AVAILABILITY:
This schedule applies to Customers with electrical use above 5 annual average megawatts (aMWs), or as warranted by special circumstances notwithstanding that another rate schedule might otherwise apply, and is available throughout the District’s
service area with the exception of the Stehekin area. Service under this schedule will require a written contractual arrangement ("Contract") between the Customer and the District prior to connection of Service that will address any special circumstances
and conditions applicable to the Customer’s Energy needs.
The Customer is responsible for procuring, installing and maintaining all necessary wiring, transformers, switches, cut-outs and protection equipment beyond the Point of Delivery, with such service facilities and equipment being of a type and character
acceptable to the District. The entire service installation, protection coordination and the balance of the load between phases is subject to approval by the District.
RATES, TERMS AND CONDITIONS:
Rates, terms and conditions of Service will be established by Contract and will be at the District's sole discretion. Terms and conditions may include load following, load shaping, imbalance, firming, reactive power, voltage control, environmental attributes,
conservation requirements, duration, interruption, curtailment, credit requirements (including provision of financial statements), and other provisions relating to Service.
POWER SUPPLY:
Service is contingent on an executed Contract between the District and Customer, which will specify the terms of the power supply arrangement for Customer, and is limited to, availability of power supply, District transmission capabilities, and other
constraints identified by the District. The Contract will provide for procurement of power supply by the District. The Customer may identify power supply for consideration by the District, Power supply will be on terms acceptable to the District.
The District reserves the right to consider alternative arrangements for power supply. As specified by the Contract, all power supply must be of quality that meets District standards and satisfies applicable law, and Customer shall assume all costs
and mitigate all risks associated with the power supply to the District's satisfaction.
The power supply described above is intended to be the primary source of power for Customer. This rate schedule includes supplementary services including services associated with the Load Imbalance Charge and the Day-ahead Charge. In no event will such
supplementary services be the primary source of power to the Customer. In exercising its discretion to interrupt or curtail service as described in the District's Utility Service Regulations, the District may reduce or suspend the provisions of such
supplementary services to loads on this rate schedule before curtailing or interrupting service to other loads. Except as may be specifically provided in a Contract, in the event that supplementary service is reduced or suspended, the Customer shall
not be entitled to any compensation or reduction in charges and the District shall not be liable for any damages (including direct, indirect, consequential, or of any other nature) for such interruption or failure, nor shall such failure or interruption
be held to constitute a breach of Contract on the part of the District or in any way relieve the Customer from performing the obligations of the Customer's Contract.
SPECIFIC CHARGES:
Such Contract may incorporate one or more of the following charges by reference:
4.a Energy Capacity Charge. The energy capacity charge applies in all billings periods beginning with the first billing period in which Demand first exceeds 5000 kW. The charge is $10.93/kW of the
positive difference, if any, of 90% of the Demand minus the average demand during the billing period (which is the total delivered Energy for the billing period divided by the number of hours in the billing period).
4.b Load Imbalance Charge. The Load Imbalance Charge shall be determined by the District for each clock hour period as follows:
"Actual Load" means the average hourly Energy delivered to the Point of Delivery.
"Available Power Supply" means, unless otherwise provided by the Contract between Customer and the District, the Load Forecast plus the Forecast Reserve Amount.
"Forecast Reserve Amount" means an amount added by the District to the Load Forecast account for load forecast uncertainty and is determined at the District's sole discretion.
"Load Forecast" means, unless otherwise provided by Contract between Customer and the District, an hourly load forecast provided by the Customer to the District by 5:00 p.m. Pacific Time on each business day in the format specified by the District for
the seven days that start two days after the day the forecast is delivered. In the event the District does not receive a timely Load Forecast from Customer for a given day, the Load Forecast shall be the last forecast provided to the District for
that day, or if the Customer has not provided a forecast for that day, the Load Forecast shall be deemed zero for each hour.
"Load Imbalance Energy" means Actual Load minus Available Power Supply, expressed in kWhs.
A. If the Actual Load is less than or equal to the Load Forecast, then the Load Imbalance Charge is calculated summing the results of Step 1 and Step 2 below.
- Step 1. Forecast Reserve Amount multiplied by the applicable Deviation Band 1 Load Imbalance Price.
- Step 2. Multiply the different between the absolute value of the Load Imbalance energy and the Forecast Reserve Amount by the applicable Load Imbalance Price as determined by the Imbalance Deviation (%) and tables below where:
- Imbalance Deviation (%) = Absolute value of (Load Imbalance energy) / Available Power Supply.
B. If the Actual Load is greater than the Load Forecast, then the Load Imbalance Charge is calculated by:
Multiplying the Load Imbalance Energy by the applicable Load Imbalance Price as determined by the Imbalance Deviation (%) and tables below where:
- Imbalanced Deviation (%) = Absolute value of (Load Imbalance energy) / Available Power Supply
Applicable when the Hourly Index price is greater than or equal to $0.00/kWh:
| Imbalance Deviation (%) or Load Imbalance Energy (kWh) | Load Imbalance Price when Load Imbalance energy is negative (District will credit Customer for Load Imbalance energy) ($/kWh) | Load Imbalance Price when Load Imbalance energy is positive (Customer will pay District for Load Imbalance energy) ($/kWh) |
Deviation Band 1: If Imbalance Deviation (%) is less than or equal to 1.5% and the absolute value of the Load Imbalance energy is less than or equal to -2,000 kW | 90% of the Hourly Index | 110% of the Hourly Index |
Deviation Band 2: If Imbalance Deviation (%) is (i) greater than 1.5 percent or the absolute value of the Load Imbalance energy is more than 2,000 kW and (ii) less than or equal to 7.5% and the absolute value of the Load Imbalance energy is less than or
equal to 10,000 kW | 82.5% of the Hourly Index | 117.5% of the Hourly Index |
Deviation Band 3: If Imbalance Deviation (%) is greater than 7.5% or the absolute value of the Load Imbalance energy is greater than 10,000 kW | 75% of the Hourly Index | 125% of the Hourly Index |
*For any hour in which the District incurs spill at any of its hydroelectric projects and Actual Load is less than Available Power Supply, and the Load Imbalance Price is positive for an hour, the Load Imbalance price shall be $0.00.
Applicable when the Hourly Index is less than $0.00/kWh:
| Imbalance Deviation (%) or Load Imbalance energy (kWh) | Load Imbalance Price when Load Imbalance energy is negative (Customer will pay District for Load Imbalance energy) ($/kWh) | Load Imbalance Price when Load Imbalance energy is positive (Customer will pay District for Load Imbalance energy) ($/kWh) |
Deviation Band 1: If Imbalance Deviation (%) is less than or equal to 1.5% and the absolute value of the Load Imbalance energy is less than or equal to 2,000 kW | The absolute value of 110% of the Hourly Index | $0.004 |
Deviation Band 2: If Imbalance Deviation (%) is (i) greater than 1.5 percent or the absolute value of the Load Imbalance energy is more than 2,000 kW and (ii) less than or equal to 7.5% and the absolute value of the Load Imbalance energy is less than or
equal to 10,000 kW | The absolute value of 117.5% of the Hourly Index | $0.004 |
Deviation Band 3: If Imbalance Deviation (%) is greater than 7.5% or the absolute value of the Load Imbalance energy is greater than 10,000 kW | The absolute value of 125% of the Hourly Index | $0.006 |
A persistent deviation occurs if Customer engages in a pattern or providing Load Forecasts that result in deviations that are greater than 1.5% in one direction where deviations are calculated as the absolute value of the difference between the Actual
Load and Load Forecast, divided by Load Forecast. If the District, in its sole discretion, determines that the Load Forecasts results in a persistent deviation, the District may adjust the Forecast Reserves Amount and/or impose the Demand Exceedance
Charge and the Excess Energy Charge on all Load Imbalance energy in all relevant hours, notwithstanding that the Demand Exceedance Charge and Excess Energy Charge as if such deviations were in excess of Customer's maximum authorized demand.
In addition to the foregoing, ion the event the District procures or otherwise provides Customer with Energy to replace a quantity of Available Power Supply that was not delivered or otherwise made available to the District despite being expected to be
delivered as of the District's day-ahead transaction window, Customer will be charged for all costs, penalties, fines, and other expenses incurred by the District in providing such Energy.
Example Load Imbalance Calculations
Example 1: Load Imbalance Charge calculation:
Actual Load (kWh): 9,100
Load Forecast (kWh): 10,000
Forecast Reserve Amount (kWh): 500
Available Power Supply (kWh): 10,500
Load Imbalance energy (kWh): -1,400 (9,100 - 10,500) Actual Load is less than or equal to Load Forecast
Imbalance Deviation (%): 13% Absolute value (-1,400) / 10,500 kWh Deviation Band 3 applies
Hourly Index Price ($/kWh): $0.025
Step 1 ($): $11.25
500 (kWh) X $0.025 ($/kWh) X 90% (Deviation Band 1)
Step 2 ($): $16.88
(1,400 - 500) (kWh) X $0.025 ($/kWh) X 75% (Deviation Band 3)
Load Imbalance Charge ($) $28.13 (District pays Customer) ($11.25 + $16.88)
Example 2: Load Imbalance Charge calculation:
Actual Load (kWh): 10,200
Load Forecast (kWh): 10,000
Forecast Reserve Amount (kWh): 500
Available Power Supply (kWh): 10,500
Load Imbalance energy (kWh): -300 (10,200 - 10,500) Actual Load is greater than Load Forecast
Imbalance Deviation (%): 3% Absolute value (-300) / 10,500 kWh Deviation Band 2 applies
Hourly Index Price ($/kWh) $0.025
Load Imbalance Charge ($) $6.19 (District pays Customer)
300 (kWh)
X $0.025 ($/kWh) X 82.5% (Deviation Band 2)
Example 3: Load Imbalance Charge Calculation:
Actual Load (kWh): 11,300
Load Forecast (kWh): 10,000
Forecast Reserve Amount (kWh): 500
Available Power Supply (kWh): 10,500
Load Imbalance energy (kWh): 800 (11,300 - 10,000 -500) (Actual Load is greater than Load Forecast)
Imbalance Deviation (%) 8% Absolute value (800) / 10,500 kWh Deviation Band 3 applies
Hourly Index Price ($/kWh) $0.025
Load Imbalance Charge ($) $25.00 (Customer pays District)
(800 kWh)
X $0.025 ($/kWh) X 125% (Deviation Band 3)
4.c Load Following Charge. The load following charge applies in all billing periods beginning with the billing period in which Demand first exceeds 5000 kW. The charge is calculated by multiplying
$13.66 per load-following kilowatt by the maximum hourly load-following kilowatt amount in the billing period. The highest 1-minute demand minus the lowest 1-minute demand in each hour will establish the load-following kilowatt amount for that hour.
In calculating the maximum load-following kilowatt amount in the billing period, a change in Demand will not count towards the Load Following Charge if the change was in direct result of an interruption, suspension or curtailment directed or caused by
the District that was not due to the fault or unexcused nonperformance of Customer.
4.d Demand Exceedance Charge. In addition to all other rates and charges, in each billing period in which Demand exceeds the Service’s maximum authorized demand, Customer will be assessed $150
plus, for each day an exceedance occurs, 1.5 times the applicable demand charge on the amount by which the highest Demand in the day exceeded the maximum authorized demand. This charge is, in addition to, not exclusive of, the District's rights to
require additional protective measures, recover for damages sustained to the Electric Service Facilities, disconnect Service, remedies available by Contract, or take any other remedial action available to recover losses and prevent future exceedances.
4.e Excess Energy Surcharge. In addition to all other rates and charges, a surcharge of the greater of the highest energy charge applicable under the Contract or the Hourly Index price for each applicable
hour will apply to all Energy used within an hour in excess of the Customer's maximum authorized demand. Any surcharge is in addition to, not exclusive of, the District's rights to required additional protective measures, recover for damages sustained
to the Electric System, disconnect Service, remedies available by Contract, or take any other remedial action available to recover losses and prevent future exceedances.
4.f Scheduling Charge. The scheduling charge equals the total quantity of energy procured or reserved by the District for Service pursuant to the Contract (expressed in kWh) multiplied by $0.00644/kWh.
4.g Reserves Charge. The reserves charge equals $13.66/kW-month multiplied by 3.5% of the Demand (kW) for the billing period.
4.h Transmission Charge. The Transmission charge is $2.10/kW-month multiplied by the Customer's twelve-month coincidental peak (12CP). Customer's 12CP is set on July 1 of each year and equals the average
of the Customer's Demand coincident with the District's transmission system monthly peak in each month of the previous calendar year. Being assessed this charge does not make Customer a transmission customer of the District or grant any rights to
Customer with respect to the District's Open Access Transmission Tariff.
4.i Transmission Losses Charge. Transmission losses are financially settled with the District. The hourly transmission losses charge is calculated by multiplying the Transmission Loss Factor (%),
as set forth in the District's Transmission Rate Schedules, by the total energy usage (kWh) and the Hourly Index ($/kWh). The transmission losses charge is the sum of the hourly transmission losses charge for all hours during the delivery period.
4.j Basic Charge. The basic charge is, for each billing period, $0.10/kW multiplied by the amount in (kW), if any, by which Customer's maximum authorized demand exceeds 5,000 kW, plus $1,000.
4.k Power Factor Charge. A charge will be assessed in billing periods when the average power factor is less than 0.95 ("Power Factor Limit"). "Average Power Factor" is the average metered power factor over
the billing period or, if that is not available, is calculated as follows, where "kilowatt-hours" and "kilovolt-ampere-reactive-hours" are total amounts during the billing period.
The "PF Demand" equals the Demand multiplied by the Power Factor Limit divided by the Average Power Factor, then subtracting the Demand. The power factor charge equals the PF Demand multiplied by the applicable demand charge. For avoidance of doubt, in
no event will the power factor charge be negative.
4.l Day-Ahead Charge. The day-ahead charge is the Day Ahead Mid-C Peak Index Price or Day Ahead Mid-C Off Peak Index Price published by ICE. The day-ahead charge applies to day-ahead Energy adjustments as
specified by Contract. If ICE ceases to publish these indices that District, in its reasonable discretion, may select a replacement index.
A persistent deviation occurs if Customer's load forecasts used for day-ahead purchases are frequently greater than the primary power supply associated with Customer's load (minus any portion of the power supply required by the Contract to be reserved).
If the District, in its sole discretion, determines that the forecasts result in a persistent deviation, the District may adjust the forecasted amount and/or impose the Demand Exceedance Charge and the Excess Energy Charge on all day-ahead energy
in all relevant hours as if such deviations were in excess of Customer's maximum authorized demand.
4.m Liquidity Risk Charge. The liquidity risk charge equals all invoiced amounts in the billing period, except the Transaction Specific Charge (4.n), multiplied by the rate set forth in the level below
corresponding to the lowest Rating on the last day of the billing period.
| Level | Moody's Rating | S&P Rating | Fitch Rating | Rate |
| 1 | Aa3 or above | AA- or above | AA- or above | 0.50% |
| 2 | A3 to A1 | A- to A+ | A- to A+ | 0.75% |
| 3 | Baa3 to Baa1 | BBB- to BBB+ | BBB- to BBB+ | 1.50% |
| 4 | Below Baa3 | Below BBB- | Below BBB- | 3.00% |
Notwithstanding the foregoing, the liquidity risk charge will be calculated using the rate in level 4 of the table above if, as of the last day of the billing period, (i) a Rating is suspended, withdrawn, or otherwise unavailable from any Rating Agency
for a credit related reason; (ii) an event of default, as defined in the Contract, on the part of Customer has occurred and is ongoing; or (iii) less than two Rating Agencies have assigned a Rating to Customer. The term "Rating" means the unenhanced
long-term senior unsecured debt rating or issuer rating assigned by a Rating Agency to the Customer.
4.n Transaction Specific Charge. The Transaction Specific Charge equals all invoiced amounts in the billing period multiplied by a factor that is equivalent to 6.4 percent.
4.o Transitional Energy Service. Service under this Section 4.o is available exclusively where the District elects to continue service on a transitional basis to Customers that were served by Contract under
this Schedule 4 but for which the Contract has terminated while a replacement Contract is being negotiated. Service under this Section 4.o is not available to new Customers or to Customers that have not paid the required deposit. Transitional Energy
Service includes the following:
Transitional Energy Charge: The Day-Ahead Charge in Section 4.l plus $0.06887/kWh.
Transitional Demand Charge: $6.60/kW-month
Security Deposit: A security deposit will be required in the amount of the highest previous or projected monthly billed amount, multiplied by a factor of three (3). At the District's sole discretion, the
District may increase or decrease the security deposit in accordance with Section 8 of the Utility Service Regulations.
Interruption of Service: In exercising its discretion to interrupt service as described in the District's Utility Service Regulations, the District may prioritize interruption of service to loads taking
Transitional Energy Service ahead of other loads. In the event that service is interrupted or fails by reason of accident, energy scarcity, or any other cause whatsoever, the Customer shall not be entitled to any compensation or reduction in charges
and the District shall not be liable for any damages for such interruption or failure, nor shall such failure or interruption be held to constitute a breach of Contract on the part of the District or in any way relieve the Customer from performing
its obligations related to service. This limitation of liability includes all damages of any nature, including direct, indirect, or consequential.
Other Costs: All other costs of complying with, and costs reasonably attributable to noncompliance with, District Requirements related to providing Transitional Energy Service where "District Requirements"
means any law, regulation, rule, tariff, rate schedule, standard, procedure, order or other obligation or standard imposed on the District or Customer, and any policies of the District approved by District's Board of Commissioners and then in effect,
including in relation to capacity, resource adequacy, and environmental attributes.
Demand Limit: The demand limit for Transitional Energy Service will be the demand limit for Customer's service under the Contract as of the termination of the Contract. The demand limit is subject to change
in accordance with the District's Utility Service Regulations.
Other Rate Schedules: 4.b, 4.c, 4.d, 4.e, 4.f, 4.g, 4.i, 4.j, 4.k, 4.l, 4.m, and 4.n.
Definitions
"Fitch" means Fitch Ratings, Inc., or any successor thereto.
"Hourly Index" means the Powerdex Mid-Columbia Hourly Index. If the Powerdex Mid-Columbia Hourly Index ceases to be published or is no longer representative of the District's real-time purchases and sales, the District, in its reasonable discretion, may
select a replacement source for the Hourly Index.
"Moody's" means Moody's Ratings, or any successor thereto.
"Rating Agencies" means, collectively, Fitch, Moody's and S&P. If any Rating Agency is dissolved or liquidated or no longer performs the functions of a securities rating agency, it may be replaced by any other nationally recognized securities rating
agency designated by the District.
"Rating Agency" means any one of the Rating Agencies.
"S&P" means S&P Global Ratings, a Division of S&P Global, Inc., or any successor thereto.
CONTRACTS ENTERED INTO BEFORE FEBRUARY 19, 2019:
For Contracts that include a scheduling services charge and were executed prior to February 19, 2019, the scheduling services charge for Energy scheduled by the District is as follows:
Charges for energy scheduled by the District for the benefit of the Customer shall be as follows:
0.1 mills per kilowatt hour for energy from one month or longer block purchases from less than two suppliers;
0.2 mills per kilowatt hour if a one month or longer block is supplied from three or more suppliers.
For energy scheduled by the District in blocks of less than one month, the following rates shall apply to transactions for each day, and summed over the billing month:
0.25 mills per kilowatt hour for energy scheduled when the Intercontinental Exchange Mid-C Day-Ahead Peak (ICE Peak) index is greater than $0 but less than or equal to $50 per MWH;
0.50 mills per kilowatt hour for energy scheduled when the ICE Day Ahead Peak index exceeds $50 but is less than or equal to $100;
0.75 mills per kilowatt hour for energy scheduled when the ICE Day Ahead Peak index exceeds $100.
TAX ADJUSTMENT:
The amount of any tax levied on the service by any state, city or town or other jurisdictional entity in accordance with R.C.W. 54.28.070 or other applicable law will be added to the charges.
SERVICE POLICY:
Service under this schedule is subject to all the rules and regulations as set forth in the District’s Utility Service Regulations..
EFFECTIVE: August 1, 2025