Topic:"Revenue Requirement" in M12551

1 4.0 ONE PART REAL-TIME PRICING TARIFFS 2 3 Consistent with its October 15, 2025 memorandum to AAR Stakeholders (Appendix J) on NS 4 Power's Proposal for Methodological Changes to 1P-RTP Tariff, the Company proposes that 5 starting in 202...

AI summary The document discusses NS Power's proposal to implement two One Part Real-Time Pricing (1P-RTP) Tariffs starting in 2026, eliminating the avoided fuel cost adjustment. The proposal includes a Transmission RTP Tariff and a Distribution Voltage RTP Tariff, with fixed cost adders designed to recover non-fuel-related costs. The change is driven by the new Cost of Service Study (COSS) filed in the 2026-2027 GRA, which no longer separates environmental and non-environmental costs.

Application for Annually Adjusted Rates for 2026 Redacted 1 adders, and proposed future 1P-RTP adjustments be reviewed as part of GRAs. No stakeholder 2 comments on the October 15 memorandum were received in regard to NS Power's proposed 3...

AI summary NS Power is proposing to adjust its 1P-RTP tariffs based on hourly marginal costs and non-fuel fixed costs, citing volatility in cost estimation due to emissions constraints and non-dispatchable resources. The application aligns with the 2025 AARs proceeding and suggests future tariff adjustments should be handled through General Rate Applications rather than the AAR process.

Application for Annually Adjusted Rates for 2026 Redacted 2 3 The BUTU Tariff has three base cost rate components subject to approval in this Application: a 4 Customer Charge, a Demand Charge, and an Energy Charge. 5 6 The BUTU Tariff file...

AI summary The document discusses the BUTU Tariff's three base cost rate components—Customer Charge, Demand Charge, and Energy Charge—approved in the Application for Annually Adjusted Rates for 2026. The tariff follows the methodology outlined in the Board's Order M09940 and includes a four-year phase-in period starting January 1, 2023. NS Power is directed to update pricing components based on new studies or applications.

14 Figure 13: CBL Adder 2026 ($/MWh) CBL Cost 73.60 Minus FCR 3.75 CBL Energy Charge 69.85 Constant (CBLA) 1.25 Plus FCR transferred from CBL Cost 3.75 Total CBLA 5.00 8.1.3 Variable Capital Charge 2 The ELIADC Energy Charge includes a Var...

AI summary This section discusses the CBL Adder and Variable Capital Charge (VCC) in the context of NS Power's 2021 AAR application. The CBL Adder is calculated by subtracting FCR from CBL Cost and adding back FCR transferred from CBL Cost, resulting in a total CBLA. The VCC is part of the ELIADC Energy Charge and is used to account for the incremental generation and delivery costs of electricity for PHP.

REDACTED 2026 AAR Application Appendix B2 Page 1 of 19 REDACTED (CONFIDENTIAL INFORMATION REMOVED) 1P-RTP ADDER CALCULATION Transmission-connected O&M Capital ROE Generation Costs $0.01496 $0.02561 $0.01125 $0.05182 $0.01538 $0.02086 $0.00...

AI summary This document presents a table with various cost calculations, including transmission-connected costs, fixed costs, and customer costs. It includes percentages and monetary values related to operations, capital, return on equity, and fuel cost adjustments.

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 Transmission 196,618,713 211,929,809 408,548,522 48% 52% 0% 145.32 2.11% $9,004 $...

AI summary The document presents a cost breakdown for 2026 on-peak and off-peak rates in cents per kWh, including transmission, distribution, and customer classes. It includes figures for variance, costing determinants, and apportioned amounts. The data highlights the distribution of costs across different customer classes and service levels.

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.

SALES, GENERATION AND DEMAND ANALYSIS FOR THE YEAR ENDING DECEMBER 31, 2026 ( 1) DOMESTIC ( 2) SMALL GENERAL ( 3) GENERAL ( 4) GENERAL LARGE (1) MWH SALES 5,286,337,241 376,992,742 2,308,034,614 363,766,784 (2) ENERGY LINE 8.2% 8.2% 7.9% 5...

AI summary The document presents a detailed analysis of sales, generation, and demand for the year ending December 31, 2026, including data on energy sales, losses, system demand, and load factors across different customer classes and voltage-based service levels.

SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, if in the opinion of NS Power issues not specifically set out herein, must be addressed for the ongoing benefit of NS Power and its customers. - (2)...

AI summary NS Power reserves the right to establish separate service agreements when necessary for the benefit of its customers and the power supply system. Specific operating agreements are required to ensure that generation and load do not compromise system integrity. NS Power also retains the right to apply for changes in rates or service terms through the Nova Scotia Energy Board.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary The Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, income tax, and OM&G, and are recovered through Bundled Service. Deferred costs are those approved by the Nova Scotia Energy Board for future recovery.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is allowed to manage PHP's load under the Active Demand Control protocol. Annual reports are required to the Board, detailing system savings and schedule variances. PHP is entitled to a 25% credit based on the difference between the Customer Baseline Cost and the actual annual cost to serve them.

VCC CALCULATION Description Units Value Variable capital cost impact $ $787,508 PHP load forecast-2026 GWh 774.46 VCC Rate $/MWh $1.02 2026 AAR Application Appendix H Page 1 of 37 REDACTED (CONFIDENTIAL INFORMATION REMOVED)

AI summary The document provides a table detailing the variable capital cost impact, PHP load forecast for 2026, and the VCC rate. These figures are part of an AAR application appendix, which includes confidential information that has been redacted.

SPECIAL CONDITIONS - (1) NS Power reserves the right to have a separate service agreement, if in the opinion of NS Power issues not specifically set out herein, must be addressed for the ongoing benefit of NS Power and its customers. - (2)...

AI summary NS Power reserves the right to establish separate service agreements when necessary for the benefit of its customers and the power supply system. The LRS' RtR Customers and generators must ensure their operations do not compromise system integrity, with specific requirements outlined in written agreements. NS Power retains the authority to apply for changes in rates and terms through the Nova Scotia Utility and Review Energy Board.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary The Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, and operational expenses, and are to be recovered through Bundled Service, not through other applicable tariffs.

REDACTED 1 sense of any timeline that deviates significantly from what is currently forecast such 2 as the sensitivity scenario that was provided in the filing. 3 4 (c) As the provided sensitivity which is considered a "worst case scenario...

AI summary NS Power argues that a sensitivity scenario modeling a delayed wind resource timeline in 2026 has only a minimal five percent impact on annual marginal costs and does not warrant further modeling of less severe scenarios at this time.

REDACTED 2 (a) Assuming this Application is approved as filed, effective January 1, 2026, what is the annual revenue forecast to be collected from each rate class under the AAR? In providing your answer, please identify the load forecast b...

AI summary The document contains two questions related to revenue forecasting under an application. The first asks for the annual revenue forecast per rate class, assuming approval, and requests details on the load forecast and assumptions. The second inquires about the impact of PHP becoming an ATL customer and the Goose Harbour Wind Farm's operation before 2026.

12 Response IR-1: 13 14 (a) Estimated revenue for 2026 is provided in the table below, based on the 2026 forecast 15 produced in Q3 2025.

AI summary The document provides an estimated revenue for 2026, based on a forecast produced in Q3 2025.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 3 of 8 $61.75/MWh. The FCR transferred from the CBL Cost is then added to the calculated CBLA to equal $5/MWh FCR. x When the forecast CBL Cost is at or over $61.75/MWh, the FCR to b...

AI summary The ELIADC Energy Charge is calculated by summing the CBL Energy Charge, CBLA, and VCC. When the forecast CBL Cost exceeds $61.75/MWh, the FCR transferred is capped at $3.75/MWh, with the difference assigned a value of zero. These charges are submitted for Board approval annually as part of the Annual Adjusted Rates proceeding.

INTRA-YEAR MODIFICATIONS TO THE CBL ENERGY CHARGE NS Power will utilize its established forecasting methodology to determine the CBL Energy Charge. PHP will undertake commercially reasonable efforts to accurately forecast its energy usage....

AI summary NS Power will use its forecasting methodology to determine the CBL Energy Charge, with potential for intra-year modifications if significant changes occur. PHP is expected to forecast its energy usage accurately. Revisions may be made with Board approval if delays in NS Block energy imports or other significant changes affect the CBL Energy Charge.

NON-CONFIDENTIAL 1 Request IR-4: 2 3 Preamble: In response to the Board's Directive comparing monthly Forecast-to-Actual NB 4 imports, in Section 2.3, page 14, NS Power indicated that forecast accuracy can be assessed 5 via FAM reporting....

AI summary The document addresses a request (IR-4) related to forecast accuracy in the context of the Board's directive comparing monthly Forecast-to-Actual NB imports. NS Power explains that the FAM filings provide actual costs against FAM budget costs and notes that AAR rates are handled in a separate proceeding.

(b) Please provide the missing information required to evaluate historical forecast accuracy regarding natural gas, diesel, import purchases, and Maritime Link. Α В С D E F G H 1 (millions of dolla rs) YTD 2 dec dec dec dec dec dec oct 3 N...

AI summary The document requests missing information to evaluate historical forecast accuracy for natural gas, diesel, import purchases, and Maritime Link. A table provides actual, forecast, and budget figures for these categories across multiple years, with a response indicating that NS Power did not prepare the table but the data appears accurate.

PARTIALLY CONFIDENTIAL (Attachment Only) 1 Request IR-12: 2 3 Reference: Appendix F2, F3 and F4. 4 5 (a) For each cross-referenced document from the GRA, please provide the assigned 6 NSEB exhibit number. 7 8 (b) Please provide a pdf versi...

AI summary The request (IR-12) asks for exhibit numbers, PDFs of cross-referenced documents, and an explanation of why NS Power refused access to confidential information. The response refers to a table and mentions the 2024 AARs and confidentiality undertakings.

DEMAND CLASSIFICATION (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (9) (10) (11) ALLOCATION COMPANY DOMESTIC GENERAL GENERAL LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL PHP MUNICIPAL UNMETERED FACTOR (1) Transmissi...

AI summary The document presents a detailed breakdown of demand classification across various categories, including transmission, operating and maintenance expenses, depreciation, interest, corporate taxes, and revenue, with associated allocations and factors. It includes various line items and references to regulatory and financial processes.

FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (21) PREFERRED DIVIDENDS (22) CORPORATE TAXES 0 -2,636 0 -1,316 0 -89 0 -558 0 -88 0 -64 0 -109 0 -168 0 -194 0 -30 0 -19 P-17 P-17 (23) Non-Operating Revenue: (24) EXPORT SAL...

AI summary The document provides a summary of financial figures for the year ending December 31, 2026, including preferred dividends, corporate taxes, non-operating revenue, return on profit/loss, total generation, and operating and maintenance expenses. Key figures are listed in thousands of dollars.

NOVA SCOTIA POWER INC. CAPACITY BASED ANCILLARY SERVICES 2026 REVENUE REQUIREMENT AND RATE DESIGN (1) (2) (3) (4) (5) (6) (7) (8) (9) Revenue Requirement ($/kW-yr) Services Required (MW) Revenue Requirement ($000/yr) Usage (MW) Rate for Ne...

AI summary The document presents a table outlining the revenue requirement and rate design for Nova Scotia Power Inc.'s capacity-based ancillary services in 2026, including various services such as regulation, load following, and operating reserves, along with their associated costs and rates.

NOVA SCOTIA POWER INC. 2026 REACTIVE SUPPLY AND VOLTAGE CONTROL RATE DESIGN (1) Revenue Requirement ($000/yr) (2) Billing Determinants (MW) (3) Yearly ($/MW-yr) (4) Monthly ($/MW-mo) (5) Weekly ($/MW-wk) (6) On-Peak Daily ($/MW-dy) (7) Off...

AI summary The document presents a revenue requirement and billing determinants table for Nova Scotia Power Inc.'s 2026 reactive supply and voltage control rate design. It outlines various revenue and cost figures across different time intervals, including yearly, monthly, weekly, and hourly rates for on-peak and off-peak periods.

• And in the micro-grid configuration: - o customer monthly charges on all but one customer; and - o an amount that could arise from consolidation of customer load shape (whereby the diversity is lost to NS Power) and possibly from the cus...

AI summary The text discusses the micro-grid configuration and the implications of customer load shape consolidation and customer class differences. It references the Retailers Regulations from 2015, which classify B-t-M as a form of RtR supply, requiring LRS to execute an LRS Participation Agreement and be subject to RtR tariffs rather than Bundled Service tariffs. Two methods to meet the no-harm requirement are outlined: secondary metering and enhanced recovery of embedded costs.

5.1 Context The supply-related cost represents the largest component of the existing cost of Bundled Service, as it includes the asset-related cost (including financing and return on equity) of all generating plant, the fixed and variable...

AI summary The supply-related cost is the largest component of the Bundled Service cost, including asset-related costs, O,M & G costs, and fuel costs. To avoid economic disadvantage, NS Power must recover the same amount from RtR customers as would have been recovered from Bundled Service customers, adjusted for avoided costs. Recovery will occur through Energy Balancing Service, Standby Service, and RtR Market Transition Tariff revenue.

Annually Adjusted Rates for 2026 REI IR-18 Attachment 1 Page 25 of 41 REDACTED (CONFIDENTIAL INFORMATION REMOVED) systematically when other variable generation production is high and system marginal cost is low. Given the unpredictable nat...

AI summary The document discusses the challenges of incorporating variable generation into rate structures, proposing a mid-point rate with a spread to reflect incremental costs. It suggests avoiding time-based rates due to complexity and instead using a spread between top-up and spill rates to account for variability in generation patterns.

8.2.5 Basis for selection The amount of embedded cost recovery depends in large part on the amounts of NS Power fixed costs recovered by other mechanisms. As noted in the discussion of the EBS and Standby Service tariffs, the amounts recov...

AI summary The selection of the RtR Market Transition Tariff over Exit Fees is based on its ability to achieve full and fair embedded cost recovery with less risk and uncertainty, considering the complexity and variability of Exit Fee estimates.

(a) No Evidence of Forecast Accuracy or Historical Validation Through the Information Request Process, REI asked a series of questions to test the validity of the marginal cost forecasting for 2026. In response, however, NSPI did not provi...

AI summary REI questioned the accuracy of NSPI's marginal cost forecasting for 2026. NSPI could not provide historical data due to a cybersecurity breach and only offered limited comparisons, such as a single-quarter forecast discrepancy for solid fuel plants and diesel combustion turbines. These discrepancies raise concerns about the reliability of forecasting methods.

the wholesale customer must provide: - 1. Documentation demonstrating that the import capacity will be supported by the external control area and afforded the same curtailment priority as the external control area's native load. - 2. Docum...

AI summary Special conditions outline requirements for wholesale customers regarding import capacity support, transmission assurance, reliability performance, and financial obligations in case of failure. These include documentation requirements, capacity procurement timelines, and procedures for cost recovery and CCF adjustments.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, return on equity, income tax, and OM&G, and are approved for recovery by the Nova Scotia Energy Board.

Case 2023 GRA 2026 GRA 4 Exclude the GRLF, LRT and Shore Power rate classes. Power. Exclude the following rate classes: the GRLF, OATT, LRT and Shore % VARIANCE 149 150 151 152 153 154 155 ROE Transmission-connected HV (Not Applicable star...

AI summary The document presents a comparison between the 2023 and 2026 General Rate Applications (GRA), highlighting various rate classes and their associated costs and variances. It includes figures for ROE, transmission-connected, HV, distribution, and other categories, along with percentage variances between the two years.

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 3 CP De mands Energy Requ uirement Purchased Powe r- Biomass Maritime Link Purchased Po wer other than B Wind Biomass and ı Purcha...

AI summary The text presents a table outlining cost allocation factors and energy requirements across various rate classes and embedded cost categories, including fuel-related costs, purchased power, and energy-related and demand-related costs. It includes columns for different types of energy sources and cost allocations.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, return on equity, income tax, and OM&G, and are approved for recovery by the Nova Scotia Energy Board.

ed in the 2024/25 TVP Evaluation Report being extended, and the pilot for 2025/26 was suspended. NS Power intends to provide an update in its 2027 AAR application. The Board directs NS Power to do so. The NSUARB directed NS Power to perfor...

AI summary The NSUARB directed NS Power to provide a sensitivity analysis on delayed wind resources in its 2026 AAR application, but NS Power only provided one unrealistic scenario. The Board accepts the modeling but directs NS Power to update the 2027 AAR with actual in-service dates and energy impacts of any delays.

ce to customers. NS Power reported that it proposed a draft Terms of Reference for an interruptible service pilot with REI in July 2025. NS Power remains amenable to discussing this service structure. When NS Power filed this AAR applicati...

AI summary NS Power proposed a draft Terms of Reference for an interruptible service pilot with Renewall Energy Inc. (REI). The Board is concerned about using a new COSS in the AAR application since it has not been approved. The current COSS is outdated and the Board agrees with NS Power that adjustments can be made through a compliance filing.

SPECIAL CONDITIONS (1) The Port Authority owns and is responsible for the maintenance and operation of all electrical equipment required for the supply of port electricity to docked ships other than the meters and - metering transformers s...

AI summary The Port Authority and NSPI have defined roles and responsibilities regarding electrical equipment, metering, and operational procedures for port electricity supply. Special conditions include metering responsibilities, staff availability, scheduling, metering costs, transformer losses, and power factor requirements.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under Section 3G(2) of the Electricity Act (Nova Scotia) to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include generation-related fixed costs and those approved by the Nova Scotia Energy Board for future recovery.

SPECIAL CONDITIONS - (1) The Port Authority owns and is responsible for the maintenance and operation of all electrical equipment required for the supply of port electricity to docked ships other than the meters and metering transformers s...

AI summary This section outlines the special conditions for port electricity supply, including ownership responsibilities, operational requirements, metering arrangements, and power factor maintenance. The Port Authority and NSPI have defined roles, and customers are required to cover additional costs for specialized metering and communication systems.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary The Renewable to Retail Market Transition Tariff (RTT) aims to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing, return on equity, and OM&G, and are not otherwise recovered through other tariffs. The RTT is established under Section 3G(2) of the Electricity Act (Nova Scotia).

Request IR-4: Refer to M12551, Exhibit N-1, the Application, Section 7.0 Renewable to Retail Market (RtR) Tariffs and the proposed RtR Tariff Administration Charge , which states: The Company has calculated the RtR Tariff Administration Ch...

AI summary The document discusses NS Power's proposed RtR Tariff Administration Charge, including the deferral of costs incurred in 2026 and anticipated recovery starting in 2027. Questions are raised about current estimated costs, whether interest costs will be applied, and the expected interest rate.

ffering a TVP structure for AARs? Refer to M12551, Exhibit N-1, the Application, Section 7.0 Renewable to Retail Market (RtR) Tariffs and the proposed RtR Tariff Administration Charge , which states: The Company has calculated the RtR Tari...

AI summary The document discusses NS Power's proposed RtR Tariff Administration Charge and associated costs, including deferred costs and future recovery plans. It also references standby service tariff charges for 2025 and 2026 and asks about estimated costs, interest rates, and supporting documentation.

Section 7.2 Standby Service Tariffs and Figure 10: Standby Service Tariff Charges, which shows the Administration Charge ($/customer/month) of $401.58 for 2025 and $414.63 for 2026.[[5]](#footnote-6) 1. Does the proposed higher 2026 Admini...

AI summary The document discusses the proposed increase in the 2026 Administration Charge for standby service tariffs, asking whether the 3.25% increase aligns with other AAR tariffs. It also addresses the Annually Adjusted Energy Savings Credit, noting that NS Power does not project savings in this category for 2026 and requests an explanation and supporting information.

2 Reference: Assumptions, page 11, Appendix A3 PCON; and Board-Directed Sensitivity 3 Analyses, pages 12-13 and Appendix A6 PCON. - 4 (a) NS Power has stated that higher SO2 emission limits have resulted in lower 5 marginal costs. Please c...

AI summary The document contains a series of questions directed to NS Power regarding SO2 emissions, marginal cost impacts, surplus energy delivery, and sensitivity analyses related to commodity price volatility, wind generation delays, and tariff assumptions. The questions seek clarification on assumptions, risk factors, and forecasting methodologies used in cost modeling.

17 Request IR-9: - 18 (a) Please explain what financial and operational risks or benefits NS Power 19 faces if it underestimates marginal costs in the AAR calculation versus the 20 risks or benefits if it overestimates marginal costs. - 21...

AI summary The request asks NS Power to explain the financial and operational risks or benefits of underestimating or overestimating marginal costs in the AAR calculation, quantify these impacts, identify affected customer classes, and address impediments to more frequent updates of marginal costs in the RtR market.

7 Request IR-15: - 8 Reference: Appendix F3, page 137 Standby Demand Charge Calculation. - 9 (a) Please explain in detail the source and derivation of the Interruptible 10 Service Credit, including the methodology, assumptions, and calcula...

AI summary Request IR-15 asks for detailed information on the Interruptible Service Credit, including its source, derivation, methodology, and assumptions, as well as its relation to the Pilot Interruptible Service in the RtR market and the Board order or tariff provision authorizing it.

ysis showing the impact on marginal and average costs if PHP continues to receive service under the ELIADC through 2026 versus taking service under a to-be-filed successor tariff which may be above-the-line. Please quantify the potential r...

AI summary The text consists of a series of questions directed at NS Power regarding the financial and operational implications of various scenarios, including the impact of ELIADC, accuracy of wind generation data, forecasting methods, risk management, and the potential for more frequent marginal cost updates in the RtR market.

ed under the proposed 1P-RTP and the alternate 1P-RTP (as provided in response to part (c) above) rates, and explain any material differences in the total cost recovery. - (e) NS Power further states, In view of the foregoing [referencing...

AI summary NS Power has eliminated the adjustment for the projected imbalance in the recovery of the avoided fuel in response to the SO2 emissions limit. Energy charges are now based on hourly marginal costs, and fixed cost adders include only non-fuel costs.

ed in the 2024/25 TVP Evaluation Report being extended, and the pilot for 2025/26 was suspended. NS Power intends to provide an update in its 2027 AAR application. The Board directs NS Power to do so. The NSUARB directed NS Power to perfor...

AI summary NS Power's 2026 AAR application did not fully comply with the NSUARB's directive for a sensitivity analysis on delayed wind resources. The Board accepts the modeling exercise but requires an update in the 2027 AAR application on the in-service dates of wind resources and the impact of potential delays.

Renewall Energy Inc. REI's submission was concentrated on the use of the proposed Cost of Service Study methodology, the RtR tariff review and design, RTRSS tariff calculation and the forecasted marginal cost used in the application. Notab...

AI summary Renewall Energy Inc. (REI) submitted concerns regarding the proposed Cost of Service Study methodology, RtR tariff design, and RTRSS tariff calculation, noting changes to the RTRSS formula. REI requested recalculations and regulatory action by March 31, 2026. NS Power responded by suggesting that addressing these issues may be premature and that changes should occur after the RtR begins service.

2. NS Power is directed as follows: - 1. If the updated Cost of Service Study is not approved as filed, currently before the Board in the NS Power GRA matter M12451, NS Power is directed to make any required adjustments to the 2026 AARs in...

AI summary The Board has directed NS Power to make various adjustments to its AARs, including updates on wind resource deployment, sensitivity analysis of the Maritime Link, and stakeholder engagement on tariff amendments. NS Power must also submit data on administration charge inflation adjustments and file the 2027 AAR application by a specific deadline.

SPECIAL CONDITIONS (1) The Port Authority owns and is responsible for the maintenance and operation of all electrical equipment required for the supply of port electricity to docked ships other than the meters and - metering transformers s...

AI summary The Port Authority and NSPI have defined responsibilities for electrical equipment maintenance, metering, and operational procedures. Special conditions include metering responsibilities, capital contributions for primary metering, transformer loss adjustments, and power factor requirements.

the wholesale customer must provide: - 1. Documentation demonstrating that the import capacity will be supported by the external control area and afforded the same curtailment priority as the external control area's native load. - 2. Docum...

AI summary The text outlines conditions for wholesale customers importing capacity, requiring documentation of support from external control areas and firm transmission. It also specifies that failure to deliver energy or capacity may result in financial penalties and potential adjustments to the Capacity Credit Factor (CCF) or adjudication by the Board.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary The Renewable to Retail Market Transition Tariff (RTT) is established under Section 3G(2) of the Electricity Act (Nova Scotia) to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing costs, and OM&G, and are recovered through Bundled Service, not through other applicable tariffs.

ACTIVE DEMAND CONTROL AND SCHEDULE VARIANCE NS Power shall be entitled to actively manage PHP's load in accordance with the terms and conditions set out in the Active Demand Control – Energy Supply Protocol attached as Schedule 1 to this T...

AI summary NS Power is allowed to manage PHP's load under the Active Demand Control – Energy Supply Protocol. NS Power must report system savings and schedule variances annually to the Board, including load shifting benefits and improvements to the ELIADC Tariff. PHP receives a 25% credit based on the cost differential between CBL Cost and actual annual serving costs.

May 15, 2026 Interested parties: M12551 – 2026 Annually Adjusted Rates – Compliance Filing The Nova Scotia Energy Board's decision dated March 9, 2026, approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026. The Board ret...

AI summary The Nova Scotia Energy Board approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026, and NS Power submitted a compliance filing with revisions to seven AARs following the Board's decision on the 2026-2027 GRA. Comments on the revised AARs are invited from interested parties by May 25, 2026.

ORDER The Board's decision dated March 9, 2026, approved the 2026 Annually Adjusted Rates (AARs) effective April 1, 2026. The Board retained its jurisdiction to amend the AARs following the outcome of the updated Cost of Service Study in t...

AI summary The Board approved the 2026 Annually Adjusted Rates (AARs) on March 9, 2026, and retained jurisdiction to amend them based on the updated Cost of Service Study in the NS Power General Rate Application (GRA) matter M12451. NS Power filed a compliance filing with revisions to seven AARs on May 11, 2026.

PURPOSE Pursuant to Section 3G(2) of the Electricity Act (Nova Scotia), this Renewable to Retail Market Transition Tariff (RTT) is designed to recover from Licenced Retail Suppliers (LRS) NS Power's embedded fixed costs and deferred costs,...

AI summary This Renewable to Retail Market Transition Tariff (RTT) is established under the Electricity Act to recover NS Power's embedded fixed and deferred costs from Licensed Retail Suppliers (LRS). These costs include depreciation, financing costs, and operational expenses, and are not otherwise recovered through other applicable tariffs.