Attachment_IV_-_Argonne_Pricining_And_Invoice_Requirements.pdf

ARGONNE NATIONAL LABORATORY

PRICING SHEET - Fixed Price

June 2, 2016

Contract Term: See DLA solicitation for contract term. Meter reading schedule is Meter Bill Group 20.

Estimated Annual Usage

Beginning June 2016, an on-site six (6) MW combustion turbine generator (“CHP”) started operation and will ramp up to full operation by fall. The forgoing usage estimate represents purchased electricity.

Peak and off-peak hours are based on Commonwealth Edison Company’s (“ComEd’s”) definition of Retail Peak Period and Retail Off-Peak Period in its terms and conditions. Retail Peak Period is defined as 9AM to 10PM, 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.

Fixed Price Components

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

The Fixed Energy Prices should 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. Market based Renewable Portfolio Standard costs and transmission enhancement charges must also be included on the Fixed Energy Prices.

Argonne expects bidders to recognize the benefits for the credits obtained for marginal transmission losses, ARR and zonal derates and include them in the Fixed Energy Prices.

Estimated Estimated CHP ComEd/Supplier

Ending Period Days Peak Off-Peak Total Peak kW Max kW Net Production Purchases 1/28/2016 31 8,137,302 12,373,865 20,511,167 38,629 38,629 4,970,085 15,541,082 2/26/2016 29 10,110,263 15,239,276 25,349,539 39,601 39,601 4,429,699 20,919,840 3/28/2016 31 10,068,042 16,755,794 26,823,836 39,186 39,186 4,699,725 22,124,111 4/28/2016 31 11,059,843 15,962,629 27,022,472 40,538 40,538 3,339,443 23,683,029 5/29/2015 32 9,631,434 14,397,454 24,028,888 42,995 42,995 4,313,944 19,714,944 6/29/2015 31 11,483,672 18,654,819 30,138,491 49,258 49,258 3,970,924 26,167,567 7/29/2015 30 11,495,474 18,178,996 29,674,470 49,095 49,095 3,991,952 25,682,518 8/27/2015 29 11,585,009 17,476,995 29,062,004 48,256 48,256 4,078,545 24,983,459 9/28/2015 32 8,535,422 14,393,797 22,929,219 40,179 40,179 4,076,042 18,853,177

10/23/2015 25 9,346,358 12,718,296 22,064,654 43,704 43,704 3,445,921 18,618,733 11/23/2015 31 10,175,849 16,985,433 27,161,282 40,381 40,381 4,529,105 22,632,177 12/28/2015 35 11,207,601 19,307,886 30,515,487 41,547 41,547 4,947,785 25,567,702

122,836,269 192,445,240 315,281,509 50,793,170 264,488,339

Historical kWh Usage

Solicitation # Fixed Price ANL Pricing Submittal

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:

Argonne Network PLC x Annual NITS ÷ 365 Days = Daily Price

Current Cost: 43.049 MW x $35,451 per MW per year ÷ 365 = $4,181.18 per day

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

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

Monthly invoice price should be pro-rated if transmission rate or ANL PCL changes during a billing period.

2. PJM Capacity Costs: Direct pass-through of PJM Capacity Rate for Commonwealth Edison

Company based on Argonne’s Capacity PLC. Daily charge will be assessed during monthly billing period based on the PJM Locational Reliability Charge and Argonne’s Capacity PLC assigned by ComEd.

Formula:

Current Argonne’s Capacity PLC MW 45.05 MW

Zonal Scaling Factor Adjustment x 1.05292

FPR Pool Requirement Adjustment x 1.09520

Adjusted Capacity MW: = 51.95

June 1, 2016 PJM Auction Price : $101.55 MW

Current Daily Capacity Cost: = $5,275.52 per day

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

3. Loss Factors: Direct pass-through of distribution and transmission losses.

4. Renewable Portfolio Standard (RPS): Direct pass-through of only the minimum applicable

Illinois Power Agency Alternative Compliance Payment (ACP).

Formula: ACP Rate in $/kWh times 50% of Argonne’s ComEd metered kWh

The market based non-ACP portion of supplier RPS costs must be included in the Fixed Energy Prices.

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

Argonne understands that RMR charges are currently zero for the ComEd zone.

Solicitation # Fixed Price ANL Pricing Submittal

APPENDIX I

EXPECTED INVOICE 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 Netw ork PLC x Annual NITS / 365 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

RPS - Alternative Compliance Payment $xx,xxx.xx (h = per Contract formula) ACP Rate in $/kWh x Argonne ComEd metered kWh x 50%

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

FERC 745 $xx,xxx.xx (j)

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

Total $

Fixed Price Components