Attachment IV - Argonne Requirements and Schedule - A0002.pdf

ARGONNE NATIONAL LABORATORY

PRICING SHEET - Fixed Price

June 22, 2022

Local Distribution Company: Commonwealth Edison Company (“ComEd”)

Contract Term: 24-Month period from the meter read date occurring in the month of December 2022 through the meter read date occurring in the month of December 2024. Argonne is in ComEd meter group 20 and the December 2022 meter read date is on or about December 29, 2022.

Historical Annual Usage

Peak and off-peak hours are based on ComEd’s definition of Retail Peak Period and Retail Off-Peak Period in its terms and conditions. The Retail Peak Period is 9 AM to 10 PM, Monday through Friday, excluding defined holidays by the NERC. Retail Off-Peak Period is defined as all hours other than those included in the Retail Peak Period.

Contract Projected Usage

Beginning in October 2022, a new large-scale computer system is expected to come online over a 15-week period. Once online the additional computer demand may be as high as 57,600 KW and the additional load is expected to be about 200 Million KWH per year. These are the preliminary estimates.

The following table is a summary of the estimated load. Note that baseline usage is Argonne’s internal number representing annual usage before any deviations, such as weather or the new computer.

Capacity PLC Start Date End Date 32,657.12 6/1/2022 5/31/2023

Network Service PLC Start Date End Date

33,509.45 1/1/2022 12/31/2022

Billing Demand

Rate Code End Date Days On-Peak (a) Off-Peak Total (KW)

R67 5/25/2021 29 5,753,757 8,488,324 14,242,081 35,769 R67 6/24/2021 30 9,001,067 14,337,251 23,338,318 40,606 R67 7/26/2021 32 9,550,833 16,827,588 26,378,421 43,241 R67 8/24/2021 29 7,885,271 11,132,995 19,018,267 45,190 R67 9/23/2021 30 9,195,846 14,599,078 23,794,924 46,008 R67 10/26/2021 33 11,186,587 18,069,956 29,256,544 41,911 R67 11/22/2021 27 8,746,820 13,993,348 22,740,571 37,809 R67 12/27/2021 35 10,661,754 17,776,386 28,438,139 37,757 R67 1/27/2022 31 7,349,753 11,579,977 18,929,730 35,000 R67 2/25/2022 29 8,412,568 13,078,660 21,491,229 33,071 R67 3/28/2022 31 8,432,420 14,371,188 22,803,608 33,507 R67 4/29/2022 32 9,701,650 14,101,762 23,803,411 38,166 Totals: 105,878,326 168,356,513 274,235,243

Monthly Usage (KWH)Billing Period

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SPE60422R0406

ANL Pricing Submittal

Fixed Price Components

A. Fixed Peak Price: _______ cents per kWh B. Fixed Off-Peak Price: _______ cents per kWh

The Fixed Energy Prices are to be based on ComEd peak and off-peak periods and must include ALL PJM ancillary service and ISO related costs not identified in the Pass- Through Components.

Defined peak and off-peak hours are based on ComEd’s definition of Retail Peak Period and Retail Off-Peak Period in its terms and conditions. Retail Peak Period is defined as 9 AM to 10 PM, Monday through Friday, except on days designated as holidays by the NERC. Retail Off-Peak Period is defined as all hours other than those included in the Retail Peak Period.

Pass-Through Components

1. PJM Transmission Costs: Direct pass-through of PJM Network Integration Transmission Service Rate (“NITS”) for Commonwealth Edison Company based on Argonne’s Network Service PLC.

Formula:

Daily NITS Charge ($) = Annual NSPL Tag (MW) * Daily Zonal NSPL Scaling Factor

* Daily Zonal NITS Rate ($/MW-day)

Daily TEC Charge ($) = Annual NSPL Tag (MW) * Daily Zonal NSPL Scaling Factor *

Daily Zonal TEC Rate ($/MW-day)

ARGONNE NATIONAL LABORATORY

ESTIMATED LOAD FOR APS SHUTDOWN AND NEW COMPUTER

Contract Start: January 2023 (with Dec-22 Meter Read)

Historical Total New Source 1 Source 2 New Computer Total Load Factor New Load Baseline Contract KWH Computer Deviation Baseline Max. KW

Jan-23 31 31.4 31.4 0.75 17,493,300 13,955,581 31,448,881 56,600 0 33,574 90,174 Feb-23 28 33.6 33.6 0.75 16,934,400 22,117,889 39,052,289 57,600 0 32,236 89,836 Mar-23 31 33.6 33.6 0.75 18,748,800 20,558,912 39,307,712 57,600 0 33,429 91,029 Apr-23 30 -3.5 -4.5 33.6 25.6 0.75 13,824,000 21,573,234 35,397,234 57,600 -8 34,849 92,441 May-23 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 15,473,751 29,758,551 57,600 -8 34,124 91,716 Jun-23 30 -3.5 -4.5 33.6 25.6 0.75 13,824,000 23,811,283 37,635,283 57,600 -8 39,595 97,187 Jul-23 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 28,182,117 42,466,917 57,600 -8 45,333 102,925

Aug-23 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 27,399,913 41,684,713 57,600 -8 44,440 102,032 Sep-23 30 -3.5 -4.5 33.6 25.6 0.75 13,824,000 19,658,036 33,482,036 57,600 -8 36,571 94,163 Oct-23 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 21,481,377 35,766,177 57,600 -8 39,236 96,828 Nov-23 30 -3.5 -4.5 33.6 25.6 0.75 13,824,000 24,335,835 38,159,835 57,600 -8 37,578 95,170 Dec-23 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 19,516,964 33,801,764 57,600 -8 36,311 93,903 Jan-24 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 13,955,581 28,240,381 57,600 -8 33,574 91,166 Feb-24 28 -3.5 -4.5 33.6 25.6 0.75 12,902,400 22,117,889 35,020,289 57,600 -8 32,236 89,828 Mar-24 31 -3.5 -4.5 33.6 25.6 0.75 14,284,800 20,558,912 34,843,712 57,600 -8 33,429 91,021 Apr-24 30 33.6 33.6 0.75 18,144,000 21,573,234 39,717,234 57,600 0 34,849 92,449 May-24 31 33.6 33.6 0.75 18,748,800 15,473,751 34,222,551 57,600 0 34,124 91,724 Jun-24 30 33.6 33.6 0.75 18,144,000 23,811,283 41,955,283 57,600 0 39,595 97,195 Jul-24 31 33.6 33.6 0.75 18,748,800 28,182,117 46,930,917 57,600 0 45,333 102,933

Aug-24 31 33.6 33.6 0.75 18,748,800 27,399,913 46,148,713 57,600 0 44,440 102,040 Sep-24 30 33.6 33.6 0.75 18,144,000 19,658,036 37,802,036 57,600 0 36,571 94,171 Oct-24 31 33.6 33.6 0.75 18,748,800 21,481,377 40,230,177 57,600 0 39,236 96,836 Nov-24 30 33.6 33.6 0.75 18,144,000 24,335,835 42,479,835 57,600 0 37,578 95,178 Dec-24 31 33.6 33.6 0.75 18,748,800 19,516,964 38,265,764 57,600 0 36,311 93,911

Total 387,688,500 516,129,784 903,818,284

Calendar Yr 2023 179,896,500 258,064,892 437,961,392 Calendar Yr 2024 207,792,000 258,064,892 465,856,892

Annual KWH Increase over Base Baseline Usage 258,064,892 Year 2023 with New Computer 437,961,392 179,896,500 Year 2024 with New Computer 465,856,892 207,792,000

PRELIMINARY ESTIMATES

Monthly Peak Demands (KW)Monthly KWH Deviation from Baseline Load (MW)

PJM NITS subject to change each June 1 and Argonne’s PLC subject to change each January 1. Invoice costs should be prorated when costs change during a billing cycle.

All other transmission related costs, including enhancement charges, must be included in the Fixed Energy Price.

2. PJM Capacity Costs: Direct pass-through of PJM Capacity Rate for the ComEd zone . Daily charge is to be assessed during monthly billing period based on Argonne’s Capacity PLC assigned by ComEd.

All other capaity related costs must be included in the Fixed Energy Price.

PJM capacity price, scaling factors, pooling requirements, and Argonne PLC subject to change each June 1. Invoice costs should be prorated when costs change during a billing cycle.

3. ComEd Distribution and Transmission Losses: Direct pass-through of Day-Ahead price losses. Losses are to appear as an additional line item on the invoice submitted to Argonne.

ComEd’s 2022 tariff distribution loss (“DLF)” and transmission loss (“TLF”) factors are 0.72% and 1.60%, respectively. The combined loss factor is 2.33% [(1 + 0.0072) x (1 + 0.0160) = 1.0233].

Formula:

2.16% x ComEd metered kWh x weighted average Commodity Price in the billing period.

All other loss related cost components must be included in the Fixed Peak and Off-Price prices. This includes ComEd’s Unaccounted For Energy (“UFE”) and PJM’s loss deration.

4. Direct Pass-Through Reliability Must Run and FERC Order 745:

Direct pass-through of these charges only if they apply to the ComEd zone.

Daily Capacity Charge ($) = Annual PLC Tag (MW) * Final Zonal RPM Scaling Factor * Forecast Pool Requirement * Daily Zonal Capacity Scaling Factor * Final Zonal Capacity Price ($/MW-Day)

Where:

Annual PLC tag is the capacity tag assigned to each account by the EDC for each PJM delivery year (June 1st through May 31st).

Final Zonal RPM Scaling Factor, Forecast Pool Requirement, Daily Zonal Capacity Scaling Factors, and Final Zonal Capacity Prices are as published on PJM’s website.

Where:

Annual NSPL tag is the transmission tag assigned to each account by the EDC for each calendar year.

Daily Zonal NITS Rate = Annual Zonal NITS Rate (as published on PJM’s website) divided by the number of days in the year.

Daily Zonal TEC Rate = Annual Zonal TEC Rate (as published on PJM’s website) divided by the number of days in the year.

Daily Zonal NSPL Scaling Factors are as published on PJM’s website.

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APPENDIX I

EXPECTED INVOICE COMPONENTS AND FORMAT

kWh $ per kWh ComEd Metered kWh xxx,xxx,xxx (a)

Contract Peak Energy Charge $x.xxxx $xxx,xxx.xx (b) Contract Off-Peak Energy Charge $x.xxxx $xxx,xxx.xx (c) Total Contract Energy Charge $xxx,xxx.xx (d = b+c)

Line Losses @ x.xx% xx,xxx $xx,xxx.xx (e=average commodity cost * a * x.xx%)

Transmission Charge $xxx,xxx.xx (f = per Contract formula) Argonne Network PLC x Annual NITS / 366 Days x Days in Period

Capacity Charge $xxx,xxx.xx (g = per Contract formula) Argonne Capacity PLC x Zonal Adj. x Scaling Adj. x Capacity Price x Days in Period

Reliability Must Run Charge $xx,xxx.xx (h)

FERC 745 $xx,xxx.xx (i)

Total Invoice $x, xxx,xxx.xx (sum a through i)

Total $

Fixed Price Components