NYISO Tariffs --> Open Access Transmission Tariff (OATT) --> 14 OATT Attachment H - Annual Transmission Revenue Requireme --> 14.2 OATT Att H Attachment 1 to Att H - NYPA Transmission A
Table of Contents
Historical Transmission Revenue RequirementSchedule 1
Forecasted Transmission Revenue RequirementSchedule 2
Annual True-up with Interest Calculation Schedule 3
Year to Year Comparison Schedule 4
Allocators Schedule 5
Transmission Investment Base (Part 1 of 2) Schedule 6 Page 1 of 2
Transmission Investment Base (Part 1 of 2) Schedule 6 Page 2 of 2
Transmission Investment Base (Part 2 of 2) Schedule 7
Capital Structure Schedule 8
Expenses Schedule 9
Other Schedule 10
System Dispatch Expense - Component CCCSchedule 11
Billing Units - Component BU Schedule 12
Effective Date: 6/30/2010 - Docket #: ER10-1657-000 - Page 1
NYISO Tariffs --> Open Access Transmission Tariff (OATT) --> 14 OATT Attachment H - Annual Transmission Revenue Requireme --> 14.2 OATT Att H Attachment 1 to Att H - NYPA Transmission A
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| Attachment 1 | |||
Calculation of RR Pursuant to Attachment H, Section 14.1.9.2 |
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| Schedule 1 | ||
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| Calculation of RR |
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| 9.2 | The RR component shall equal the (a) Historical Transmission Revenue Requirement plus (b) the Forecasted Transmission Revenue Requirement plus (c) the Annual True-Up, determined in accordance with the formula below. |
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Historical Transmission Revenue Requirement (Historical TRR) |
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Line No. |
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1 |
| Historical Transmission Revenue Requirement (Historical TRR) |
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2 |
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3 | 9.2 (a) | Historical TRR shall equal the sum of NMPC’s (A) Return and Associated Income Taxes, (B) Transmission Related Depreciation Expense, (C) |
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4 |
| Transmission Related Real Estate Tax Expense, (D) Transmission Related Amortization of Investment Tax Credits, |
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| (E) Transmission Operation and Maintenance Expense, (F) Transmission Related Administrative and General Expenses, (G) Transmission |
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6 |
| Related Payroll Tax Expense, (H) Billing Adjustments, and (I) Transmission Related Bad Debt Expense less |
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7 |
| (J) Revenue Credits, and (K) Transmission Rents, all determined for the most recently ended calendar year as of the beginning of the update year. |
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8 |
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| Reference |
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9 |
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| Section: |
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10 |
| Return and Associated Income Taxes |
| (A) |
| #DIV/0! |
| Schedule 8, line 64 | |
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| Transmission-Related Depreciation Expense |
| (B) |
| #DIV/0! |
| Schedule 9, Line 6, column 5 | |
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| Transmission-Related Real Estate Taxes |
| (C) |
| #DIV/0! |
| Schedule 9, Line 12, column 5 | |
13 |
| Transmission - Related Investment Tax Credit |
| (D) |
| #DIV/0! |
| Schedule 9, Line 16, column 5 | |
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| Transmission Operation & Maintenance Expense |
| (E) |
| $0 |
| Schedule 9, Line 23, column 5 | |
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| Transmission Related Administrative & General Expense |
| (F) |
| #DIV/0! |
| Schedule 9, Line 37, column 5 | |
16 |
| Transmission Related Payroll Tax Expense |
| (G) |
| $0 |
| Schedule 9, Line 43, column 5 | |
17 |
| Sub-Total (sum of Lines 10 - Line 16) |
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| #DIV/0! |
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18 |
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19 |
| Plus: Billing Adjustments |
| (H) |
| $0 |
| Schedule 10, Line 1 | |
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| Plus : Bad Debt Expenses |
| (I) |
| $0 |
| Schedule 10, Line 4 | |
21 |
| Less: Revenue Credits |
| (J) |
| $0 |
| Schedule 10, Line 7 | |
22 |
| Less: Transmission Rents |
| (K) |
| $0 |
| Schedule 10, Line 14 | |
23 |
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24 |
| Total Historical Transmission Revenue Requirement (Sum of Line 17 - Line 22) |
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25 |
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Niagara Mohawk Power Corporation |
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| Attachment 1 | ||
Forecasted Transmission Revenue Requirement |
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| Schedule 2 | |||
| Attachment H, Section 9.2 |
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| Shading denotes an input |
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Line No. |
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1 | 9.2 (b) | FORECASTED TRANSMISSION REVENUE REQUIREMENTS |
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| Forecasted TRR shall equal (1) the Forecasted Transmission Plant Additions (FTPA) multiplied by the Annual FTRRF, plus (2) the Mid-Year Trend | ||||||
3 |
| Adjustment (MYTA), plus (3) the Tax Rate Adjustment (TRA), as shown in the following formula: | ||||||
4 |
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| Forecasted TRR = (FTPA * FTRRF) + MYTA + TRA |
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6 |
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7 |
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9 |
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10 | (1) | Forecasted Transmission Plant Additions (FTPA) |
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| $0 |
| Workpaper 8, Section I, Line 16 |
11 |
| Annual Transmission Revenue Requirement Factor (FTRRF) |
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| #DIV/0! |
| Line 35 |
12 |
| Sub-Total (Lines 10*11) |
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| #DIV/0! |
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13 |
| Plus Mid-Year Trend Adjustment (2) (MYTA) |
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| $0 |
| Workpaper 9, line 31, variance column |
14 |
| Forecasted Transmission Revenue Requirement (Line 12 + Line 13) |
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| #DIV/0! |
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15 |
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16 | (2) | MID YEAR TREND ADJUSTMENT (MYTA) |
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17 |
| The Mid-Year Trend Adjustment shall be the difference, whether positive or negative, between |
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18 |
| (i) the Historical TRR Component (E) based on actual data for the first three months of the Forecast Period, |
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| and (ii) the Historical TRR Component (E) based on data for the first three months of the year prior to the Forecast Period. |
| Workpaper 9 | ||||
20 |
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21 | (3) | The Tax Rate Adjustment (TRA) |
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22 |
| The Tax Rate Adjustment shall be the amount, if any, required to adjust Historical TRR Component (A) for any change in the Federal Income Tax Rate | ||||||
23 |
| and/or the State Income Tax Rate that takes effect during the first five months of the Forecast Period. |
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24 |
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25 | 9.2 (c) | ANNUAL FORECAST TRANSMISSION REVENUE REQUIREMENT FACTOR |
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26 |
| The Annual Forecast Transmission Revenue Requirement Factor (Annual FTRRF) shall equal the sum of Historical TRR components (A) through (C), |
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27 |
| divided by the year-end balance of Transmission Plant in Service determined in accordance with Section 9.2 (a), component (A)1(a). |
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28 |
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29 |
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30 |
| Investment Return and Income Taxes |
| (A) |
| #DIV/0! |
| Schedule 1, Line 10 |
31 |
| Depreciation Expense |
| (B) |
| #DIV/0! |
| Schedule 1, Line 11 |
32 |
| Property Tax Expense |
| (C) |
| #DIV/0! |
| Schedule 1, Line 12 |
33 |
| Total Expenses (Lines 30 thru 32) |
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| #DIV/0! |
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34 |
| Transmission Plant |
| (a) |
| #DIV/0! |
| Schedule 6, Page 1, Line 12 |
35 |
| Annual Forecast Transmission Revenue Requirement Factor (Lines 33/ Line 34) |
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| #DIV/0! |
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Niagara Mohawk Power Corporation |
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| Attachment 1 | ||
Annual True-up (ATU) |
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| Schedule 3 | ||
| Attachment H Section 9.2 (c) |
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1 |
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2 | 9.2(d) | The Annual True-Up (ATU) shall equal (1) the difference between the Actual Transmission Revenue Requirement and the Prior Year | |||
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| Transmission Revenue Requirement, plus (2) the difference between the Actual Scheduling, System Control and Dispatch costs | |||
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| and Prior Year Scheduling, System Control and Dispatch costs, plus (3) the difference between the Prior Year Billing Units and the Actual Year | |||
5 |
| Billing Units multiplied by the Prior Year Unit Rate, plus (4) Interest on the net differences. | |||
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7 | (1) | Revenue Requirement (RR) of rate effective July 1 of prior year | $0 |
| Schedule 4, Line 1, Col (d) |
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| Less: Annual True-up (ATU) from rate effective July 1 of prior year | $0 |
| Schedule 4, Line 1, Col (c) |
9 |
| Prior Year Transmission Revenue Requirement | $0 |
| Line 7 - Line 8 |
10 |
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11 |
| Actual Transmission Revenue Requirement | #DIV/0! |
| Schedule 4, Line 2, Col (a) |
12 |
| Difference | #DIV/0! |
| Line 11 - Line 9 |
13 |
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14 | (2) | Prior Year Scheduling, System Control and Dispatch costs (CCC) | $0 |
| Schedule 4, Line 1, Col (e) |
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| Actual Scheduling, System Control and Dispatch costs (CCC) | $0 |
| Schedule 4, Line 2, Col (e) |
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| Difference | $0 |
| Line 15 - Line 14 |
17 |
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18 | (3) | Prior Year Billing Units (MWH) | $0 |
| Schedule 4, Line 1, Col (f) |
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| Actual Billing Units | - |
| Schedule 4, Line 2, Col (f) |
20 |
| Difference | - |
| Line 18 - Line 19 |
21 |
| Prior Year Indicative Rate | #DIV/0! |
| Schedule 4, Line 1, Col (g) |
22 |
| Billing Unit True-Up | #DIV/0! |
| Line 20 * Line 21 |
23 |
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24 |
| Total Annual True-Up before Interest | #DIV/0! |
| (Line 12 + Line 16 + Line 22) |
25 |
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26 | (4) | Interest | #DIV/0! |
| Line 57 |
27 |
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28 |
| Annual True-up RR Component | #DIV/0! |
| (Line 24 + Line 26) |
29 |
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30 |
| Interest Calculation per 18 CFR § 35.19a |
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31 |
| (1) | (2) | (3) | (4) | (5) | (6) | (7) | (8) | (9) |
32 |
| Quarters | Annual | Accrued Prin | Monthly | Days |
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| Accrued Prin | Accrued |
33 |
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| Interest | & Int. @ Beg | (Over)/Under | in | Period |
| & Int. @ End | Int. @ End |
34 |
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| Rate (a) | Of Period | Recovery | Period | Days | Multiplier | Of Period | Of Period |
35 |
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36 |
| 3rd QTR '07 |
| 0 |
| 92 | 92 | 1.0000 | $0 | $0 |
37 |
| July | 0.00% |
| #DIV/0! | 31 | 92 | 1.0000 | #DIV/0! | #DIV/0! |
38 |
| August | 0.00% |
| #DIV/0! | 31 | 61 | 1.0000 | #DIV/0! | #DIV/0! |
39 |
| September | 0.00% |
| #DIV/0! | 30 | 30 | 1.0000 | #DIV/0! | #DIV/0! |
40 |
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41 |
| 4th QTR '07 |
| #DIV/0! |
| 92 | 92 | 1.0000 | #DIV/0! | #DIV/0! |
42 |
| October | 0.00% |
| #DIV/0! | 31 | 92 | 1.0000 | #DIV/0! | #DIV/0! |
43 |
| November | 0.00% |
| #DIV/0! | 30 | 61 | 1.0000 | #DIV/0! | #DIV/0! |
44 |
| December | 0.00% |
| #DIV/0! | 31 | 31 | 1.0000 | #DIV/0! | #DIV/0! |
45 |
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46 |
| 1st QTR '08 |
| #DIV/0! |
| 91 | 91 | 1.0000 | #DIV/0! | #DIV/0! |
47 |
| January | 0.00% |
| #DIV/0! | 31 | 91 | 1.0000 | #DIV/0! | #DIV/0! |
48 |
| February | 0.00% |
| #DIV/0! | 29 | 60 | 1.0000 | #DIV/0! | #DIV/0! |
49 |
| March | 0.00% |
| #DIV/0! | 31 | 31 | 1.0000 | #DIV/0! | #DIV/0! |
50 |
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51 |
| 2nd QTR '08 |
| #DIV/0! |
| 91 | 91 | 1.0000 | #DIV/0! | #DIV/0! |
52 |
| April | 0.00% |
| #DIV/0! | 30 | 91 | 1.0000 | #DIV/0! | #DIV/0! |
53 |
| May | 0.00% |
| #DIV/0! | 31 | 61 | 1.0000 | #DIV/0! | #DIV/0! |
54 |
| June | 0.00% |
| #DIV/0! | 30 | 30 | 1.0000 | #DIV/0! | #DIV/0! |
55 |
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56 |
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57 |
| Total (over)/under Recovery |
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| (a) Interest rates shall be the interest rates as reported on the FERC Website http://www.ferc.gov/legal/acct-matts/interest-rates.asp |
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| Attachment 1 | ||||||||||
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| Schedule 4 | |||||||||
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| Niagara Mohawk Power Corporation Wholesale TSC Calculation Information |
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| 2008 Forecast using 2007 Historical Data and 2008 Forecast
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| See Note (**) below. |
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| (b)
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| (e)
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| Historical Transmission Revenue Requirement (Historical TRR) | Forecasted Transmission Revenue Requirement | Annual True Up (**) | Revenue Requirement (RR) | Scheduling System Control and Dispatch Costs (CCC) | Annual Billing Units (BU) MWh | Rate $/MWh (*) | |||||||||
1 | Prior Year Rates Effective ________ | - | - | - | - | - | - | #DIV/0! | |||||||||
2 | Current Year Rates Effective July 1, 2008 | #DIV/0! | #DIV/0! |
| #DIV/0! | - | - | #DIV/0! | |||||||||
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3 | Increase/(Decrease) |
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4 | Percentage Increase/(Decrease) |
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1.) | Information directly from Niagara Mohawk Prior Year Informational Filing |
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2.) |
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(a) | Schedule 1, Line 24 |
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(b) | Schedule 2, Line 14 |
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(c) | Schedule 3, Line 28 |
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(d) | Attachment H, Section 9.2 The RR Component shall equal Col (a) Historical Transmission Revenue Requirement plus Col (b) the Forecasted Transmission Revenue Requirement plus Col (c) the Annual True-Up | ||||||||||||||||
(e) | Schedule 11 - Annual Scheduling, System Control and Dispatch Costs. (i.e. the Transmission Component of control center costs) as recorded in FERC Account 561 and its associated sub-accounts from the prior calendar year excluding any NY Independent System Operating (NYISO) system control and load dispatch expenses already recovered under Schedule 1 of the NYISO Tariff. | ||||||||||||||||
(f) | Schedule 12 - Billing Units shall be the total Niagara Mohawk load as reported to the NYISO for the calendar year prior to the Forecast Period, including the load for customers taking service under Niagara Mohawk's TSC rate. The total Niagara Mohawk load will be adjusted to exclude (i) load associated with wholesale transactions being revenue credited through the WR, CRR, SR, ECR, and Reserved components of Attachment H of the NYISO TSC rate including Niagara Mohawk's external sales, load associated with grandfathered OATT agreements, and any load related to pre-OATT grandfathered agreements; (ii) load associated with transactions being revenue credited under Historical TRR Component J; and (iii) load associated with netted station service. | ||||||||||||||||
(g) | (Col (d) + Col (e)) / Col (f) |
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(*) | The rate column represents the unit rate prior to adjustments; the actual rate will be determined pursuant to the applicable TSC formula rate. | ||||||||||||||||
(**) | There was no true-up for this period. This is illustrative only. |
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Niagara Mohawk Power Corporation |
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| Attachment 1 | ||
Allocation Factors - As calculated pursuant to Section 9.1 |
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| Schedule 5 | |||
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| Shading denotes an input |
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No. |
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| Definition |
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1 | 9.1 1. | Electric Wages and Salaries Factor |
| 83.5000% |
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| Fixed per settlement |
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3 | 9.1 3. | Transmission Wages and Salaries Allocation Factor | 13.0000% |
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| Fixed per settlement | |
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5 |
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6 |
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7 |
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8 | 9.1 2. | Gross Transmission Plant Allocation Factor |
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9 |
| Transmission Plant in Service |
| #DIV/0! | JLL | Schedule 6, Page 2, Line 3, Col 5 |
| Gross Transmission Plant Allocation Factor shall equal the total investment in |
10 |
| Plus: Transmission Related General |
| $0 |
| Schedule 6, Page 2, Line 5, Col 5 |
| Transmission Plant in Service, Transmission Related Electric General Plant, |
11 |
| Plus: Transmission Related Common |
| $0 |
| Schedule 6, Page 2, Line 10, Col 5 |
| Transmission Related Common Plant and Transmission Related Intangible Plant |
12 |
| Plus: Transmission Related Intangible Plant | $0 |
| Schedule 6, Page 2, Line 15, Col 5 |
| divided by Gross Electric Plant. | |
13 |
| Gross Transmission Investment |
| #DIV/0! |
| Sum of Lines 9 - 13 |
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14 |
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15 |
| Total Electric Plant |
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| JLL | FF1 207.104 |
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16 |
| Plus: Electric Common |
| $0 |
| Schedule 6, Page 2, Line 10, Col 3 |
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17 |
| Gross Electric Plant in Service |
| $0 |
| Line 15 + Line 16 |
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18 |
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19 |
| Percent Allocation |
| #DIV/0! |
| Line 13 / Line 17 |
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20 |
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21 | 9.1 4. | Gross Electric Plant Allocation Factor |
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22 |
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23 |
| Total Electric Plant in Service |
| $0 |
| Line 15 |
| Gross Electric Plant Allocation Factor shall equal |
24 |
| Plus: Electric Common Plant |
| $0 |
| Schedule 6, Page 2, Line 10, Col 3 |
| Gross Electric Plant divided by the sum of Total Gas Plant, |
25 |
| Gross Electric Plant in Service |
| $0 |
| Line 23 + Line 24 |
| Total Electric Plant, and Total Common Plant |
26 |
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27 |
| Total Gas Plant in Service |
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| JLL | FF1 201.8d |
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28 |
| Total Electric Plant in Service |
| $0 |
| Line 15 |
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29 |
| Total Common Plant in Service |
| $0 |
| Schedule 6, Page 2, Line 10, Col 1 |
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30 |
| Gross Plant in Service (Gas & Electric) |
| - |
| Sum of Lines 27-Lines 29 |
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31 |
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32 |
| Percent Allocation |
| #DIV/0! |
| Line 25 / Line 30 |
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Niagara Mohawk Power Corporation |
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| Attachment 1 Schedule 6 Page 1 of 2 |
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Annual Revenue Requirements of Transmission Facilities |
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Transmission Investment Base (Part 1 of 2) |
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Attachment H, section 9.2 |
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Line No. |
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1 | 9.2 (a) | Transmission Investment Base |
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2 |
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3 | A.1. | Transmission Investment Base shall be defined as (a) Transmission Plant in Service, plus (b) Transmission Related Electric General Plant, plus |
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| (c) Transmission Related Common Plant, plus (d) Transmission Related Intangible Plant, plus (e) Transmission Related Plant Held for Future Use, less | |||||||||
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| (f) Transmission Related Depreciation Reserve, less (g) Transmission Related Accumulated Deferred Taxes, plus (h) Transmission Related | |||||||||
6 |
| Regulatory Assets net of Regulatory Liabilities, plus (i) Transmission Related Prepayments, plus (j) Transmission Related Materials and Supplies, | |||||||||
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| plus (k) Transmission Related Cash Working Capital. | |||||||||
8 |
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9 |
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10 |
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| Reference |
| 2007 |
| Reference |
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11 |
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| Section: |
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12 |
| Transmission Plant in Service |
| (a) |
| #DIV/0! |
| Schedule 6, page 2, line 3, column 5 | |||
13 |
| General Plant |
| (b) |
| $0 |
| Schedule 6, page 2, line 5, column 5 | |||
14 |
| Common Plant |
| (c) |
| $0 |
| Schedule 6, page 2, line 10, column 5 | |||
15 |
| Intangible Plant |
| (d) |
| $0 |
| Schedule 6, page 2, line 15, column 5 | |||
16 |
| Plant Held For Future Use |
| (e) |
| $0 |
| Schedule 6, page 2, line 19, column 5 | |||
17 |
| Total Plant (Sum of Line 12 - Line 16) |
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18 |
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19 |
| Accumulated Depreciation |
| (f) |
| #DIV/0! |
| Schedule 6, page 2, line 29, column 5 | |||
20 |
| Accumulated Deferred Income Taxes |
| (g) |
| #DIV/0! |
| Schedule 7, line 6, column 5 | |||
21 |
| Other Regulatory Assets |
| (h) |
| #DIV/0! |
| Schedule 7, line 11, column 5 | |||
22 |
| Net Investment (Sum of Line 17 -Line 21) |
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23 |
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24 |
| Prepayments |
| (i) |
| #DIV/0! |
| Schedule 7, line 15, column 5 | |||
25 |
| Materials & Supplies |
| (j) |
| #DIV/0! |
| Schedule 7, line 21, column 5 | |||
26 |
| Cash Working Capital |
| (k) |
| $0 |
| Schedule 7, line 28, column 5 | |||
27 |
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28 |
| Total Investment Base (Sum of Line 22 - Line 26) |
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| Attachment 1 | ||||||||||||||||||||
Annual Revenue Requirements of Transmission Facilities |
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| Schedule 6 | ||||||||||||||||||||
Transmission Investment Base (Part 1 of 2) |
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| Page 2 of 2 | ||||||||||||||||||||
| Attachment H Section 9.2 (a) A. 1. |
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| Shading denotes an input |
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| (2) |
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Line |
| (1) |
| Allocation |
| Electric |
| Allocation |
| Transmission |
| FERC Form 1/PSC Report |
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No. |
| Total |
| Factor |
| Allocated |
| Factor |
| Allocated |
| Reference for col (1) |
| Definition | |||||||||||||
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1 | Transmission Plant |
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| FF1 207.58g | 9.2(a)A.1.(a) | Transmission Plant in Service shall equal the | |||||||||||||
2 | Wholesale Meter Plant |
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| #DIV/0! |
| Workpaper 1, Line 45 |
| balance of total investment in Transmission Plant | |||||||||||||
3 | Total Transmission Plant in Service (Line 1+ Line 2) |
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| #DIV/0! |
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| plus Wholesale Metering Investment | ||||||||||||||
4 |
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5 | General Plant |
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| 100.00% |
| $0 |
| 13.00% | (c) | $0 |
| FF1 207.99g | 9.2(a)A.1.(b) | Transmission Related Electric General Plant shall | |||||||||||||
6 |
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| equal the balance of investment in Electric General | |||||||||||||
7 |
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| Plant mulitplied by the Transmission Wages and | |||||||||||||
8 |
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| Salaries Allocation Factor | |||||||||||||
9 |
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10 | Common Plant |
| JLL | 83.50% | (a) | $0 |
| 13.00% | (c) | $0 |
| FF1 201. 8h | 9.2(a)A.1.(c) | Transmission Related Common Plant shall equal Common | |||||||||||||
11 |
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| Plant multiplied by the Electric Wages and Salaries | |||||||||||||
12 |
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| Allocation Factor and further multiplied by the | |||||||||||||
13 |
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| Transmission Wages and Salaries Allocation Factor. | |||||||||||||
14 |
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15 | Intangible Plant |
| JLL | 100.00% |
| - |
| 13.00% | (c) | $0 |
| FF1 205.5g | 9.2(a)A.1.(d) | Transmission Related Intangible Plant shall equal Intangible | |||||||||||||
16 |
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| Electric Plant multiplied by the Transmission Wages and | |||||||||||||
17 |
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| Salaries Allocation Factor. | |||||||||||||
18 |
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19 | Transmission Plant Held for Future Use | $0 | JLL |
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| $0 |
| Workpaper 10, Line 1 | 9.2(a)A.1.(e) | Transmission Related Plant Held for Future Use shall equal | |||||||||||||
20 |
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| the balance in Plant Held for Future Use associated with | |||||||||||||
21 |
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| property planned to be used for transmission service within | |||||||||||||
22 |
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| five years | |||||||||||||
23 | Transmission Accumulated Depreciation |
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24 | Transmission Accum. Depreciation |
| JLL |
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| $0 |
| FF1 219.25b | 9.2(a)A.1.(f) | Transmission Related Depreciation Reserve shall equal the | |||||||||||||
25 | General Plant Accum.Depreciation |
| JLL | 100.00% |
| $0 |
| 13.00% | (c) | $0 |
| FF1 219.28b |
| balance of: (i) Transmission Depreciation Reserve, plus (ii) | |||||||||||||
26 | Common Plant Accum Depreciation |
| JLL | 83.50% | (a) | $0 |
| 13.00% | (c) | $0 |
| FF1 356.1 end of year balance | the product of Electric General Plant Depreciation Reserve | ||||||||||||||
27 | Amortization of Other Utility Plant |
| JLL | 100.00% |
| $0 |
| 13.00% | (c) | $0 |
| FF1 200.21c |
| multiplied by the Transmission Wages and Salaries | |||||||||||||
28 | Wholesale Meters | #DIV/0! |
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| #DIV/0! |
| Workpaper 1, Line 46 |
| Allocation Factor, plus (iii) the product of Common Plant | |||||||||||||
29 | Total Depreciation (Sum of line 24 - Line 28) |
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| #DIV/0! |
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| Depreciation Reserve multiplied by the Electric Wages and | ||||||||||||||
30 |
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| Salaries Allocation Factor and further multiplied by the | |||||||||||||
31 |
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| Transmission Wages and Salaries Allocation Factor plus (iv) | |||||||||||||
32 |
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| the product of Intangible Electric Plant Depreciation Reserve | |||||||||||||
33 |
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| multiplied by the Transmission Wages and Salaries | |||||||||||||
34 |
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| Allocation Factor plus (v) depreciation reserve associated with | |||||||||||||
35 |
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| the Wholesale Metering Investment | |||||||||||||
36 |
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| Allocation Factor Reference |
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| (a) Schedule 5, line 1 |
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| (b) Schedule 5, line 32 - not used on this Schedule |
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| (c) Schedule 5, line 3 |
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| (d) Schedule 5, line 19 - not used on this Schedule |
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Niagara Mohawk Power Corporation | Attachment 1 |
Annual Revenue Requirements of Transmission Facilities | Schedule 7 |
Transmission Investment Base ( Part 2 of 2) |
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| Attachment H Section 9.2 (a) A. 1. |
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| Shading denotes an input |
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Line No. |
| (1) Total | (2) Allocation Factor | (3) = (1)*(2) Electric Allocated | (4) Allocation Factor | (5) = (3)*(4) Transmission Allocated | FERC Form 1/PSC Report Reference for col (1) |
| Definition | |
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1 | Transmission Accumulated Deferred Taxes |
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2 | Accumulated Deferred Taxes (281-282) |
| 100.00% | $0 | #DIV/0! (d) | #DIV/0! | FF1 275.2k | 9.2(a)A.1.(g) | Transmission Related Accumulated Deferred Income Taxes | |
3 | Accumulated Deferred Taxes (283) | $0 | 100.00% | $0 | #DIV/0! (d) | #DIV/0! | Workpaper 2, Line 5 (link) |
| shall equal the electric balance of Total Accumulated Deferred | |
4 | Accumulated Deferred Taxes (190) |
| 100.00% | $0 | #DIV/0! (d) | #DIV/0! | FF1 234.8c |
| Income Taxes (FERC Accounts 190, 55,281, 282, and 283 net of | |
5 | Accumulated Deferred Inv. Tax Cr (255) |
| 100.00% | $0 | #DIV/0! (d) | #DIV/0! | FF1 267.8h |
| stranded costs), multiplied by the Gross Transmission Plant | |
6 | Total (Sum of line 2 - Line 5) |
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| Allocation Factor. | |
7 |
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8 | Other Regulatory Assets |
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9 | FAS 109 (Asset Account 182.3) |
| 100.00% | $0 | #DIV/0! (d) | #DIV/0! | FF1 232 lines 2,4,9,17 | 9.2(a)A.1.(h) | Transmission Related Regulatory Assets shall be Regulatory | |
10 | FAS 109 ( Liability Account 254 ) |
| 100.00% | $0 | #DIV/0! (d) | #DIV/0! | FF1 278.1 lines 4&21(f) |
| Assets net of Regulatory Liabilities multiplied by the Gross | |
11 | Total (line 9 + Line 10) | $0 |
| $0 |
| #DIV/0! |
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| Transmission Plant Allocation Factor. | |
12 |
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13 | Transmission Prepayments |
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| FF1 111.57c | 9.2(a)A.1.(i) | Transmission Related Prepayments shall be the product of | |
14 | Less: Prepaid State and Federal Income Tax |
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| FF1 263 lines 2 & 9 (h) |
| Prepayments excluding Federal and State taxes multiplied by | |
15 | Total Prepayments | $0 | #DIV/0! (b) | #DIV/0! | #DIV/0! (d) | #DIV/0! |
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| the Gross Electric Plant Allocation Factor and further | |
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| multiplied by the Gross Transmission Plant Allocation Factor. | |
17 |
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18 | Transmission Material and Supplies |
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| 9.2(a)A.1.(j) | Transmission Related Materials and Supplies shall equal: (i) | |
19 | Trans. Specific O&M Materials and Supplies |
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| $0 | FF1 227.8 |
| the balance of Materials and Supplies assigned to | |
20 | Construction Materials and Supplies |
| #DIV/0! (b) | #DIV/0! | #DIV/0! (d) | #DIV/0! | FF1 227.5 |
| Transmission plus (ii) the product of Material and Supplies | |
21 | Total (Line 19 + Line 20) |
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22 |
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| Plant Allocation Factor and further multiplied by Gross | |
23 |
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25 | Cash Working Capital |
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| 9.2(a)A.1.(k) | Transmission Related Cash Working Capital shall be an | |
26 | Operation & Maintenance Expense |
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| $0 | Schedule 9, Line 23 |
| allowance equal to the product of: (i) 12.5% (45 days/ 360 days = 12.5%) | |
27 |
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| multiplied by (ii) Transmission Operation and Maintenance Expense. | |
28 | Total (line 26 * line 27) |
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29 |
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30 |
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| Allocation Factor Reference |
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| (a) Schedule 5, line 1 - not used on this Schedule |
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| (b) Schedule 5, line 32 |
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| (c) Schedule 5, line 3 - not used on this Schedule |
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Niagara Mohawk Power Corporation | Attachment 1 |
Annual Revenue Requirements of Transmission Facilities | Schedule 8 |
Cost of Capital Rate |
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| Shading denotes an input | 0 |
Line No. | ||
1 | The Cost of Capital Rate shall equal the proposed Weighted Costs of Capital plus Federal Income Taxes and State Income Taxes. | |
2 |
| The Weighted Costs of Capital will be calculated for the Transmission Investment Base using NMPC’s actual capital structure and will equal the sum of (i), (ii), and (iii) below: |
3 |
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4 | (i) | the long-term debt component, which equals the product of the actual weighted average embedded cost to maturity of NMPC’s long-term debt outstanding during the year and the sum of (a) the ratio of actual long-term debt to total capital at year-end; and |
5 |
| (b) the extent, if any, by which the ratio of NMPC's actual common equity to total capital at year-end exceeds fifty percent (50%). Long term debt shall be defined as the average of the beginning of the year and end of year balances of the following: long term debt less the unamortized |
6 |
| Discounts on Long-Term Debt less the unamortized Loss on Reacquired Debt plus unamortized Gain on Reacquired Debt. Cost to maturity of NMPC's long-term debt shall be defined as the cost of long term debt included in the debt discount expense and |
7 |
| any loss or gain on reacquired debt. |
8 | (ii) | the preferred stock component, which equals the product of the actual weighted average embedded cost to maturity of NMPC’s preferred stock then outstanding and the ratio of actual preferred stock to total capital at year-end; |
9 |
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10 | (iii) | the return on equity component shall be the product of the allowed return on equity of 11.5% and the ratio of NMPC’s actual common equity to total capital at year-end, provided that such ratio |
11 |
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13 |
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| WEIGHTED |
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| CAPITALIZATION |
| COST OF |
| COST OF |
| EQUITY |
15 |
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| CAPITALIZATION | Source: | RATIOS |
| CAPITAL | Source: | CAPITAL |
| PORTION |
16 |
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17 |
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| (i) | Long-Term Debt | $0 | Workpaper. 6, Line 16b | #DIV/0! |
| #DIV/0! | Workpaper 6, Line 17c | #DIV/0! |
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18 |
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| FF1 112.3c | #DIV/0! |
| #DIV/0! | Workpaper 6, Line 24d | #DIV/0! |
| #DIV/0! |
19 |
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| (iii) | Common Equity |
| FF1 112.16c - FF1 112.3,12,15c | #DIV/0! |
| 11.50% |
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20 |
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21 |
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| Total Investment Return | $0 |
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22 |
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23 |
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25 |
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26 | 9.2.2.(b) | Federal Income Tax shall equal | = ( | A. + | [ | B | / | C] | X |
| Federal Income Tax Rate | ) |
27 |
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| Federal Income Tax Rate | ) | |
28 |
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29 |
| where A is the sum of the preferred stock component and the return on equity component, each as determined in Sections (a)(ii) and for the ROE set forth in (a)(iii) above, B is the Equity AFUDC component of Depreciation Expense for |
30 |
| Transmission Plant in Service as defined at Section 9.1.16 (FF1 117.38c), and C is the Transmission Investment Base as shown at Schedule 6, Page 1 of 2, Line 28. |
31 |
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| = ( | #DIV/0! | +( | $0 | ) / |
| #DIV/0! | X |
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33 |
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35 |
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36 |
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37 |
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38 | 9.2.2.(c) | State Income Tax shall equal | = ( | A. + | [ | B | / | C] | + |
| Federal Income Tax Rate | ) X | State Income Tax Rate |
39 |
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| State Income Tax Rate | ) |
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40 |
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41 |
| where A is the sum of the preferred stock component and the return on equity component as determined in (a)(ii) and (a)(iii) above , B is the Equity AFUDC component of Depreciation Expense for Transmission Plant in |
42 |
| Service as defined at Section 14.1.9.1.16 above, and C is the Transmission Investment Base as shown at Schedule 6, Page 1 of 2, Line 28. |
43 |
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44 |
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| = ( | #DIV/0! | +( | $0 | ) / |
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47 |
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48 |
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49 |
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50 |
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51 |
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52 |
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53 | (a)+(b)+(c) Cost of Capital Rate | = | #DIV/0! |
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54 |
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55 |
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56 | 9.2(a) A. Return and Associated Income Taxes shall equal the product of the Transmission Investment Base and the Cost of Capital Rate | ||||||||||||||||||||||||||
57 |
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58 |
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59 |
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60 | Transmission Investment Base |
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61 |
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62 | Cost of Capital Rate |
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63 |
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64 | = Investment Return and Income Taxes |
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Niagara Mohawk Power Corporation | Attachment 1 |
Annual Revenue Requirements of Transmission Facilities | Schedule 9 |
Transmission Expenses |
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| Attachment H Section 9.2 |
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| 0 |
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| Shading denotes an input |
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Line No. |
| (1) Total | (2) Allocation Factor | (3) = (1)*(2) Electric Allocated | (4) Allocation Factor | (5) = (3)*(4) Transmission Allocated | FERC Form 1/ PSC Report Reference for col (1) |
| Definition |
| Depreciation Expense |
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1 | Transmission Depreciation |
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| $0 | FF1 336.7f | 9.2.B. | Transmission Related Depreciation Expense shall equal the sum of: |
2 | General Depreciation |
| 100.0000% | $0 | 13.0000% (c) | $0 | FF1 336.10f |
| (i) Depreciation Expense for Transmission Plant in Service, plus (ii) |
3 | Common Depreciation |
| 83.5000% (a) | $0 | 13.0000% (c) | $0 | FF1 356.1 |
| the product of Electric General Plant Depreciation Expense multiplied |
4 | Intangible Depreciation |
| 100.0000% | $0 | 13.0000% (c) | $0 | FF1 336.1f |
| by the Transmission Wages and Salaries Allocation Factor plus (iii) |
5 | Wholesale Meters |
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| #DIV/0! | Workpaper 1, Line 47 |
| Common Plant Depreciation Expense multiplied by the Electric |
6 | Total (line 1+2+3+4+5) |
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| #DIV/0! |
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| Wages and Salaries Allocation Factor, further multiplied by the |
7 |
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| Transmission Wages and Salaries Allocation Factor plus (iv) |
8 |
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| Intangible Electric Plant Depreciation Expense multiplied by the |
9 |
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| Transmission Wages and Salaries Factor plus (v) depreciation |
10 |
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| expense associated with the Wholesale Metering Investment. |
11 |
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12 | Real Estate Taxes |
| 100.0000% | $0 | #DIV/0! (d) | #DIV/0! | FF1 263.25i | 9.2.C. | Transmission Related Real Estate Tax Expense shall equal the |
13 |
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| electric Real Estate Tax Expenses multiplied by the Gross |
14 |
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| Transmission Plant Allocation Factor. |
15 |
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16 | Amortization of Investment Tax Credits |
| #DIV/0! (b) | #DIV/0! | #DIV/0! (d) | #DIV/0! | FF1 117.58c | 9.2.D. | Transmission Related Amortization of Investment Tax Credits shall |
17 |
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| equal the product of Amortization of Investment Tax Credits multiplied |
18 |
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| by the Gross Electric Plant Allocation Factor and further multiplied by |
19 |
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| the Gross Transmission Plant Allocation Factor. |
20 | Transmission Operation and Maintenance |
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21 | Operation and Maintenance |
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| $0 | FF1 321.112b | 9.2.E. | Transmission Operation and Maintenance Expense shall equal |
22 | less Load Dispatching - #561 |
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| $0 | FF1 321.84-92b |
| the sum of electric expenses as recorded in |
23 | O&M (Line 21 - Line 22) | $0 |
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| $0 |
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| FERC Account Nos. 560, 562-574. |
24 |
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25 | Transmission Administrative and General |
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| 9.2.F. | Transmission Related Administrative and General Expenses shall | |
26 | Total Administrative and General |
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| FF1 323.197b |
| equal the product of electric Administrative and General Expenses, |
27 | less Property Insurance (#924) |
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| FF1 323.185b |
| excluding the sum of Electric Property Insurance, Electric Research and |
28 | less Pensions and Benefits (#926) |
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| FF1 323.187b |
| Development Expense and Electric Environmental Remediation Expense, |
29 | less: Research and Development Expenses (#930) | $0 |
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| Workpaper 12, Line 3 |
| and 50% of the NYPSC Regulatory Expense |
30 | Less: 50% of NY PSC Regulatory Expense |
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| FF1 351.4h |
| multiplied by the Transmission Wages and Salaries Allocation Factor, |
31 | less: Environmental Remediation Expense | $0 |
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| Workpaper 11, Line 3 |
| plus the sum of Electric Property Insurance multiplied by the Gross |
32 | Subtotal (Line 26-27-28-29-30-31) | $0 | 100.0000% | $0 | 13.0000% (c) | $0 |
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| Transmission Plant Allocation Factor, plus transmission-specific Electric |
33 | PLUS Property Insurance alloc. using Plant Allocation | $0 | 100.0000% | $0 | #DIV/0! (d) | #DIV/0! | Line 27 |
| Research and Development Expense, and transmission-specific |
34 | PLUS Pensions and Benefits | $88,644,000 | 100.0000% | $88,644,000 | 13.0000% (c) | $11,523,720 | Workpaper 3 |
| Electric Environmental Remediation Expense. In addition, Administrative |
35 | PLUS Transmission-related research and development | $0 |
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| $0 | Workpaper 12 |
| and General Expenses shall exclude the actual Post-Employment |
36 | PLUS Transmission-related Environmental Expense | $0 |
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| $0 | Workpaper 11 |
| Benefits Other than Pensions ("PBOP") included in FERC Account 926, |
37 | Total A&G (Line 32+33+34+35+36) | $88,644,000 |
| $88,644,000 |
| #DIV/0! |
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| and shall add back in the amounts shown on Workpaper 3, page 1, |
38 |
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| or other amount subsequently approved by FERC under Section 205 or 206. |
39 | Payroll Tax Expense |
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| 9.2.G. | Transmission Related Payroll Tax Expense shall equal the product of |
40 | Federal Unemployment |
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| FF1 263.4i |
| electric Payroll Taxes multiplied by the Transmission Wages and |
41 | FICA |
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| FF1 263.3i |
| Salaries Allocation Factor. |
42 | State Unemployment |
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| FF1 263.17i |
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43 | Total (Line 40+41+42) | $0 | 100.0000% | $0 | 13.0000% (b) | $0 |
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| Allocation Factor Reference |
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| (a) Schedule 5, line 1 |
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| (b) Schedule 5, line 32 |
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| (c) Schedule 5, line 3 |
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| (d) Schedule 5, line 19 |
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Niagara Mohawk Power Corporation |
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| Attachment 1 | |||
Annual Revenue Requirements of Transmission Facilities |
| Schedule 10 | ||||
Billing Adjustments, Revenue Credits, Rental Income |
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| 0 |
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| Attachment H Section 14.1.9.2 (a) |
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| Shading denotes an input |
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Line No. |
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| (1) Total | Source |
| Definition |
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1 |
| Billing Adjustments |
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| 9.2.H. | Billing Adjustments shall be any adjustments made in accordance with Section 14.1.9.4.4 below. |
2 |
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3 |
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4 |
| Bad Debt Expense | $0 | Workpaper 4, Line 4 | 9.2.I. | Transmission Related Bad Debt Expense shall equal |
5 |
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| Bad Debt Expense as reported in Account 904 related to NMPC's wholesale transmission billing. |
6 |
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7 |
| Revenue Credits | $0 | Workpaper 5, Line 11 | 9.2.J. | Revenue Credits shall equal all Transmission revenue recorded in FERC account 456 |
8 |
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| excluding (a) any NMPC revenues already reflected in the WR, CRR, SR, ECR and Reserved |
9 |
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| components in Attachment H of the NYISO TSC rate; (b) any revenues associated |
10 |
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| with expenses that have been excluded from NMPC’s revenue requirement; and (c) any |
11 |
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| revenues associated with transmission service provided under this TSC rate, for which the |
12 |
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| load is reflected in the calculation of BU. |
13 |
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14 |
| Transmission Rents | $0 | Workpaper 7 | 9.2.K. | Transmission Rents shall equal all Transmission-related rental income recorded in FERC |
15 |
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| account 454.615 |
16 |
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17 |
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| 9.4(d) |
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18 |
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| 1 | Any changes to the Data Inputs for an Annual Update, including but not limited to |
19 |
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| revisions resulting from any FERC proceeding to consider the Annual Update, or |
20 |
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| as a result of the procedures set forth herein, shall take effect as of the beginning |
21 |
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| of the Update Year and the impact of such changes shall be incorporated into the |
22 |
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| charges produced by the Formula Rate (with interest determined in accordance |
23 |
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| with 18 C.F.R. § 38.19(a)) in the Annual Update for the next effective Update |
24 |
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| Year. This mechanism shall apply in lieu of mid-Update Year adjustments and |
25 |
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| any refunds or surcharges, except that, if an error in a Data Input is discovered |
26 |
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| and agreed upon within the Review Period, the impact of such change shall be |
27 |
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| incorporated prospectively into the charges produced by the Formula Rate during |
28 |
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| the remainder of the year preceding the next effective Update Year, in which case |
29 |
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| the impact reflected in subsequent charges shall be reduced accordingly. |
30 |
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| 2 | The impact of an error affecting a Data Input on charges collected during the |
31 |
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| Formula Rate during the five (5) years prior to the Update Year in which the error |
32 |
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| was first discovered shall be corrected by incorporating the impact of the error on |
33 |
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| the charges produced by the Formula Rate during the five-year period into the |
34 |
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| charges produced by the Formula Rate (with interest determined in accordance |
35 |
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| with 18 C.F.R. § 38.19(a)) in the Annual Update for the next effective Update |
36 |
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| Year. Charges collected before the five-year period shall not be subject to correction. |
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(b) |
| List of Items excluded from the Revenue Requirement | Reason |
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| Niagara Mohawk Power Corporation |
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| Attachment 1 Schedule 11 Page 1 of 1 | |||||||
| System, Control, and Load Dispatch Expenses (CCC) |
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| Attachment H, Section 9.5 |
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| The CCC shall equal the annual Scheduling, System Control and Dispatch Costs (i.e., the transmission component of control center costs) as recorded in FERC Account 561 and its associated sub-accounts using information from the prior calendar year, excluding NYISO system control and load dispatch expense already recovered under Schedule 1 of the NYISO Tariff. | ||||||||||
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1 |
| Scheduling and Dispatch Expenses | 0 |
| Source | |||||||
2 |
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3 |
| Accounts | 561 | Load Dispatching |
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| FF1 321.84b | |||||
4 |
| Accounts | 561.1 | Reliability |
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| FF1 321.85b | |||||
5 |
| Accounts | 561.2 | Monitor and Operate Transmission System |
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| FF1 321.86b | |||||
6 |
| Accounts | 561.3 | Transmission Service and Schedule |
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| FF1 321.87b | |||||
7 |
| Accounts | 561.4 | Scheduling System Control and Dispatch |
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| FF1 321.88b | |||||
8 |
| Accounts | 561.5 | Reliability, Planning and Standards Development |
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| FF1 321.89b | |||||
9 |
| Accounts | 561.6 | Transmission Service Studies |
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| FF1 321.90b | |||||
10 |
| Accounts | 561.7 | Generation Interconnection Studies |
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| FF1 321.91b | |||||
11 |
| Accounts | 561.8 | Reliability, Planning and Standards Dev. Services |
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| FF1 321.92b | |||||
12 |
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13 |
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| Total Load Dispatch Expenses (sum of Lines 3 - 11) |
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| sum lines 3 - 11 | ||||||
14 |
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15 | Less Account 561 directly recovered under Schedule 1 of the NY ISO Tariff |
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16 |
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17 |
| Accounts | 561.4 | Scheduling System Control and Dispatch |
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| line 7 | |||||
18 |
| Accounts | 561.8 | Reliability, Planning and Standards Dev. Services |
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| line 11 | |||||
19 |
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| Total NYISO Schedule 1 |
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| line 17 + line 18 | ||||||
20 |
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21 |
| Total CCC Component |
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| line 13 - line 19 | ||||||
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Niagara Mohawk Power Corporation |
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| Attachment 1 Schedule 12 Page 1 of 1 |
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Billing Units - MWH |
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Attachment H, Section 9.6 |
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| BU shall be the total Niagara Mohawk load as reported to the NYISO for the calendar billing year prior to the Forecast Period, including the load for customers taking service under Niagara Mohawk’s TSC Rate. The total Niagara Mohawk load will be adjusted to exclude (i) load associated with wholesale transactions being revenue credited through the WR, CRR, SR, ECR and Reserved components of Workpaper H of the NYISO TSC rate including Niagara Mohawk’s external sales, load associated with grandfathered OATT agreements, and any load related to pre-OATT grandfathered agreements; (ii) load associated with transactions being revenue credited under Historical TRR Component J; and (iii) load associated with netted station service. |
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Line No. |
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| Dec 06- Nov 07 |
| SOURCE | ||
1 |
| Subzone 1 |
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| NIMO TOL (transmission owner load) | ||
2 |
| Subzone 2 |
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| NIMO TOL (transmission owner load) | ||
3 |
| Subzone 3 |
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| NIMO TOL (transmission owner load) | ||
4 |
| Subzone 4 |
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| NIMO TOL (transmission owner load) | ||
5 |
| Subzone 29 |
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| NIMO TOL (transmission owner load) | ||
6 |
| Subzone 31 |
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| NIMO TOL (transmission owner load) | ||
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7 |
| Total NIMO Load report to NYISO |
| 0.000 |
| sum lines 1-6 | ||
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8 |
| LESS: All non-retail transactions |
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9 |
| Watertown |
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| FF1 page 329.11.j | ||
10 |
| High Load Factor Fitzpatrick |
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| NIMO TOL (transmission owner load) | ||
11 |
| Disputed Station Service |
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| NIMO TOL (transmission owner load) | ||
12 |
| Other non-retail transactions |
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| All other non-retail transactions (Sum of 300,000 series PTID's from TOL) | ||
13 |
| Total Deductions |
| 0.000 |
| sum lines 9 - 12 | ||
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14 |
| PLUS: TSC Load |
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15 |
| NYMPA Muni's, Misc. Villages, Jamestown (X1)** |
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| FF1 page 329.19.j **** | ||
16 |
| NYPA Niagara Muni's (X2) |
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| FF1 page 329.1.j **** | ||
17 |
| Total additions |
| 0.000 |
| sum lines 15 -17 | ||
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18 |
| Total Billing Units |
| 0.000 |
| line 7 - line 13 + line 18 | ||
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****
|
| In 2007, the volumes were not detailed in FERC Form 1 as shown. Detail for 2007 will be provided as requested. On 8/31/07, the contracts for Jamestown and the NYPA Niagara Municipal expired. The previous contract was billed at demand. The 2007 energy values for the NYPA Niagara Municipals and Jamestown are proxy numbers representing a full year of metered load for December 2006 - November 2007 as billed in January - December. These entities transitioned to the TSC rate on September 1, 2007 for billing effective October 2007. However, the full year billing load was included above. | ||||||
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** |
| One of the Misc Villages at Line 15 is reported on the TOL file with one of the NYPA Niagara Muni's labeled X2. | ||||||
Effective Date: 6/30/2010 - Docket #: ER10-1657-000 - Page 1
NYISO Tariffs --> Open Access Transmission Tariff (OATT) --> 14 OATT Attachment H - Annual Transmission Revenue Requireme --> 14.2 OATT Att H Attachment 1 to Att H - NYPA Transmission A
Each month, the ISO shall charge, and each Transmission Customer shall pay, the applicable NYPA Transmission Adjustment Charge (“NTAC”) calculated in accordance with Section 14.1.2.2 of this Attachment for the first two (2) months of LBMP and in accordance with Section 14.1.2.1 of this Attachment thereafter. The NTAC shall apply to Transmission Service:
14.2.2.1.1from one or more Interconnection Points between the NYCA and another Control Area to one or more Interconnection Points between the NYCA and another Control Area (“Wheels Through”);[1] or
14.2.2.1.2from the NYCA to one or more Interconnection Points between the NYCA and another Control Area, including transmission to deliver Energy purchased from the LBMP Market and delivered to such a Control Area Interconnection (“Exports”);1 or
14.2.2.1.3to serve Load within the NYCA.
In summary the NTAC will be applied to all Energy Transactions, including internal New York State Loads and Wheels Through and Exports out of the NYCA at a uniform, non-discountable rate.
Beginning with January 2001, NYPA shall calculate the NTAC applicable to Transmission Service to serve New York State Load, Wheels Through and Exports as follows:
NTAC = {(RR12) - (EA) - (IR12) - SR - CRN - WR - ECR - NR - NT}/(BU12)
Where:
RR=NYPA’s Annual Transmission Revenue Requirement, which includes the Scheduling, System Control and Dispatch Costs of NYPA’s control center, as approved by FERC;
EA=Monthly Net Revenues from Modified Wheeling Agreements, Facility Agreements and Third Party TWAs, and Deliveries to directly connected Transmission Customers;
SR=SR1 + SR2
SR1 will equal the revenues from the Direct Sale by NYPA of Original Residual TCCs, and Grandfathered TCCs associated with ETAs, the expenses for which are included in NYPA’s Revenue Requirement where NYPA is the Primary Owner of said TCCs.
SR2 will equal NYPA’s revenues from the Centralized TCC Auction allocated pursuant to Attachment M; this includes revenues from: (a) TCCs associated with Residual Transmission Capacity that are sold in the Centralized TCC Auction; and (b) the sale of Grandfathered TCCs associated with ETAs, if the expenses for these ETAs are included in NYPA's Revenue Requirement.
Revenue from TCCs associated with Residual Transmission Capacity includes payments for Original Residual TCCs that the Transmission Providers sell through the Centralized TCC Auction and the allocation of revenue for other TCCs sold through the Centralized TCC Auction (per the Facility Flow-Based Methodology described in Attachment N).
SR1 shall be updated prior to the start of each month based on actual data for the calendar month prior to the month in which the adjustment is made (i.e., January actual data will be used in February to calculate the NTAC effective in March). SR1 for a month in which a Direct Sale is applicable shall equal the total nominal revenue that NYPA will receive under each applicable TCC sold in a Direct Sale divided by the duration of the TCC (in months).
SR2 shall equal the Transmission Owner’s share of Net Auction Revenue for all rounds of a Centralized TCC Auction, as calculated pursuant to Attachment N, divided equally among the months covered by the Centralized TCC Auction. SR2 shall be adjusted after each Centralized TCC Auction, and the revised SR2 shall be effective at the start of each Capability Period;
ECR= NYPA's share of Net Congestion Rents in a month, calculated pursuant to Attachment N. The computation of ECR is exclusive of any Congestion payments or Rents included in the CRN term;
CRN= Monthly Day-Ahead Congestion Rents in excess of those required to offset Congestion paid by NYPA’s SENY governmental customers associated with the NYPA OATT Niagara/St. Lawrence Service reservations, net of the Initial Cost.
IR= A. The amount that NYPA will credit to its RR assessed to the SENY Load on account of the foregoing NYPA Niagara/St. Lawrence OATT reservations for SENY governmental customers. Such annual revenues will be computed as the product (“Initial Cost”) of NYPA’s current OATT system rate of $2.23 per kilowatt per month and the 600 MW of TCCs (or the amount of TCCs reduced by Paragraph C below). In the event NYPA sells these TCCs (or any part thereof), all revenues from these sales will offset the NTAC and the Initial Cost will be concomitantly reduced to reflect the net amount of Niagara/St. Lawrence OATT Reservations, if any, retained by NYPA for the SENY Load. The parties hereby agree that the revenue offset to NTAC will be the greater of the actual sale price obtained by NYPA for the TCCs sold or that computed at the applicable system rate in accordance with Paragraph B below;
B. The system rate of $2.23 per kilowatt per month will be benchmarked to the RR for NYPA transmission initially accepted by FERC (“Base Period RR”) for the purposes of computing the Initial Cost. Whenever an amendment to the RR is accepted by FERC (“Amended RR”), the system rate for the purpose of computing the Initial Cost will be increased (or decreased) by the ratio of the Amended RR to the Base Period RR and the effect of Paragraph A on NTAC will be amended accordingly.
C. If prior to the Centralized TCC Auction all Grandfathered Transmission Service including NYPA's 600 MW Niagara/St. Lawrence OATT reservations held on behalf of its SENY governmental customers are found not to be feasible, then such OATT reservations will be reduced until feasibility is assured. A reduction, subject to a 200 MW cap on the total reduction as described in Attachment M, will be applied to the NYPA Niagara/St. Lawrence OATT reservations held on behalf of its SENY governmental customers.
WR= NYPA’s revenues from external sales (Wheels Through and Exports) not associated with Existing Transmission Agreements in Attachment L, Tables 1 and 2 and Wheeling revenues from OATT reservations extending beyond the start-up of the ISO;
NR= NYPA Reserved1 + NYPA Reserved2
NYPA Reserved1 will equal NYPA’s Congestion payments for a month received pursuant to Section 20.2.3 of Attachment N of this Tariff for NYPA’s RCRR TCCs. NYPA Reserved2 will equal the value that NYPA receives for the sale of RCRR TCCs in a month, with the value for each RCRR TCC sold divided equally over the months remaining until the expiration of that RCRR TCC.
NT= The amount of actual NYPA transmission revenues minus NYPA’s monthly revenue requirement.
BU= Annual Billing Units are New York State Loads and Loads associated with Wheels Through and Exports in megawatt-hours (“MWh”).
The RR and SR will not include expenses for NYPA’s purchase of TCCs or revenues from the sale of such purchased TCCs or from the collection of Congestion Rents for such TCCs.
The ECR, EA, CRN, WR, NR, and NT shall be updated prior to the start of each month based on actual data for the calendar month prior to the month in which the adjustment is made (i.e., January actual data will be used in February to calculate the NTAC effective in March).
The NTAC shall be calculated as a $/MWh charge and shall be applied to Actual Energy Withdrawals, except for Wheels Through and Exports in which case the NTAC shall be applied to scheduled Energy quantities. The NTAC shall not apply to scheduled quantities that are Curtailed by the ISO.
At the start of LBMP implementation certain variables of the NTAC equation will not be available. For the first and second months of LBMP implementation, the only terms in the NTAC equation that will be known by NYPA are its historical Annual Transmission Revenue Requirement (RR) and the historical Billing Units (BU), which have been approved by or filed with FERC. For these two months NYPA shall calculate the NTAC using the following equation:
NTAC = {(RR12) - (EA) - (IR12)}/(BU12)
SR2 shall not be available until after the first Centralized TCC Auction. For the third month of LBMP implementation until the second month of the Capability Period corresponding to the first Centralized TCC Auction, NYPA shall recalculate the NTAC using the following equation:
NTAC = {(RR12) - (EA) - (IR12) - WR - CRN - SR1 - ECR}/(BU12)
Prior to and during implementation of LBMP those current NYPA transmission customers wishing to terminate their Third Party TWAs shall notify the ISO. The ISO shall duly inform NYPA of such conversion so that NYPA can calculate revenues (EA) to be derived from Existing Transmission Wheeling Agreements.
14.2.2.2.2.1NYPA’s recovery pursuant to NTAC initially is limited to expenses and return associated with its transmission system as that system exists at the time of FERC approval of the NTAC (“base period revenue requirement”). Additions to its system may be included in the computation of NTAC only if: a) upgrades or expansions do not exceed $5 million on an annual basis; or b) such upgrades or expansions have been unanimously approved by the Transmission Owners. Notwithstanding the above, NYPA may invest in transmission facilities in excess of $5 million annually without unanimous Transmission Owners’ authorization outside the NTAC recovery mechanism. In that case, NYPA cannot recover any expenses or return associated with such additions under NTAC and any TCC or other revenues associated with such additions will not be considered NYPA transmission revenue for purposes of developing the NTAC nor be used as a credit in the allocation of NTAC to transmission system users.
NYPA shall coordinate with the ISO to update certain components of the NTAC formula on a monthly or Capability Period basis. NYPA may update the NTAC calculation to change the RR, initially approved by FERC, and such updates shall be submitted to FERC. An integral part of the agreement between the other Transmission Owners and NYPA is NYPA’s consent to the submission of its RR for FERC review and approval on the same basis and subject to the same standards as the Revenue Requirements of the Investor-Owned Transmission Owners. Each January, beginning with January 2001, the ISO shall inform NYPA of the prior year’s actual New York internal Load requirements and the actual Wheels Through and Exports and shall post this information on the OASIS. NYPA shall change the BU component of the NTAC formula to reflect the prior calendar year’s information, with such change to take effect beginning with the March NTAC of the current year. NYPA will calculate the monthly NTAC and provide this information to the ISO by no later than the fourteenth day of each month, for posting on the OASIS to become effective on the first day of the next calendar month. Beginning with LBMP implementation, the monthly NTAC shall be posted on the OASIS by the ISO no later than the fifteenth day of each month to become effective on the first day of the next calendar month.
NYPA’s Annual Transmission Revenue Requirement (RR), for facilities owned as of January 31, 1997, and Annual Billing Units (BU) of the NTAC are:
RR = $165,449,297
BU = 133,386,541MWh
NYPA’s Annual Transmission Revenue Requirement is subject to Commission approval in accordance with Section 14.2.3 of this Attachment.
The New York State Loads, Wheels Through, and Exports will be billed based on the product of: (i) the NTAC; and (ii) the Customer’s billing units for the month. The billing units will be based on the monthly metered energy for all Transactions to supply Load in the NYCA, and hourly Energy schedules for all Wheels Through and Exports.
Effective Date: 6/30/2010 - Docket #: ER10-1657-000 - Page 1
[1] The NTAC shall not apply to Wheels Through or Exports scheduled with the ISO to destinations within the New England Control Area provided that the conditions listed in Section 2.7.2.1.4 of this Tariff are satisfied.