Topic:"Cost To Customer" in M12551

& lt;sup>26 With the proposed simplification in classification of the non-fuel generation costs to be done entirely based on the system load factor, there is no longer a need, for tracking the environmental costs in the COSS, were determin...

AI summary The text discusses a proposed simplification in the classification of non-fuel generation costs based on the system load factor, eliminating the need to track environmental costs in the COSS, which were previously determined by the Company's bookkeeping records.

8 Figure 6: BUTU Demand Charge Components in Dollars per kW of Billing Demand 2026 Demand Charge Components Marginal Cost Based Methodology Embedded Cost Methodology Proposed Rates Demand-related Purchased Power Cost $0.000 $6.252 $6.252 D...

AI summary Figure 6 outlines the demand charge components for BUTU in 2026, comparing marginal cost-based methodology, embedded cost methodology, and proposed rates. The table highlights the costs associated with demand-related purchased power and fixed generation costs under different methodologies.

1 Figure 12: Calculation of ELIADC Energy Charge Item Description 2026 ($/MWh) A CBL Cost 73.60 B FCR 3.75 C=A–B CBL Energy Charge 69.85 D CBL Adder 5.00 E Variable Capital Cost 1.02 F=C+D+E ELIADC Energy Charge 75.87 2

AI summary Figure 12 outlines the calculation of the ELIADC Energy Charge for 2026, breaking down components such as the Customer Baseline Cost, Fixed Cost Recovery, and Variable Capital Cost to arrive at the final energy charge of $75.87 per MWh.

REDACTED 2026 AAR Application Appendix B2 Page 6 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Approved Year 2025 Proposed Year 2026 Exclude the GRLF, LRT and Shore Power rate classes. Exclude the following rate classes: the GRLF, OATT...

AI summary The document presents a comparison of approved and proposed costs for various voltage classes in 2025 and 2026, highlighting significant variances in customer administration costs and the exclusion of specific rate classes for the 2026 AAR application. Certain voltage classes show substantial percentage changes in costs, while others remain relatively stable.

NON-CONFIDENTIAL 4 9 10 1 (ii) The Distribution cost amounts by service voltage level are then segregated by the 2 relative into On and off-peak category by using the relative share of time of use 3 sales. 5 (iii) The Distribution cost fix...

AI summary The text outlines the process of segregating distribution costs by service voltage level into on-peak and off-peak categories based on the relative share of time-of-use sales. Fixed cost rates for each voltage level are derived by dividing the distribution cost by on- and off-peak sales in kWh.

2026 AAR Application Appendix B3 Page 6 of 11 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 2026 On peak rates in Cents/ kWh Fig 3 rates in Cents/ kWh Variance Fixed Cost Adder Fuel ADJ Grand Total Generation Transmission Distribution Custom...

AI summary The document provides a detailed breakdown of 2026 on-peak and off-peak electricity rates in cents per kWh for Transmission and Distribution, including fixed cost adders, fuel adjustment mechanisms, and grand totals. It highlights the structure of the rate application and associated cost components.

FOR THE YEAR ENDING DECEMBER 31, 2026 CLASS : TOTAL COMPANY RATE BASE Variable Fixed COSTS (Source Exh 6) Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy Customer Generation Usage (Energy) $1,537,126 $741,...

AI summary The document presents a detailed cost breakdown for the year ending December 31, 2026, including generation, transmission, distribution, and retail costs. It outlines various cost components such as fuel, operating, capital, return, and total costs, along with unit costs and energy sales data.

- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.166 Total 8.902 The charge is applicable to top-up energy consumed in each hour.

AI summary The text outlines a fixed cost adder of 2.166 cents per kWh, applicable to top-up energy consumed hourly, as part of the energy charge components, which also include a fuel cost of 6.736 cents per kWh, totaling 8.902 cents per kWh.

POWER FACTOR CORRECTION Under normal operating conditions, an average power factor over the entire billing period, calculated for kWh consumed and lagging kVAR-h, as recorded, of not less than 90% lagging for the total Mill load (under all...

AI summary The text outlines the requirement for maintaining a minimum power factor of 90% lagging for the total Mill load under normal operating conditions. If this requirement is not met, adjustment factors will be applied to the CBL Energy Charge.

- (2) Energy-related fixed generation cost, coming into effect as a result of a General Rate Application. Energy Charge Components cents per kWh Energy-related Purchased Power and Fuel Cost 7.9266.984 Energy-related Fixed Generation Cost 2...

AI summary The text introduces an energy-related fixed generation cost that is implemented through a General Rate Application. It includes a table outlining energy charge components, including energy-related purchased power and fuel cost, energy-related fixed generation cost, and the total. The Fuel Adjustment Mechanism (FAM) is also mentioned.

COST OF ELECTRICITY UNDER THE ELIADC TARIFF The price paid by PHP for electricity under this Tariff will be based on the forecast incremental cost to serve PHP at an assumed levelized baseline load level, plus an adder to contribute to the...

AI summary The ELIADC Tariff determines the price PHP pays for electricity based on forecasted incremental costs, with adjustments for system savings and Active Demand Control. Key components include Customer Baseline Energy Cost, Variable Capital Charge, and an Active Demand Control Credit.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary The document outlines the process by which NS Power calculates the Customer Baseline Load (CBL) Cost and Energy Charge for PHP, including how the CBL Adder (CBLA) is determined based on forecast CBL Cost. The CBL Energy Charge forms the basis of the ELIADC Energy Charge and includes costs such as fuel, purchased power, line losses, and variable operating costs.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 8 of 8 Under normal operating conditions, an average power factor over the entire billing period, calculated for kWh consumed and lagging kVAR-h, as recorded, of not less than 90% la...

AI summary The document outlines a requirement for maintaining a power factor of at least 90% lagging for the total Mill load under the Extra Large Industrial Active Demand Control Tariff. If this requirement is not met, adjustment factors will be applied to the CBL Energy Charge.

NON-CONFIDENTIAL 1 Decrease in ancillary generation related costs of 19 percent between the submitted OATT 2 applications in the 2023-2024 GRA and the 2026-2027 GRA. 3 4 Exclusion of the interruptible credit amount of $11.2 million from th...

AI summary The submitted OATT applications show a 19% decrease in ancillary generation costs between the 2023-2024 and 2026-2027 GRA periods. However, the exclusion of $11.2 million in interruptible credit from standby demand charges caused a 76% increase in demand charge costs, partially offset by a 6% rise in demand usage. A 60.5% residual imbalance is attributed to the cross-over effect.

Updated RtR Tariffs are needed to Improve Cost Causation REI acknowledges that the AAR process is not necessarily the proper venue for revising tariff structures.[5](#page-3-0) However, NSPI's 2026 AAR filing reveals that the current RtR t...

AI summary REI argues that the current RtR tariffs are misaligned with cost causation principles and require revision to reflect monthly variability of marginal costs, ensure appropriate annual energy cost adjustment methodology, and implement a true-up mechanism to minimize risk and volatility.

ONE PART TRANSMISSION REAL TIME PRICING TARIFF Page 2 of 3 will be required to make a capital contribution equal to the additional capital cost of primary metering as opposed to the cost of secondary metering. - (3) The cost of any special...

AI summary The One-Part Transmission Real-Time Pricing Tariff outlines requirements for customers, including capital contributions for metering, transformer loss adjustments, service terms, and power factor maintenance. It also addresses eligibility and conditions for transitioning between service types.

- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.155 Total 8.891 The charge is applicable to top-up energy consumed in each hour.

AI summary The text outlines a fixed cost adder of 2.155 cents per kWh, which reflects fixed cost energy-related generation costs. This adder is applied to top-up energy consumed in each hour, contributing to the total energy charge of 8.891 cents per kWh, which includes fuel cost and the fixed cost adder.

CLASS : TOTAL COMPANY RATE BASE COSTS (Source Exh 6) Variable Fixed Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy Customer Generation (1) Usage (Energy) $1,528,710 $740,938 $74,223 $109,815 $53,749 $237,...

AI summary This document presents a detailed breakdown of costs and revenue for a utility company's total company class, including generation, transmission, distribution, and retail segments. It includes data on rate base, variable and fixed costs, unit costs, and total costs by category, providing a comprehensive financial overview.

COLUMN A B C D E F G H I J K L M N O P Q R S T U V X Cost Allocation Fact tors Fuel-re lated Cos ts from COS Large Industrial 104.38% 246,525 3.62541% 722,193,823 6.37% 697,602,851 $26,846,935 I $551,396 $437,072 $195,143 $1,183,611 $7,260...

AI summary The table presents cost allocation factors and related financial data for different customer classes including Large Industrial, PHP, and Municipal. It details percentages, dollar amounts, and various cost-related metrics.

- (2) Demand-related fixed generation cost, coming into effect as a result of a General Rate Application. Demand Charge Components $ per kW of billing demand Demand-related Purchased Power Cost $6.2526.222 Demand-related Fixed Generation C...

AI summary The document outlines the implementation of demand-related fixed generation cost as part of a General Rate Application. It includes a table showing the cost per kW of billing demand for purchased power and fixed generation costs, as well as the definition of Contract Demand requirement.

- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.166 Total 8.902 The charge is applicable to top-up energy consumed in each hour.

AI summary The fixed cost adder of 2.166 cents per kWh is applied to top-up energy consumed each hour, reflecting fixed cost energy-related generation costs. This is part of the overall energy charge, which includes fuel cost and fixed cost adder, totaling 8.902 cents per kWh.

Customer Baseline Energy Charge, Customer Baseline Energy Cost, and Contribution to Utility Costs In advance of each tariff year, PHP shall advise NS Power of its forecast annual and monthly energy requirements for the subsequent calendar...

AI summary The document outlines the methodology for calculating the Customer Baseline Energy Charge (CBL Energy Charge) and related components, including the CBL Adder (CBLA) and Variable Capital Charge (VCC), for PHP. These charges are based on forecasted costs and are submitted for Board approval as part of the annual rate-setting process.

Request IR-10: - In Appendix F4, please explain the increase in Average Unit Cost at the Transmission Level from - 7.688 to 7.835. How does it align with Appendix D in the Costs by Functional Area tab for the unit - costs for Total Transmi...

AI summary The document requests an explanation for the increase in Average Unit Cost at the Transmission Level from 7.688 to 7.835 and how it aligns with the Total Transmission unit costs in Appendix D, row (13).

1. NS Power has stated that higher SO2 emission limits have resulted in lower marginal costs. Please confirm the SO2 emissions associated with NS Power production in 2026, the applicable SO2 emission limits, and the remaining headroom unde...

AI summary The document presents a series of questions to NS Power regarding SO2 emissions, marginal costs, surplus energy delivery, and sensitivity analyses related to commodity price volatility, Muskrat Surplus Energy, and wind project delays. It also requests confirmation on the inclusion of the Goose Harbour Lake wind farm in the 2026 PHP CBL load and a comparison of marginal and average costs under different tariff scenarios.

SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - o By midnight each business day, hourly price forecasts for each...

AI summary This section outlines special conditions for a tariff, including hourly energy price forecasts, metering requirements, transformer loss adjustments, service duration, and power factor maintenance. Customers may be required to make capital contributions for primary metering and must maintain a minimum power factor to avoid adjustments.

- (2) A fixed cost adder adjusted concurrent with changes in base cost rates coming into effect as a result of a General Rate Case application. Base Energy Charge Components Transmission Voltage of 69 kV or Higher (cents per kWh) Distribut...

AI summary This section describes a fixed cost adder that is adjusted in line with changes in base cost rates resulting from a General Rate Case application. The table provides breakdowns of base energy charges, including fuel cost and fixed cost adder components for different voltage levels.

- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.166 Total 8.902 The charge is applicable to top-up energy consumed in each hour.

AI summary The document outlines a fixed cost adder of 2.166 cents per kWh, applicable to top-up energy consumed hourly, as part of energy charge components that include fuel cost and total charges.

SPECIAL CONDITIONS - (1) Projections of the anticipated hourly energy price (week ahead and day ahead) will be provided to the customer according to the following schedule: - O By midnight each business day, hourly price forecasts for each...

AI summary The document outlines special conditions for a tariff, including hourly energy price projections, metering requirements, capital contributions for primary metering, transformer loss adjustments, service duration, firm service eligibility, and power factor requirements.

- (2) Fixed cost adder reflective of fixed cost energy-related generation costs. Energy Charge Components cents per kWh Fuel Cost 6.736 Fixed Cost Adder 2.155 Total 8.891 The charge is applicable to top-up energy consumed in each hour.

AI summary The document outlines a fixed cost adder of 2.155 cents per kWh, which reflects fixed cost energy-related generation costs. This charge applies to top-up energy consumed in each hour, in addition to a fuel cost of 6.736 cents per kWh, resulting in a total energy charge of 8.891 cents per kWh.