FPL (85.10449%)
374,250,706 FMPA (8.806%)
38,417,786 OUC (6.08951%)
26,566,608 Total 439,235,100 (a) Refer to Attachment I for calculation assumptions
- 2.
The amount accumulated at the end of the calendar year preceding the date of the report.
Total9 FPL (85.10449%)
577,370,861 FMPA (8.806%)
51,962,354 OUC (6.08951%)
36,378,222 Total 665,711,437 Schedule of the projected amounts remaining to be collected.
FPL (85.10449%) (see note (b))
None FMPA (8.806%)
None OUC (6.08951%)
None 3.
(b) Pursuant to Order No. PSC-05-0902-S-El, customer contributions to the decommissioning trust were suspended effective September 1, 2005.
8 An adjustment was necessary to allocate the decommissioning costs of Unit 2 among the participants. This is because the decommissioning costs of Unit 2 include the costs of decommissioning facilities common to both St. Lucie Units 1 and 2. FMPA's and OUC's contractual obligations provide that with respect to common facility costs, they pay only their ownership share of Unit 2 times one half of these costs. Therefore, multiplying FMPA's and OUC's respective ownership shares of Unit 2 by the total cost of decommissioning would overstate their cost obligations. This adjustment is reflected in the "St. Lucie Unit 2 - FPL Ownership Percentage" presented on page 39.of FPL's 1994 Decommissioning Study for St. Lucie Units 1 and 2 (Florida Public Service Commission (FPSC) Docket No. 941350-EI). The adjusted percentages are as follows: FPL: 85.2051%, FMPA: 8.74682%, and OUC: 6.04838%.
9 NRC letter dated November 26, 2008, St. Lucie Plant,. Unit Nos. 1 and 2 - Biennial Decommissioning Funding Report (TAC Nos. MD9354 and MD9355), provides FPL should report all funds within the external trust to the NRC as designated for radiological decommissioning purposes since FPL does not earmark each cost component of decommissioning within the trust. Attachment 2 segregates the trust account amounts by license termination, spent fuel management and site restoration costs based on assumptions from the decommissioning cost study filed in December 2010 with the Florida Public Service Commission.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
(Weighted Avg)
FPL (85.10449%)
3.9%
2.97%
FMPA (8.806%)
5.9%
2.97%
OUC (6.08951%)
4.8%
2.97%
1_
1 1.16%
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
- 7.
Any material changes to trust agreements.
None None None
L-2011-058 ATTACHMENT 1 ST. LUCIE NUCLEAR PLANT - UNIT 2 NRC Minimum Decommissioning Cost Determination NRC Minimum = $98.76 million X (0.65L + 0.13E + 0.22B)
Where:
$98.76 million is value for reference PWR 10 in 1986 dollars L = Labor escalation factor to current year 11 E = Energy escalation factor to current year12 B = LLRW escalation factor to current year13 Item Description Value 1
Labor escalation factor for Quarter 4, 2010 11 112.8 2
Base adjustment factor from NUREG-1307 10 1.98 3
Escalation factor from NUREG-1307 100 4
L = #1 times #2 divided by #3 2.23 5
Electric power escalation factor, 201014 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 2010 15 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#10) per NUREG-1307 2.26 12 Value of B from Table 2.1 of NUREG-1307 13 12.28 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.45 14 1986 minimum-millions of dollars for PWR 98.76 15 2010 minimum-millions of dollars: #13 times #14 439.2 10 NUREG 1307, Rev 14, Table 3.2 11 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002201 (South Region).
12 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities,
. Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
13 NUREG 1307 provides a value for B in Table 2.1. Inthe October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
14 December 2010 value is 191.3. (See note #12) Information was preliminary as of 01/18/11.
15 December 2010 value is 252.1 (See note #12) Information was preliminary as of 01/08/11.
L-2011-058 ATTACHMENT 2 ST. LUCIE NUCLEAR PLANT - UNIT 2 Florida Power and Light Company Decommissioning Trust Fund - License Termination Funds As of December 31, 2010 TtLG Cost Study thouands of $2010t Loense Termination Spent Fuel Management Site Restoration Total Cateanory License Termination Spent Fuel Management Site Restoration Total I I Total St. Lucie
. Lucie Unit 21 FPL I
FMPA OUC Unit 2 517,410 142,476 51,744 71163_0 72.71%
20.02%
7.27%
100%
Total Decommissioning Trust Fund Balance as of 12/31110 10 CFR 50.2 Decommissioning Trust Fund Allocation based on TLG Study 10 CFR 50.75(c) NRC Minimum Amount as of 12131110 577,370,861 51,962,354 36,378,222 665,711,437 419,793,231 37,780,646 26,449,778 484,023,656 374,250,706 38,417,786 26,566,608 439,235,100
L-2011-058 1.
Turkey Point Nuclear Plant - Unit 3 Florida Power and Light Company (FPL),
Decommissioning Funding Status Report The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
Plant Owner (% Ownership)
NRC Minimum (a)
FPL (100%)
423,579,900 (a) Refer to Attachment I for calculation assumptions
- 2.
The amount accumulated at the end of the calendar year preceding the date of the report.
II Total16 FPL (100%)
583,819,707
- 3.
Schedule of the projected amounts remaining to be collected.
FPL (100%) (see note (b))
I None (b) Pursuant to FPSC Order No. PSC-05-0902-S-EI, customer contributions to the decommissioning trust were suspended effective September 1, 2005.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
FPL (100%)
3.9%
2.95%
0.95%
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
- 7.
Any material changes to trust agreements.
None None None 1r NRC letter dated November 26, 2008, St. Lucie Plant, Unit Nos. 1 and 2 - Biennial Decommissioning Funding Report (TAC Nos. MD9354 and MD9355), provides FPL should report all funds within the external trust to the NRC as designated for radiological decommissioning purposes since FPL does not earmark each cost component of decommissioning within the trust. FPL is utilizing the same reporting assumptions for both Turkey Point and St. Lucie. Attachment 2 segregates the trust account amounts by license termination, spent fuel management and site restoration costs based on assumptions from the decommissioning cost study filed in December 2010 with the Florida Public Service Commission.
L-2011-058 ATTACHMENT 1 TURKEY POINT NUCLEAR PLANT - UNIT 3 NRC Minimum Decommissioning Cost Determination NRC Minimum = $95.24 million X (0.65L + 0.13E + 0.22B)
Where:
$95.24 million is value for reference PWR17 in 1986 dollars L = Labor escalation factor to current year 18 E = Energy escalation factor to current year19 B = LLRW escalation factor to current year2 ° Item Description Value 1
Labor escalation factor for Quarter 4, 2010 18 112.8 2
Base adjustment factor from NUREG-1 307 17 1.98 3
Escalation factor from NUREG-1307 100 4
L = #1 times #2 divided by #3 2.23 5
Electric power escalation factor, 2010 21 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 201022 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#10) per NUREG-1 307 2.26 12 Value of B from Table 2.1 of NUREG-1307 20 12.28 13 0.65L(#4) + 0.13E(#1 1) + 0.22B(#12) 4.45 14 1986 minimum-millions of dollars for PWR 95.24 15 2010 minimum-millions of dollars: #13 times #14 423.6 17 NUREG 1307, Rev 14, Table 3.2 18 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002201 (South Region).
19 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
20 NUREG 1307 provides a value for B in Table 2.1. In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
21 December 2010 value is 191.3. (See note #19) Information was preliminary as of 01/18/11.
22 December 2010 value is 252.1 (See note #19) Information was preliminary as of 01/18/11.
L-2011-058 ATTACHMENT 2 TURKEY POINT NUCLEAR PLANT - UNIT 3 Florida Power and Light Company Decommissioning Trust Fund - License Termination Funds As of December 31, 2010 TLG December 2010 Cost Study (millions)
License Termination Spent Fuel Management Site Restoration Total Cateaory %
License Termination Spent Fuel Management Site Restoration Total Total Decommissioning Trust Fund Balance as of 12/31/10 10 CFR 50.2 Decommissioning Trust Fund Allocation based on TLG Study 10 CFR 50.75(c) NRC Minimum Amount as of 12/31/10 Turkey Point Unit 3 449,543 169,113 35,047 653,703 68.77%
25.87%
5.36%
100%
583,819,707 401,485,174 423,579,900
L-2011-058 Turkey Point Nuclear Plant - Unit 4 Florida Power and Light Company (FPL),
Decommissioning Funding Status Report
- 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
Plant Owner (% Ownership)
NRC Minimum (a)
FPL (100%)
423,579,900 (a) Refer to Attachment I for calculation assumptions
- 2.
The amount accumulated at the end of the calendar year preceding the date of the report.
II Total2 FPL (100%)
657,399,673 Schedule of the projected amounts remaining to be collected.
FPL (100%) (see note (b))
I None 3.
(b) Pursuant to FPSC Order No. PSC-05-0902-S-EI, customer contributions to the decommissioning trust were suspended effective September 1, 2005.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
FPL (100%)
3.9%
2.95%
0.95%
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
- 7.
Any material changes to trust agreements.
None None None 23 NRC letter dated November 26, 2008, St. Lucie Plant, Unit Nos. 1 and 2 - Biennial Decommissioning Funding Report (TAC Nos. MD9354 and MD9355), provides FPL should report all funds within the external trust to the NRC as designated for radiological decommissioning purposes since FPL does not earmark each cost component of decommissioning within the trust. FPL is utilizing the same reporting assumptions for both Turkey Point and St. Lucie. Attachment 2 segregates the trust account amounts by license termination, spent fuel management and site restoration costs based on assumptions from the decommissioning cost study filed in December 2010 with the Florida Public Service Commission.
L-2011-058 ATTACHMENT 1 TURKEY POINT NUCLEAR PLANT - UNIT 4 NRC Minimum Decommissioning Cost Determination NRC Minimum = $95.24 million X (0.65L + 0.13E + 0.22B)
Where:
$95.24 million is value for reference PWR24 in 1986 dollars L = Labor escalation factor to current year2 5 E = Energy escalation factor to current year26 B = LLRW escalation factor to current year 27 Item Description Value 1
Labor escalation factor for Quarter 4, 2010 25 112.8 2
Base adjustment factor from NUREG-1307 24 1.98 3
Escalation factor from NUREG-1 307 100 4
L = #1 times #2 divided by #3 2.23 5
Electric power escalation factor, 2010 28 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 201029 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1307 82 9
P = #5 divided by #6 1.68 10-F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#10) per NUREG-1307 2.26 12 Value of B from Table 2.1 of NUREG-1307 27 12.28 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.45 14 1986 minimum-millions of dollars for PWR 95.24 15 2010 minimum-millions of dollars: #13 times #14 423.6 24 NUREG 1307, Rev 14,.Table 3.2 25 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002201 (South Region).
26 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
27 NUREG 1307 provides a value for B in Table 2.1. In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
28 December 2010 value is 191.3. (See note #26) Information was preliminary as of 01/18/11.
29 December 2010 value is 252.1 (See note #26) Information was preliminary as of 01/18/11.
L-2011-058 ATTACHMENT 2 TURKEY POINT NUCLEAR PLANT - UNIT 4 Florida Power and Light Company Decommissioning Trust Fund - License Termination Funds As of December 31, 2010 TLG December 2010 Cost Study (millions)
License Termination Spent Fuel Management Site Restoration Total Category %
License Termination Spent Fuel Management Site Restoration Total Total Decommissioning Trust Fund Balance as of 12131/10 10 CFR 50.2 Decommissioning Trust Fund Allocation based on TLG Study 10 CFR 50.75(c) NRC Minimum Amount as of 12131/10 Turkey Point Unit 4 483,444 204,893 44,176 732,513 66.00%
27.97%
6.03%
100%
657,399,673 433,870,699 423,579,900
L-2011-058 Seabrook Station NextEra Energy Seabrook, LLC, Hudson Light and Power Department, Massachusetts Municipal Wholesale Electric Company, Taunton Municipal Lighting Plant Decommissioning Funding Status Report3°
- 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
Plant Owner (% Ownership)
NRC Minimum (a)
NextEra Energy Seabrook, LLC.
(88.22889%)
425,283,984 Hudson Light and Power Department (.07737%)
372,942 Massachusetts Municipal Wholesale Electric Company (11.5934%)
55,882,912 Taunton Municipal Lighting Plant (.10034%)
483,662 Total 482,023,500 (a) Refer to Attachment I for calculation assumptions
- 2.
The amount accumulated at the end of the calendar year preceding the date of the report.
Total31 NextEra Energy Seabrook, LLC. (88.22889%)
366,725,239 Hudson Light and Power Department (.07737%)
366,858 Massachusetts Municipal Wholesale Electric Company (11.5934%)
35,589,403 Taunton Municipal Lighting Plant (.10034%)
478,741 Total 403,160,241 Schedule of the projected amounts remaining to be collected.
FAll owners (see note (b))
I 3.
(b) Attachment 2 provides the funding schedule to complete funding in 2030. This attachment provides the overall composite funding schedule and related information and provides the corresponding information applicable to each of the Seabrook Joint Owners.
30 The New Hampshire Nuclear Decommissioning Financing Committee (NDFC) was established under New Hampshire law (to provide assurance of adequate funding of nuclear generating facilities) "to ensure proper and safe decommissioning and subsequent surveillance of nuclear reactor sites to the extent necessary to prevent such sites from constituting a hazard to future generations." RSA 162-F:1. NDFC is responsible for determining the appropriate amount of money that needs to be set aside and maintained in a trust fund, and periodically updated, for the purpose of decommissioning any nuclear facilities located in the state of New Hampshire.
31 Attachment 2 was developed based on the Decommissioning Trust and funding assurance balances as of December 31, 2010, minus the estimated expenses applicable to both for purpose of developing a fund schedule for 2010 as ordered by the NDFC. Attachment 3 segregates the trust account amounts by license termination, spent fuel management and site restoration costs based on assumptions from the most recent decommissioning cost study available.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
(Projected)
All owners (see note (c))
(c) Attachment 2 details earnings by fund and owner, and general inflation determined by Prime Buchholz & Associates Inc. and approved by the New Hampshire Nuclear Decommissioning Financing Committee. Decommissioning costs are assumed to escalate at 4.2% per year and core inflation rates are assumed to escalate at 3.00% per year.
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
None
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
None
- 7.
Any material changes to trust agreements.
Effective April 16, 2009, the name was changed on the qualified and non-qualified trusts from FPL Energy Seabrook, LLC to NextEra Energy Seabrook, LLC to reflect a corporate name change. Also, the name of the trustee was changed from "Mellon Trust of Delaware, National Association" to "BNY Mellon Trust of Delaware", to reflect a name change that followed the merger of Mellon Trust of Delaware with the Bank of New York (Delaware). See Letter from P. Freeman, NextEra Energy Seabrook, LLC to NRC, "Seabrook Station: Proposed Amendment to Nuclear Decommissioning Trust Agreement," June 28, 2010.
See Response
L-2011-058 ATTACHMENT 1 SEABROOK STATION NRC Minimum Decommissioning Cost Determination NRC Minimum = $105 million X (0.65L + 0.13E + 0.22B)
Where:
$105 million is value for reference PWR32 in 1986 dollars L = Labor escalation factor to current year 33 E = Energy escalation factor to current year34 B = LLRW escalation factor to current year35 Item Description Value 1
Labor escalation factor for Quarter 4, 2010 33 113.6 2
Base adjustment factor from NUREG-1 307 32 2.16 3
Escalation factor from NUREG-1 307 100 4
L = #1 times #2 divided by #3 2.45 5
Electric power escalation factor, 2010 36 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 2010 37 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#10) per NUREG-1307 2.26 12 Value of B from Table 2.1 of NUREG-1307 35 12.28 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.59 14 1986 minimum-millions of dollars for PWR 105 15 2010 minimum-millions of dollars: #13 times #14 482.0 32 NUREG 1307, Rev 13, Table 3.2 33 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, and Series CIU20100000002101 (Northeast Region).
34 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
35 NUREG 1307 provides a value for B in Table 2.1.
In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
36 December 2010 value is 191.3. (See note #34) Information was preliminary as of 01/18/11.
37 December 2010 value is 252.1 (See note #34) Information was preliminary as of 01/18/11.
L-2011-058 ATTACHMENT 2 SEABROOK STATION
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L-2011-058 SEABROOK STATION DECOMMISSIONING COST PROJECTIONS Summary Page for Totals of All Owners Year End Equities Bonds Cash Dacom Cash Casht+ Bonds 12/31 Total Total Total Expense Multiple Multiple 2030 429.275.492 429.275,492 858.550.984 131,771,353 2.8 4.2 2031 246,523.667 413.376.981 826.753.962 307,537,473 2.3 3.5 2032 297.649.703 297,649.703 595.299.406 354.323,127 2.7 4.1 2033 256.797,975 256.797,975 513,595,950 216.516.532 2.5 3.7 2034 181.756.496 227,056.128 454.112,256 209,375,171 2.3 3.5 2035 175.996.467 175.996.467 351,992,934 194.618.987 2.4 3.5 2039 146,324,421 146.324.421 292.649841 145,267.649 2.9 4.2 2037 126,955.033 126.955.033 253.910,067 1.3.443.362 3.1 4.7 2039 112,405,319 112,400.319 224,800.637
. 96,987.200 9.1 12.1 2039 110,784.045 1150784,045 221.568,09 27.903,563 15.1 22.7 2094 147.796,490 122.234,975 19022.23244 14.652852 11.9 19.9 2041 186,736.369 134.611,962 137.720.713 10,226,917 9.7 17.2 2042 228,126,358 148,066.037 94.048.599 15.866.447 5,7 14.6 2043 272.598.931 162.609,152 48.378,676 16.532.836 2.8 12.2 2044 320.849.995 179.059.252 17,274.005 0 0 10.0 2045 333.112.467 185.900,706 17,950.760 6.0 9.9 2048 345.792.329 192,971.519 19,704.692 0.0 9.9 2047 3589.03.296 200.293,438 19.490.299 0.0 9.9 2548 372.451,143 207.852.956 20,364.039 0.0 9.6 2949 386,510,025 215.696.797 21,161.854 0.0 9,9 2990 451,056,712 223,813.099 22,050,652 0.6 9.7 2901 416,110,206 232.209.029 22.976,780 0.0 917 2052 431,633,888 240,867,501 24.606.828 0,0 9,7 2053 447,726,553 249,842,241 24.947.360 0.0 9.6 2904 464,3609582 259,117.805 25.995,149 0.0 9.6 2055 481.548,512 268,701,070 27.086,946 0.0 9.5 2056 499,251.231 278,570,199 28.301.253 6.0 9.5 2057 517,579,599 298,786,699 29,410,030 0.0 9.4 2059 536,497,552 299.330.393 30.645,252 0.0 9.4 2059 556,016,098 310,207,270 31.932,352 0.0 9.3 2080 576.065.657 321,369,290 33,363,679 0.0 6.3 2081 596,630.728 332.946.511 34,670,999 0.0 9.2 2062 618205,863 344,852,476 36,127.181 0.0 9.2 2063 640.218.342 357,111,384 37,644,522 0.0 9.1 2064 662.803,507 369.687,101 39,332,125 0.0 9.0 2005 696,164.314 382,658.866 40,873,067 0.0 9 0 2068 710.0058,671 395.991.921 42,589,736 0.0 8.9 2057 734,688.976 409,687.347 44,378,505 0.0 6.8 2069 759.851.572 423,698.377 46.367,992 0.0 8.9 2069 785,766,968 438.113.930 49,184.583 0.0 8.7 2070 812.333.324 452,988.190 50,266,335 0.0 8.7 2971 839.544,151 469,017.211 522,317.085 9.6 8.6 2072 867,290,784 483.440.237 54.662,459 0.0 8.5 2073 895,751,804 491,256.6,25 56.804,008 0.0 8.4 2074 924,818,455 515.424,026 59.189.776 0.0 8.4 2075 954.471.096 531,872.545
" 61,675,747 0.0 7.0 2076 976,754,455 044,240,163 76.062.570 5.0 8.1 2077 1,006,875.548 560,958.927 66.965,305 0.0 7.4 2078 1,033,205,387 575,563,946 76.107.506 0.0 7.0 2679 1,057,226,625 588.879,791 82.582.027 0.0 6.8 2080 1,080,627,095 601,644.176 866.276.812 0.0 7.0 2081 1,105,954,916 615.872.670 86.105,452 0.0 6.9 2062 1.130,826.150 629.636,164 89,721.891 00 7.3 2063 1,166,300,219 645,955.961 895.714.869 0.0 5.7 2064 1,173,194.490 653.048,538 113,838,891 0.0 7.0 2065 1,201,006.611 668,424.257 93.066,119 0.0 5.6 2096 1,213.623,306 675.343,799 118,940.422 0.0 6.7 2087 1,239 203,390 689.458,863 101,047,842 0.0 5.3 2086 1,247,729,632 694.083.840 129,427,192 0.0 5.6 2089 1,260,1206061 700.846,621 124.612.820 6.6 5.6 2090 1,273,411,964 708.099.375 124.692.439 0.0 5.9 2091 "1,291.462,205 717.981.653 119.123.630 0.0 4.5 2092 1,027,739,627 571.237,513 399,744.285 158.209,445 2.5 6.1 2693 759,119.572 421.67.959 787,325,626 15.638.,41 4.6 7.3 2094 491.397,236 273,060,204 1,146,686,161 165.299,360 6.9 8.6 2095 235,626,381 130.929.806 1,466,224,749 165,872,511 7.9 56 2096 1.712,884,109 186.010,499 9.2 9.2 2097 1,572,986,335 187,014,113 8.1 8.1 2098 1,421,578,105 194,868,706 7.6 7.6 2899 91272,319.024 188,035.529 7.1 7.1 2100 1.126.164.384 180,331.467 1.0 1.0 2101 1.137,635.563 2102 Ownership 106.06%
Share of necommissioning Cost
.1273120606 0601,121,6000 Pre-Tax Tax Fund Return Rate 1A 6.00%
20.00%
1B 9.56%
26.00%
1C 3.50%
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2 6.00%
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5 9.50%
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'0% Earnings for 12/10 for Funds 18, 5 and 6 inflation Rates Core 3.00%
Decommissinning420 Scenario 8 - Contribution Formula Update 2030 Decommissioning, 2101 Liability Extansion Increased equity in tail period 4.20% Escalation Rate, 0.25% Escrow Net Earnings D0J Proceeds Excluded Funding Ends 2030 Decom Begins 2030 TLG Estimate based on TLG study approved bý tDFC (0851.1 milgon in 2006 dollars)
Target Cost = TLG Estimate YE 2010 Balance = 11130110 Sal + Cents + Earn - Exp Escalating annual contributions 5 Year phaseout prior to shutdown Final payment in 2101
-Run on 121302010 Equity Allocations as of 11/30110:
NentEra 66.4%
Hudson 30.2%
MWEC 48.6%
Taunton 30.2%
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L-2011-058 ATTACHMENT 3 SEABROOK STATION NextEra Energy Seabrook, LLC Decommissioning Trust Fund - License Termination Funds As of December 31, 2010 TLG Cost Study (thousands of $20061 License Termination Spent Fuel Management Site Restoration Total beabrook 508,677 135,648 31,450 675,775 75.27%
20.07%
4.65%
100%
Nextlra I Hudson I MMWE.
i Tauton I 1O tal Component %
License Termination Spent Fuel Management Site Restoration Total Total Decommissioning Trust Fund Balance as of 12/31/10 10 CFR 50.2 Decommissioning Trust Fund Allocation based on TLG Study )
10 CFR 50.75(c) NRC Minimum Amount as of 12/31110 (t) Refer to Schedule 2 for summary of funding requirements 366,725,239 366,858 35,589,403 478,741 403,160,241 276,045,569 276,146 26,789,258 360,363 303,471,336 425,283,984 372,942 55,882,912 483,662 482,023,500
L-2011-058 Duane Arnold Energy Center NextEra Energy Duane Arnold, LLC (NextEra),
Central Iowa Power Cooperative (CIPCO),
Corn Belt Power Cooperative (Corn Belt)
Decommissioning Funding Status Report 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
Plant Owner (% Ownership)
NRC Minimum (a)
NextEra (70%)
387,320,164 CIPCO (20%)
110,662,904 Corn Belt (10%)
55,331,452 Total 553,314,520 (a) Refer to Attachment 1 for calculation assumptions.
- 2.
The amount accumulated at the end of the calendar year preceding the date of the report.
3.
Plant Owner (% Ownership)
Total NextEra (70%)
213,176,089 CIPCO (20%)
39,485,852 Corn Belt (10%)
19,391,909 Total 272,053,850 Schedule of the annual amounts remaining to be collected.
Plant Owner (% Ownership)
Annual Annuity Projected Funds at Shutdown NextEra (70%) (see notes (b))
$0 CIPCO (20%) (see note (b))
(c)
Corn Belt (10%)
(c)
Total (b) Refer to Attachment 2 for Decommissioning Funding Plan, SAFTSTOR Alternative.
(c) Actual annual contributions to the external sinking fund will vary based upon reassessment of owner's decommissioning funding obligations in light of NRC requirements, actual inflation, actual fund earnings, and other factors. Attachment 3 provides the funding schedules applicable to each of the Duane Arnold Energy Center Owners.
L-2011-058 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Plant Owner (% Ownership)
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
(Projected)
NextEra (see note (d)) (70%)
2%
CIPCO (see note (e)) (20%)
4%
Corn Belt (see note (f)) (10%)
3%
Basis for Allowance:
(d) The real rate of return allowed by 10 CFR 50.75 is 2%.
(e) Central Iowa Power Cooperative (CIPCO) is a public corporation incorporated under Chapter 499 Iowa Code (2009). CIPCO has the authority and is required to fix, establish, and collect adequate rates and other charges for electrical energy or services sold or furnished by it. CIPCO is accordingly authorized to establish its own rates and other charges through which it can recover its cost of service.
CIPCO is governed by a 13 member Board of Directors that are elected by the CIPCO members. The Board of Directors is the rate making authority for CIPCO.
CIPCO rates are not regulated by any state or federal authority. In a Board Resolution dated October 27, 2009, the CIPCO Board of Directors resolved that the rates and other charges for electrical energy services and the decommissioning fund be established assuming a real rate of return on the decommissioning fund of four percent.
(f) Corn Belt Power Cooperative is a public corporation incorporated under Chapter 499 Iowa Code (2009). CIPCO has the authority and is required to fix, establish, and collect adequate rates and other charges for electrical energy or services sold or furnished by it. Corn Belt is governed by an 11 member Board of Directors who are elected by its members. The Corn Belt Board of Directors is accordingly authorized to establish its own rates and other charges through which it can recover its cost of service and is the rate making authority for the Cooperative.
The Cooperative's rates are not regulated by any state or federal authority. In a Board Resolution dated October 30, 2009, the Corn Belt Board of Directors resolved that the rates and other charges for electrical energy services and the decommissioning fund be established assuming a real rate of return on the decommissioning fund of three percent.
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
None
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
See response
L-2011-058 On April 7, 2010 NextEra Energy Duane Arnold, LLC. (NextEra) notified the NRC of its intent to terminate the existing $93 million Parent Guaranty 120 days after the NRC's receipt of the notice (ADAMS Accession No. ML101040713). Subsequently, the Parent Guaranty was terminated in August 2010. On August 22, 2010 the NRC sent NextEra acknowledgement of the termination (ADAMS Accession No. ML101620393) indicating no objection to the termination of the Parent Guaranty.
- 7.
Any material changes to trust agreements.
None
L-2011-058 ATTACHMENT I DUANE ARNOLD ENERGY CENTER NRC Minimum Decommissioning Cost Determination NRC Minimum = $121.2 million X (0.65L + 0.13E + 0.22B)
Where:
$121.2 million is value for reference BWR38 in 1986 dollars L = Labor escalation factor to current year 39 E = Energy escalation factor to current year40 B = LLRW escalation factor to current year41 Item Description Value 1
Labor escalation factor for Quarter 4, 2010 39 111.3 2
Base adjustment factor from NUREG-1 307 38 2.08 3
Escalation factor from NUREG-1307 100 4
L = #1 times #2 divided by #3 2.32 5
Electric power escalation factor, 2010 42 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 2010 43 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.54P(#9) + 0.46F(#10) per NUREG-1307 2.32 12 Value of B from Table 2.1 of NUREG-1307 41 12.54 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.57 14 1986 minimum-millions of dollars for BWR 121.2 15 2010 minimum-millions of dollars: #13 times #14 553.3 38 NUREG 1307, Rev 14, Table 3.2 39 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002301 (Midwest Region).
40 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
41 NUREG 1307 provides a value for B in Table 2.1. In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.54 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
42 December 2010 value is 191.3. (See note #40) Information was preliminary as of 01/18/11.
43 December 2010 value 252.1 (See note #40) Information was preliminary as of 01/18/11.
L-2011-058 Duane Arnold Energy Center Decommissioning Funding Plan 2034 Shutdown, SAFBTOR Altemadve (Thousands of Dollars)
Basis Year 2010 Fund Balance as of 12131110: (Thousands of Dollars)
Next Era 213,176 70% uwnership CIPCO 309,486 20% ownership Corn Belo 19,392 10% ownership Total Trust Fund Balance 272,054 2006 Enoaladon 2010 Eonalaun Annual EarnIngs - Next Era Annual Earnings - CIPCO Annual Earnings -Corn Belt 2.7%
1.%
2%
4%
3%
A 0
C D
E F
G H
Next Era Decommissioning Trust Fund Balanco escalated at 2%
minus 70% of CIPCO Decommissioning Trust Fund Balano.
escalated at 4%
minus 20% of expenses+
Contibutions Corn Bell Decommissioning Trust Fund Balanco esoalatod at 3%
minus 10% of expenses +
Contributors, 2009 2010
.5Cost IE scalaion I Etscalagon Total Decommlsioning Trust Fund minus Year (2008 Dollars) I at 2.7% 1 at 1.0% 1 expenses expenses CIPCO Decommissioning Trust Fund Conrfrbufgons 1,000 1,000 1,000 1.000 Corn Belt Decommissioning Trust Fund Condrbugons 700 ADO Calculaton,,
Column Eu (Column E (Praurous arsfund balanc)
(1.02)) - (Column D 0.70 (70% o, cu-nt years dcmmiooning expendinuret)
Column F = (Column F(Prooious yaurs fund boalnc)u (1.04)) -(Column D* 0 20)1(20% of cfrnt years doirmmseoning axpend~uros) + Column I (crent yonres contibutiors)
Column G = (Column G (Prious year's fund balance) (1.03)) -(Column D* 0.10) (10% of.u.nont yearsdocommimoning openditures) + Column J (current year's contobulons)
Column H = Column E + Column F + Column G
L-2011-058 ATTACHMENT 3 CIPCO and Corn Belt Decommissioning Trust Fund Contributions (In thousands of dollars)
Year CIPCO Decommissioning Corn Belt Decommissioning Trust Fund Contributions Trust Fund Contributions 2011 1,000 0
2012 1,000 550 2013 1,000 700 2014 1,000 850 2015 1,000 0
L-2011-058 Point Beach Nuclear Plant - Unit 1 NextEra Energy Point Beach, LLC (NextEra),
Decommissioning Funding Status Report
- 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
NRC Minimum (a)
NextEra (100%)
398,528,276 (a) Refer to Attachment I for calculation assumptions.
- 2. The amount accumulated at the end of the calendar year preceding the date of the report.
3.
I I
Total NextEra (100%)
260,164,914 Schedule of the projected amounts remaining to be collected.
Projected Funds at Shutdown NextEra (100%) (see notes (b) (c))
413,488,047 (b) Projection includes a pro-rata credit during the dismantlement period pursuant to 10CFR 50.75(e)(1)(ii).
(c) Assumes no annual contributions to the fund.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
(Projected)
NextEra (see note (d) 2%
Basis for Allowance:
(d) The real rate of return allowed by 10 CFR 50.75 is 2%.
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
- 7.
Any material changes to trust agreements.
Effective April 16, 2009, the name was changed on the qualified and non-qualified trusts from FPL Energy Point Beach, LLC to NextEra Energy Point Beach, LLC to reflect a corporate name change. Also, the name of the trustee was changed from "Mellon Trust of Delaware, National Association" to "BNY Mellon Trust of Delaware", to reflect a name change that followed the merger of Mellon Trust of Delaware with the Bank of New York (Delaware).
See response
L-2011-058 ATTACHMENT 1 POINT BEACH NUCLEAR PLANT - UNIT 1 NRC Minimum Decommissioning Cost Determination NRC Minimum = $88.55 million X (0.65L + 0.13E + 0.22B)
Where:
$88.55 million is value for reference PWR44 in 1986 dollars L = Labor escalation factor to current year45 E = Energy escalation factor to current year46 B = LLRW escalation factor to current year47 Item Description Value 1
Labor escalation factor for Quarter 4, 2010 45 111.3 2
Base adjustment factor from NUREG-1307 44 2.08 3
Escalation factor from NUREG-1307 100 4
L = #1 times #2 divided by #3 2.32 5
Electric power escalation factor, 2010 48 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 2010 49 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#10) per NUREG-1307 2.26 12 Value of B from Table 2.1 of NUREG-1307 47 12.28 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.50 14 1986 minimum-millions of dollars for PWR 88.55 15 2010 minimum-millions of dollars: #13 times #14 398.5 44 NUREG 1307, Rev 14, Table 3.2 45 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002301 (Midwest Region).
46 NUREG 1307 specifies that source is a weighted calculation Using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
47 NUREG 1307 provides a value for B in Table 2.1. In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
48 December 2010 value is 191.3. (See note #46) Information was preliminary as of 01/18/11.
49 December 2010 value is 252.1 (See note #46) Information was preliminary as of 01/18/11.
L-2011-058 Point Beach Nuclear Plant - Unit 2 NextEra Energy Point Beach, LLC (NextEra),
Decommissioning Funding Status Report
- 1.
The minimum decommissioning fund estimate pursuant to 10 CFR 50.75(b) and (c).
NRC Minimum (a)
NextEra (100%)
398,528,276 (a) Refer to Attachment I for calculation assumptions.
- 2.
The amount accumulated at the end of the calendar year preceding the date of the report.
3.
I Total NextEra (100%)
245,135,466 Schedule of the projected amounts remaining to be collected.
Projected Funds at Shutdown NextEra (100%) (see notes (b)(c))
408,653,331 (b) Projection includes a pro-rata credit during the dismantlement period pursuant to IOCFR 50.75(e)(1)(ii).
(c) Assumes no annual contributions to the fund.
- 4.
Assumptions used regarding escalation in decommissioning costs, rate of earnings on decommissioning funds and rates of other factors used in funding projections.
Rate of Earnings Escalation Real Rate of (Nominal Rate Of Factor Return Return)
(Inflation)
(Projected)
NextEra (see note (d))
2%
Basis for Allowance:
(d) The real rate of return allowed by 10 CFR 50.75 is 2%.
- 5.
Any contracts upon which the licensee is relying pursuant to 10 CFR 50.75(e)(1)(v).
- 6.
Any modifications to a licensee's method of providing financial assurance occurring since the last submitted report.
L-2011-058 ATTACHMENT 1 POINT BEACH NUCLEAR PLANT - UNIT 2 NRC Minimum Decommissioning Cost Determination NRC Minimum = $88.55 million X (0.65L + 0.13E + 0.22B)
Where:
$88.55 million is value for reference PWR50 in 1986 dollars L = Labor escalation factor to current year51 E = Energy escalation factor to current year52 B = LLRW escalation factor to current year 53 Item Description Value 1
Labor escalation factor for Quarter 4, 2010 51 111.3 2
Base adjustment factor from NUREG-1 307 50 2.08 3
Escalation factor from NUREG-1307 100 4
L = #1 times #2 divided by #3 2.32 5
Electric power escalation factor, 2010 54 191.3 6
Electric power escalation factor for Jan., 1986 from NUREG-1307 114.2 7
Fuel escalation factor for 2010 55 252.1 8
Fuel escalation factor for Jan., 1986 from NUREG-1 307 82 9
P = #5 divided by #6 1.68 10 F = #7 divided by #8 3.07 11 E = 0.58P(#9) + 0.42F(#10) per NUREG-1307 2.26 12 Value of B from Table 2.1 of NUREG-1307 53 12.28 13 0.65L(#4) + 0.13E(#11) + 0.22B(#12) 4.50 14 1986 minimum-millions of dollars for PWR 88.55 15 2010 minimum-millions of dollars: #13 times #14 398.5 50 NUREG 1307, Rev 14, Table 3.2 1 NUREG 1307 specified that source is Bureau of Labor Statistics Data, Employment Cost Index, Series CIU20100000002301 (Midwest Region).
52 NUREG 1307 specifies that source is a weighted calculation using Bureau of Labor Statistics Data, Producer Price Index-Commodities, Series wpu0573 (light fuel oils) and wpu0543 (industrial electric power).
53 NUREG 1307 provides a value for B in Table 2.1. In the October 2010 revision (Rev. 14) of the NUREG, the value is 12.28 for Generic LLW Disposal Site assuming 85% of the total LLW volume is dispositioned using waste vendors and the Clive, Utah facility and the remaining 15% is dispositioned by direct disposal at one of the two full-service disposal facilities.
54 December 2010 value is 191.3. (See note #52) Information was preliminary as of 01/18/11.
55 December 2010 value is 252.1 (See note #52) Information was preliminary as of 01/18/11.