RBG-47026, Response to Request for Additional Information Regarding Decommissioning Funding Assurance
| ML101520363 | |
| Person / Time | |
|---|---|
| Site: | River Bend  |
| Issue date: | 05/10/2010 |
| From: | Lorfing D Entergy Operations |
| To: | Document Control Desk, Office of Nuclear Reactor Regulation |
| References | |
| RBG-47026, TAC ME0562 | |
| Download: ML101520363 (17) | |
Text
- e yRiver Bend Station 5485 U.S. Highway 61N St. Francisville, LA 70775 Tel 225-381-4157 David N. Lorfing Manager, Licensing RBG-47026 May 10, 2010 U.S. Nuclear Regulatory Commission ATTN: Document Control Desk Washington, DC 20555-0001
SUBJECT:
Response to Request for Additional Information Regarding Decommissioning Funding Assurance River Bend Station, Unit 1 Docket No. 50-458 License No. NPF-47
References:
- 1. Entergy letter CNRO-2009-00005, "Status of Decommissioning Funding for Plants Operated by Entergy Operations, Inc. for the Year Ending December 31, 2008," dated March 30, 2009 (ML090920218).
- 2. NRC letter dated June 18, 2009 regarding Status of Decommissioning Funding Assurance for River Bend Station, Unit 1 (70% Regulated)
(ML091540293).
- 3. Entergy letter CNRO-2009-00010, "Decommissioning Funding Assurance Plans" dated August 13, 2009 (ML092260590).
- 4. NRC letter dated October 14, 2009, regarding Decommissioning Funding Assurance for River Bend Station, Unit 1 (70% Regulated) - Request for Additional Information (TAC No. ME0562) (ML092680611).
- 5. Entergy letter CNRO 2009-00013 "Response to Request for Additional Information Regarding Decommissioning Funding Assurance" dated November 12, 2009 (ML093200212)
- 6. NRC communication dated March 11, 2010 "Request for Additional Information by The Office of Nuclear Reactor Regulation, Decommissioning Financial Assurance Plan, 2009 Biennial Decommissioning Review, River Bend Station (70 % Regulated), Unit 1"
Dear Sir or Madam:
Entergy Operations, Inc. (Entergy) submitted the biennial report of decommissioning funding status in Reference 1. NRC requested follow up telephone conference calls in Reference 2 regarding the decommissioning funding status for the subject plants. Entergy provided further information for River Bend Station in Reference 3 and NRC Aoo(
RBG-47026 Page 2 of 4 requested additional information in Reference 4.' Entergy responded with further information for River Bend Station in Reference 5.
The Entergy response for River Bend Station to Reference 6 is provided in the attachment to this letter.
This letter contains no new commitments.
I If you have any questions, please contact Mr. Les England at 601-368-5766.
Sincerely, Manager, Licensing I
River Bend Station - Unit 1 DNL / LAE Attachments:
- 1. Response to Request for Additional Information, Decommissioning Financial Assurance Plans, 2009 Biennial Decommissioning Review, River Bend Station, Unit 1 (70 Percent Regulated) cc: next page
RBG-47026 Page 3 of 4' cc:
Regional Administrator U. S. Nuclear Regulatory Commission Region IV 612 E. Lamar Blvd., Suite 400 Arlington, TX 76011-4125 NRC Senior Resident Inspector P. 0. Box 1050 St. Francisville, LA 70775 U. S. Nuclear Regulatory Commission Attn: Mr. Alan B. Wang MS 0-8 B1 Washington, DC 20555-0001 Mr. Jeffrey P. Meyers Louisiana Department of Environmental Quality Office of Environmental Compliance Attn. OEC - ERSD P. 0. Box 4312 Baton Rouge, LA 70821-4312 Mr, L. Jager Smith, P.E.(ECH)
RBG-47026 Page 4 of 4
( Blank Page)
RBG-47026 Page 1 of 13 RESPONSE TO REQUEST FOR ADDITIONAL INFORMATION DECOMMISSIONING FINANCIAL'ASSURANCE PLANS 2009 BIENNIAL DECOMMISSIONING REVIEW RIVER BEND STATION, UNIT 1 (70 PERCENT REGULATED)
- 1. Provide the total amount anticipated to be provided by ETI over the duration of the EGSL-ET Power Purchase Agreement (Agreement), including a schedule of annual amounts. State the duration of the Agreement. State the basis for calculating the total amount and the schedule of annual amounts, such as whether the amounts presented are in current dollars, and the factors and rates used to project the amounts.
Response
In December 2009, ETI filed a rate case at the Public Utility Commission of Texas seeking, among other things, decommissioning payments to be made for River Bend (PUCT Docket No.
37744). The request was for a decommissioning revenue requirement of $2,836,000 per year from 2010 through 2024, and a decommissioning revenue requirement for 2025 of $1,891,000.
The following Table 1 (taken from the ETI filing, Exh. PBG-3, p.1) shows the requested decommissioning revenues (in the column denoted [1]), the balances in the non-tax qualified and tax qualified decommissioning trusts by year (in the columns denoted [2] and [3]), the total of the trust amounts (in the column denoted [4]), and annual decommissioning expenditures (in the column denoted [5]). The dollar values are expressed in dollars as of the year shown.
RBG-47026 Page 2 of 13 Table 1 Entergy Texas, Inc.
River Bend Decommissioning Model -
Texas Retail Revenue Requirement Fund Balance and Expenditure Summary
($000)
Decommissionina Fund Balances Line Revenue NonW No Year RgmL 111Quarifif 1
Beginning Balance Tax
- d [21 1.964 Tax Cluatifled [3]
91,557 Decomm.
Total 14]
Expend, [5]
93,521 2
2010 2,836 2,068 99,514 101,582 0
3 2011 2,836 2,180 108,251 110,431 0
4 2012 2,836 2,304 117,914 120,218 0
6 2013 2,836 2,437 128,2-9-7....-
130,734
-0 6
2014 2,836 2,580 139,581 142.161 0
7 2015 2,836 2,732 151,641 154,373 0
8 2016 2,836 2,894 164,521 167,415 0
9 2017 2,836 3,066 178,288 181,354 0
10 2018 2,836 3,249 193,007 196.256 0
11 2019 2,836 3,444 208.739 212,182 0
12 2020 2,836 3,651 225,567 229.218 0
13 2021 2,836 3,872 243,561 247,432 0
14 2022 2,836 4,096 262,442 266,538 0
15 2023 2,836 4,311 281,391 285,702 0
168 2024 2,836 4,513 299,770 304,283 0
17 2025 1,891 0
311,942 311,942 9,574 18 2026 0
0 289,333_'
289,333 37.841 19 2027 0
0 021,4f 223,441 80,032 20 2028 0
0 158,920 158,920
.75,443 21 2029 0
22 2030 0
23 2031 0
24 2032 0
25 2033 0
26 2034 0
0 0
0 0
0 0
114,596 65,894 30,450 12,828 1,169 0
114,596 52,089 65,894 54,304 30,450 38,664 12,828 19,106 1,169 12,282 0
1,222 The requested decommissioning revenue requirements were based on earnings rates and assumed management fees as shown in the following Tables 2 and 3 (taken from the ETI filing, Exh..PBG-3, pp.2-3).
RBG-47026 Page 3 of 13 Table 2 Entergy Texas, Inc.
River Bend Decommissioning Model -
Texas Retail Non-Tax Qualified Trust Detail (s0o0)
Non-Tax Qualified Trust Line Revenue Earning Transfer Mgmt.
Net Decomm.
No Year RqmL [1)
Rate [2] To Trust [31 Earnings [4]
Fee [5]
Additions [6] Expend. V7] Balance (8]
a at-'nnga-nce 1,964 2
2010 2,836 5.45%
0 108 4
104 0
2,068 3
2011 2,836 5.54%
0 116 4
112 0
2,180 4
2012 2,836 5.80%
0 128 4
124 0
2,304 5
2013 2,836 5.87%
0 137 4
133 0
2,437 6
2014 2,836 5.97%
0 148 5
143 0
2,580 7
2015 2,836 5.99%
0 157 5
152 0
2,732 8
2016 2,836 6.01%
0 167 5
162 0
2,894 9
2017 2,836 6.02%..
.0 177.
5 172 0
3,06 10 2018 2,836 6.04%
0 188 5
183 0
3,249 11 2019 2,836 6.06%
0 200 5
195 0
3,444 12 2020 2,836 6.08%
0 213 5
207 0'
3,651 13 2021 2,836 6.09%
0 226 5
221 0
3,872 14 2022 2,836 5.84%
0 230 5
224 0
4,096 i5 2023 2,836 5.31%
0 221 6
215 0
4,311 16 2024 2,836 4.78%
0 208 6
203 0
4,513 17 2025 1,891 4.64%
0 212 6
206 4,719 0
18 2026 0
4.51%
0 0
0 0
0 0
19 2027 0
4.51%
0 0........--
--- 6 0
20 2028 0
4.51%
0 0
0 0
0 0
21 2029 0
4.51%
0 0
0 0
0 0
22 2030 0
4.51%
0 0
0 0
0 0
23 2031 0
4.51%
0 0
0 0
0 0
24 2032 0
4.51%
0 0
0 0
0 0
25 2033 0
4.51%
0 0
0 0
0 0
26 2034 0
4.51%
0 0
0 0
0 0
RBG-47026 Page 4 of 13 Table 3 Entergy Texas, Inc.
River Bend Deoommlsslonlng Model -
Texas Retail Tax Qualified Trust Detail
($000)
Tax Qualified Trust Line Revenue Earning Trans To Earnings Mgmt.
Net Decomm.
Qualifying No Year Rqt [1] Rate2 Trust [3]
[41 Fee 5] Additions 16] Expend. [7]
Bal [81 Percent 1
feginningBalance 91,557 2
2010 2,836 5.50%
2.836 5,183 62 7,957 0
99,514 100%
3 2011 2,836 5.83%
2,836 5,967 66 8,737 0
108,251 100%
4 2012 2,836 6.20%
2,836 6,898 71 9,663
- 0.
117,914 100%
5 2013-2,836
-69% 2,836 7,624 77 10,383 0
128.297 100%
6 2014 2,836 6.47%
2,836 8,531 83 11.284 0
139,581 100%
.7 2015 2,836 6.50%
2,836 9%313-9-0 12,060 0
151,641 100%
8 2016 2,836 6.52%
2.836 10,140 97 12,880 0
164,521 100%
9 2017 2,836 6.54%
2,836 11,035 104 13,767 0
178,288, 100%
10 2018 2,836 6.57%
2,836 11,995 112 14,719 0
193,007 100%
11 2019 2,836 6.59%
2,836 13,016 121 15,732 0
208,739 100%
12 2020 2,836 6.61%
2,836 14,122 130 16,828 0
225,567 100%
13 2021 2,836 6.63%
2,836 15,297 139 17,994 0
243,561 100%
14 2022 2,836 6,51%
2,836 16,195 150 18,881 0
262,442 100%
15 2023 2,836 6.08%
2,836 16,274 160 18,949 0
281,391-1IOF 16 2024 2,836 5.48%
2,836 15,713 171 18,379 0
299,770 100%
17 2025 1,891 5.03%
1,891 15,316 179 17,027 4,855 311,942 100%.
18 2026 0
4.88%
0 15,408 176 15,232 37,841 289,333 100%
19 2027 0
4,88%
0 14,292 152 14,140 80,032 223,441 100%
20 2028 0
4.88%
0 11,037 115 10,922 75,443 158,920 100%
21 2029 0
4.88%
0 7,850 85
-,765 52,089 114,598 100%
22 2030 0
4.88%
0 5,61 59 5,602 54.,304 65,894 100%
23 2031 0
4.88%
0 3,255 35 3,220 38,664 30,450 100%
24 2032 0
4.88%
0 1,504 20 1,484 19,108 12,828 100%
25 2033 0
4.88%
0 634 11 623 12,282 1,169 100%
26 2034 0
4.88%
0 58 5
53 1,222 0
100%
The requested decommissioning revenue requirement amounts were based on the proposed earnings rates shown in Tables 2 and 3 and an assumption that the decommissioning trust fund balance would be zero at the end of decommissioning. The decommissioning costs were escalated at 4.25 percent, which figure was based onan analysis of historical costs in the categories of labor, waste burial, and energy costs.
The decommissioning expenditures represent the Texas-jurisdictional share of the decommissioning costs, as shown in Table 4 below (taken from the ETI filing, Exh. PBG-3, p.4).
RBG-47026 Page 5 of 13 Table 4 Entergy Texas, Inc.
Rivet Bend Decommissioning Model -
Texas Retail Decommissioning Expenditures (o000)
Uina Cum. Nuclear Decommissioning Expenditures No Year Cost Esc. [1]
Estimate [2]
Texas Retal [31 TX ReitailEsc. [4]
1 2008 1,0000 0
0 0
2 2009 1,0425 0,
0 0
3 2010 1,0868 0
0 0
4 2011 1.1330 0
0 0
5 2012 1.18120 0
0 6
2013 1.2314 0
0 1
0 7
2014 1.2837 0
0 0
8 2015 1.3383 0
0 0
9 2016 1.3952 0
0 0
10 2017 1.4545 0
0 0
11 2018 1.5163 0
0 12 2019 1,5807
- 0.
0 0
13 2020 1.6479 0
0 0
14 2021 1,7179 0
0 0
15 2022 1,7909 0
16 2023
-1.8670 0
0 0
17 2024 1.9463 0
0 0
i8 2025 2.0290 11,043 4.719 9,57.4 19 2026 2,1152 41.868 17,890 37,841 20 2027 2,2051 84,938 36,294 8,3 21 2028 2.2988 76.804 32,818 75,443 22 2029 2.3965" 50.867 21,735 52,089 23 2030 2.4984 50,867 21.735 54,304 24 2031 2,6046 34,740 14,844 38,664 25 2032 2,7153 16,467 7.038 19,106 26 2033 2,8307 10,154 4,339 12,282 27 2034 2.9510 969 414 1.222 Total 378.717 161,826 380,556 The proposed earnings rates for the funds as shown in Tables 2 and 3 were based on projections obtained from Global Insight, Inc., and adjusted for asset classes held in the trust, and for the applicable tax rates. As shown in Table 4 above, the NRC minimum value ($378.7 million) was distributed over the decommissioning period in present value dollars in proportion to the cash flows from the most recent River Bend site-specific decommissioning cost estimate. The Texas-retail fraction of those 1
decommissioning expenditures (42.73 percent, based on the Texas retail production demand allocator) is shown in Table 4 column denoted [3], and the column denoted [4] is the Texas retail share of decommissioning costs escalated at the 4.25 percent value compounded over the years until the expenditure.
The Public Utility Commission of Texas was asked to adopt the decommissioning revenue requirement as determined by the aforementioned factors.
As noted in Section 5 of the Agreement, the duration of the Agreement between ETI and Entergy Gulf States Louisiana, L.L.C. is the life of River Bend plus any time required to decommission the plant.
RBG-47026 Page 6 of 13
- 2. The Agreement does not appear to specify that the proceeds must be deposited into the external sinking fund. Identify the external sinking fund used to hold the proceeds for decommissioning funding. Describe how the licensee assures that all proceeds for decommissioning funding from the Agreement are deposited into the external sinking fund, including who receives the proceeds, how often 'proceeds are received, how often proceeds are deposited into the external sinking fund, and the time between receipt and deposit. Describe the degree of discretion, if any, in depositing the proceeds into the fund. State whether the procedure is in written form, and if so, submit a copy of the procedure.
Response
The external sinking fund used to hold the proceeds for decommissioning funding is the fund created by the Decommissioning Trust Agreement for River Bend Unit No. 1 ("Trust") between Entergy Gulf States Louisiana, L.L.C. and Mellon Bank, N.A. In 2007, Mellon Bank and The Bank of New York merged creating a new entity called The Bank of New York Mellon ("BNY Mellon"). BNY Mellon is the trustee of the fund and holds all of the proceeds of the fund.
Over the years, collections from customers have been regulated by three jurisdictional regulators - the Public Utility Commission of Texas ("PUCT"), the Louisiana Public Service Commission ("LPSC") and the Federal Energy Regulatory Commission ("FERC"). Each of the three regulators determines, through regulatory proceedings, the amount related to the decommissioning of River Bend that shall be collected annually from its respective customers.
The approved amounts are then incorporated into the monthly electric rates (one twelfth of the annual approved amount) charged those customers. The amounts collected each month are deposited into the decommissioning fund held by BNY Mellon on or about the first day of the following month. Entergy Treasury personnel wire monthly the exact monthly amounts approved by the PUCT, LPSC and FERC to the fund. There is no discretion related to depositing the proceeds into the fund. This overall process is not in written form.
- 3. The Agreement does not appear to define whether the proceeds must be applied solely to decommissioning as defined in 10 CFR 50.2, or whether the proceeds may be applied to other costs. Describe the allocation of the proceeds to decommissioning as defined in 10 CFR 50.2; to the spent fuel management program; and to any other costs that are covered by the total amount. Describe the amount of discretion that may be exercised in allocating the proceeds to the three purposes described and identify who has the authority to make those decisions. Describe the methods used to identify the amounts held in the fund for each of the purposes listed. State whether the allocation and identification methods are in written form, and' if so, submitcopies of the methods.
Response
The Agreement does not define whether the proceeds must be applied solely to decommissioning as defined in 10 CFR §50.2. There are no subaccounts or other segregation between various components of decommissioning costs within the River Bend trusts, but rather, RBG-47026 Page 7 of 13 all of the trust funds are held for the entire decommissioning project under the assumption that the funding will be adequate to accomplish the entire decommissioning project, including license termination, spent fuel management, and site restoration. If the funding is estimated to be inadequate to complete the entire decommissioning project, the licensees would look to the applicable rate regulators for additional funding to complete the decommissioning. If for any reason the rate regulators do not provide additional funding, the licensees would take measures to place the plant in a SAFSTOR condition pending resolution of funding issues, and non-radiological decommissioning activities would be curtailed (such as site restoration activities).
The first priority call on the fund assets would be for radiological decommissioning, followed by spent fuel management, followed by site restoration. To the extent that the licensees seek to use funds previously designated for radiological decommissioning as defined in 10 CFR §50.2, the licensee will seek an exemption under 10 CFR §50.12 to use those funds for other than radiological decommissioning.
Since there presently is no established division between decommissioning tasks within the trust funds, no allocation is presently made and therefore there is no one designated as having authority for making any allocation decisions. The methods described herein are not set out in written form.
- 4. The November 12, 2009 Plan for Decommissioning Funding Adjustment states that the Public Utilities Commission of Texas (PUCT) regulates approximately 45% of the licensee's share of decommissioning costs for the River Bend Station, and that ETI has the obligation for the Texas-jurisdictional share of the decommissioning obligation.
However, the Agreement states that ETI is responsible for a 42.5% share of the decommissioning costs. Provide a resolution of the difference in percentage responsibility for ETI as stated in the two documents provided in the November 12, 2009 submittal.
Response
The Texas-jurisdictional share for River Bend decommissioning shown in the November 12, 2009 Plan (Accession No. ML093200212) (45% of the 70% regulated share) was an approximate value. The controlling Agreement states that the value is 42.5% (of the 70%
regulated share). The remainder of the 70% regulated share of the plant is subject to the jurisdictiontof the Louisiana Public Service Commission and the Federal Energy Regulatory Commission.
- 5. The Agreement states that it is intended to cover a 42.5% share of the licensee's funds estimated to be needed for decommissioning. Calculate the amount of the 42.5% share based on the minimum amount required by § 50.75(c), as of December 31, 2009.
RBG-47026 Page 8 of 13
Response
Entergy calculates the 42.5% share of the minimum amount required by § 50.75(c) as $162.6 million as of December 31, 2009.
.6. Describe how the Agreement requires ETI to pay for the decommissioning obligations specified in the contract notwithstanding the operational status either of the licensed power reactor to which the agreement pertains or force majeure provisions.
Response
As described in response to RAI No. 2 in EGSL's Response to Request for Additional Information dated November 12, 2009 (Accession No. ML093200212), the capacity and energy from River Bend is priced pursuant to a FERC tariff under the Entergy System Agreement, denoted MSS-4. A copy of MSS-4 was provided as Enclosure 3 to EGSL's November 12, 2009 communication. MSS-4 provides, among other charges, a monthly capacity charge that is unrelated to any energy taken from the plant (energy is priced separately; see section 40.02(b) of MSS-4). Plant expenses (designated "OXP" in the formula), including decommissioning costs (designated "DGUDE" in the formula), are calculated pursuant to section 40.05 of MSS-4, and
-the plant expenses then flow into the Monthly Capacity Charge calculated pursuant to section 40.06 of MSS-4. Plant expenses are charged on a $/kW-month basis, depending on the amount of capacity purchased. The capacity purchased is indicated in the Power Purchase Agreement that was provided as Enclosure 2 to EGSL's November 12, 2009 communication.
These capacity payments do not depend on the operational status of the plant.
Neither the Power Purchase Agreement nor MSS-4 contain any force majeure provisions, and it is not intended that any force majeure events be allowed to override the contractual and tariff provisions.
- 7. Describe the licensee's procedure for implementing Section 3 of the Agreement, particularly with respect to how an insufficiency of funds for ETI's share is determined, when the determination is made, and the amount of time within which ETI must pay a deficit to the licensee. State whether the procedure is in written form, and if so, submit a copy of the procedure.
Response
There is no written procedure for implementation of Section 3 of the Agreement. When the Agreement was entered, it was expected that an insufficiency in decommissioning funding, if any, would be determined in conjunction with River Bend's periodic filings pursuant to 10 CFR
§50.75(f), and that upon the determination of such deficiency, ETI would request additional decommissioning funding from the Public Utility Commission of Texas (as was done in December of 2009). There is no set time frame within which ETI must pay a deficit to the licensee.
RBG-47026 Page 9 of 13
- 8. The November 12, 2009 submittal stated that ETI planned to make a rate filing to the PUCT by the end of 2009. Provide a description of the rate filing, including a summary of the amounts requested, the date the filing was made, and the PUCT docket number of the case. Provide a calculation showing whether ETI's share of decommissioning costs, as of December 31, 2009, would be covered if the amount requested is authorized.
Response
The filing requested decommissioning revenues in the amounts indicated in the response to question 1 above. The filing was made in December 2009, and was assigned PUCT Docket No. 37744. The following Tables 5-8 are similar to Tables 1-4 above, respectively, except that the December 31, 2009 NRC minimum value per § 50.75(c) (as indicated in the response to request number 5 above) is used, as well as the December 31, 2009 decommissioning trust fund values. As can be seen from Table 5 below, when these values are substituted into the model, a slightly lower revenue requirement is calculated (in the column denoted [1]).
Therefore, if the amount requested is authorized, ETI's share of decommissioning costs will be met based on the December 31, 2009 NRC minimum value.
RBG-47026 Page 10 of 13 Table 5 (Assuming December 31, 2009 NRC Min. and Decom. Trust Fund Balances)
Entergy Texas, Inc.
River Bend Decommissioning Model -
Texas Retail Revenue Requirement, Fund Balance and Expenditure Summary
($000)
Decommissioning Fund Balances Line Revenue No Year Rqmt. [1l 1
Beginning Balance 2
3 4
5 6
7 8
9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 2,391 1,594 0
0 0
0 0
0 0
0 0
Non-Tax Qualified [2]
2,242 2,361 2,490 2,631 2,783 2,947 3,122 3,307 3,504 3,714 3,937 4,174 4,427 4,683 4,930 5,162 0
0 0
0 0
0 0
0 0
0 Tax Qualified [3]
97,061 104,865 113,458 122,986 133,232 144,379 156,293 169,019 182,624 197,170 212,719 229,352 247,140 265,796 284,492 302,584 315,174 292,330 225,756 160,566 1151783 66,577 30,766 12,961 1,181 0
Total [4]
99,303 107,226 115,947 125,618 136,015 147,326 159,415 172,326 186,127 200,884 216,655 233,527 251,567 270,480 289,422 307,746 315,174 292,330 225,756 160,566 115,783 66,577 30,766 12,961 1,181 0
Decomm.
Expend. [5]
0 0
0 0
0 0
0 0
0 0
0 0
0 0
0 9,673 38,234 80,861 76,225 52,629 54,867 39,064 19,304 12,409 1,234 RBG-47026 Page 11 of 13 Table 6 (Assuming December 31, 2009 NRC Min. and Decom. Trust Fund Balances)
Entergy Texas, Inc.
River Bend Decommissioning Model -
Texas Retail Non-Tax Qualified Trust Detail
($000)
Non-Tax Qualified Trust Line Revenue Earning Transfer Mgmt.
Net Decomm.
No Year Rqmt. [1]
Rate [2] To Trust [3] Earnings [4]
Fee [5]
Additions [6] Expend. [7] Balance [8]
1 Beginning Balance 2,242 2
2010 2,391 5.45%
0 124 4
119 0
2,361 3
2011 2,391 5.54%
0 133 4
128 0
2,490 4
2012 2,391 5.80%
0 146 5
142 0
2,631 5
2013 2,391 5.87%
0 157 5
152 0
2,783 6
2014 2,391 5.97%
0 169 5
164 0
2,947 7
2015 2,391 5.99%
0 179 5
174 0
3.122 8
2016 2,391 6.01%
0 190 5
185 0
3,307 9
2017 2,391 6.02%
0 202 5
197 0
3,504 10 2018 2,391 6.04%
0 215 5
210 0
3,714 11 2019 2,391 6.06%
0 228 5
223 0
3,937 12 2020 2,391 6.08%
0 243 6
237 0
4,174 13 2021 2,391 6.09%
0 258 6
253 0
4,427 14 2022 2,391 5.84%
0 262 6
257 0
4,683 15 2023 2,391 5.31%
0 252 6
246 0
4,930 16 2024 2,391 4.78%
0 238 6
232 0
5,162 17 2025 1,594 4.64%
0 242 6
236 5,398 0
18 2026 0
4.51%
0 0
0 0
0 0
19 2027 0
4.51%
0 0
0 0
0 0
20 2028 0
4.51%
0 0
0 0
0 0
21 2029 0
4.51%
0 0
0 0
0 0
'22 2030 0
4.51%
0 0
0 0
0 0
23 2031 0
4.51%
0 0
0 0
0 0
24 2032 0
4.51%
0 0
0 0
0 0
25 2033 0
4.51%
0 0
0 0
0 0
26 2034 0
4.51%
0 0
0 0
0 0
RBG-47026 Page 12 of 13 Table 7 (Assuming December 31, 2009 NRC Min. and Decom. Trust Fund Balances)
Entergy Texas. Inc.
River Bend Decommissioning Model -
Texas Retail Tax Qualified Trust Detail (Sooo)
Tax Qualified Trust Line Revenue Earning Trans To Earnings Mgmt.
Net Decomm.
Qualifying No Year Rqmt. [I] Rate [21 Trust [3]
[4 Fee 15] Additions [6] Expend. [7]
Bal [8 Percent 1
Beginning Balance 97,061 2
2010 2.391 5.50%
2,391 5,477 65 7,804 0
104,865 1000/o 3
2011 2,391 5.83%
2,391 6,271 69 8,593 0
113,458 100%
4 2012 2,391 6.20%
2.391 7,212 74 9,529 0
122,986 100%
5 2013 2,391 6.29%
2,391 7,934 80 10,245 0
133,232 100%
6 2014 2,391 6.47%
2,391 8,842 86 11,147 0
144.379 100%
7 2015 2,391 6.50%
2,391 9.616 92 11,915 0
156,293 100%
8 2016 2,391 6.52%
2,391 10,434 99 12,726 0
169,019 100%
9 2017 2,391 6.54%
2,391 11,319 107 13,604 0
182,624 100%
10 2018 2,391 6.57%
2,391 12.270 114 14,547 0
197,170 100(%
11 2019 2,391 6.59%
2,391 13,280 123 15,549 0
212,719 100%/0 12 2020 2,391 6.61%
2,391 14,374 132 16,634 0
229,352 100%
13 2021 2,391 6.63%
2,391 15,538 141 17,788 0
247,140 100%/0 14 2022 2,391 6.51%
2,391 16,417 152 18,657 0
265,796 100%
15 2023 2,391 6.08%
2,391 16,467 162 18,696 0
284,492 100%
16 2024 2,391 5.48%
2,391 15,873 172 18,092 0
302,584 100%
17 2025 1,594 5.03%
1,594 15,452 181 16,865 4,275 315,174 100%/0 18 2026 0,0 4.88%
0 15,568 178 15,390 38,234 292,330 100%
19 2027 0
4.88%
0 14,440 153 14,287 80,861 225,756 100%
20 2028 0
4.88%
0 11,151 116 11,035 76,225 160,566 100%
21 2029 0
4.88%
0 7,931 85 7,846 52,629 115,783 100%
22 2030 0
4.88%
0 5,719 59 5,660 54,867 66,577 100%
23 2031 0
4.88%
0 3,289 35 3,253 39,064 30,766 100%
24 2032 0
4.88%
0 1,520 20 1,499 19,304 12,961 100%
25 2033 0
4.88%
0 640 11 629 12,409 1,181 100%
26 2034 0
4.88%
0 58 5
53 1,234 0
100% 6
RBG-47026 Page 13 of 13 Table 8 (Assuming December 31, 2009 NRC Min. and Decom. Trust Fund Balances)
Entergy Texas, Inc.
River Bend Decommissioning Model
- Texas Retail Decommissioning Expenditures
($000)
Line Cum. Nuclear Decommissioning Expenditures No Year Cost Esc. [1]
Estimate [2]
Texas Retail [3]
TX Retail Esc. [4]
1
- ' 2008 1.0000 0
0 0
2 2009 1.0425 0
0 0
3 2010 1.0868 0
0 0
4 2011 1.1330 0
0 0
5 2012 1.1812 0
0 0
6 2013 1.2314 0
0 0
7 2014 1.2837 0
0 0
8 2015 1.3383 0
0 0
9 2016 1.3952 0
0 0
10 2017 1.4545 0
0 0
11 2018 1.5163 0
0 0
12 2019 1.5807 0
0 0
13 2020 1.6479 0
0 0
0 14 2021 1.7179 0
0 0
15 -
2022 1.7909 0
0 0
16 2023 1.8670 0
0 0
17 2024 1.9463 0
0 0
18 2025 2.0290 11,157 4,767 9,673 19 2026 2.1152 42,302 18,076 38,234 20 2027 2.2051 85,818 36,670 80,861 21 2028 2.2988 77,600 33,158 76,225 22 2029 2.3965 51,394 21,961 52,629 23 2030 2.4984 51,394 21,961 54,867 24 2031 2.6046 35,100 14,998 39,064 25 2032 2.7153 16,638 7,109 19,304 26 2033 2.8307 10,259 4,384 12,409 27 2034 2.9510 979 418 1,234 Total 382,641 163,502 384,500