Topic:"Demand Side Management" in M12661

icity - for PHP. However, for a customer with the load flexibility of PHP, a levelized load profile will, in - general, not produce the optimal customer or system load profile as the Customer would be

AI summary The text discusses the suboptimality of levelized load profiles for customers with load flexibility similar to PHP (PHP Wind Ltd), suggesting they may not align with optimal customer or system load profiles. NSPI (Nova Scotia Power Inc.) is referenced in this context.

ELID Interruptible Rider Credit Reduction per kilovolt ampere reduction in demand charge Effective January 1, 2026 $7.638 Effective January 1, 2027 $7.667 Availability

AI summary The document outlines the ELID Interruptible Rider Credit, providing the reduction per kilovolt-ampere reduction in demand charge for the years 2026 and 2027. It also mentions the availability of this rider.

This rider will be applicable to and agreed upon, between the Company and the Customer, under the following terms and conditions: - (1) The Customer has provided written notice of their desire to take service under this option, identifying...

AI summary This rider outlines the terms and conditions for a customer to provide interruptible load service to NS Power. The customer must notify NS Power of the firm and interruptible load portions, respond to interruption requests within 10 minutes, and allow NS Power to monitor and control the load. Restoration of service requires approval from NS Power.

As compensation for providing this service, the Customer will receive a per month per kilovolt ampere reduction in demand charge for billed interruptible demand as shown in the table below. ELID Priority Interruptible Credit reduction per...

AI summary The Customer will receive a monthly reduction in demand charge per kilovolt ampere for interruptible demand, effective January 1, 2026 and 2027, with rates of $0.764 and $0.767 respectively.

Customer Charge Estimates for Extra Large Industrial Dispatchable Tariff Cost Estimate Task Required to Support the Tariff Approx. Cost per Month Approx. Cost per Year low range high range low range high range Development, management, and...

AI summary The document provides cost estimates for developing and managing the Extra Large Industrial Dispatchable Tariff, including tasks such as operating procedures, engagement with PHP, and system optimization. The total monthly cost is estimated between $10,000 and $14,583, with annual costs ranging from $120,000 to $175,000.

2026-2027 General Rate Application Settlement Agreement Extra Large Industrial Dispatchable Tariff Application – Attachment 4 Page 10 of 21 GRA Element Settlement Terms PHP Treatment a) NS Power's 2026/2027 cost of service study includes P...

AI summary The settlement terms for the 2026-2027 General Rate Application discuss the inclusion of PHP as an above-the-line customer in NS Power's cost of service study, the load characteristics used for PHP, the interruptible credit applicable to PHP, and the analysis of the value of Active Demand Control (ADC) as a potential rider to the cost-based rate.

RESPONSIBILITIES OF FRANCHISE HOLDER It is the responsibility of the holder of the electric efficiency and conservation franchise granted under Section 79C of the Public Utilities Act (Franchise Holder) to apply to the Nova Scotia Utility...

AI summary The Franchise Holder must apply to NSUAREB for approval of all DSM activities, plans, and programs, including itemizing related costs. NS Power is required to seek annual approval for DSM Cost Recovery Rider amounts by October 1 and remit monthly payments to fund approved DSM costs.

PCR = Program Cost Recovery The PCR includes all estimated costs for the upcoming calendar year for the DSM Plan that has been requested by the Franchise Holder and approved by the NSUAREB (Approved DSM). It includes the cost of planning,...

AI summary The Program Cost Recovery (PCR) encompasses estimated costs for the approved Demand Side Management (DSM) Plan, including planning, implementation, and administrative expenses. It is calculated using Schedule B's cost allocation methodology for each rate schedule.

Total BA = BA1 + BA2 The BA shall be updated annually to reflect BA1, and at the conclusion of each Approved DSM Term to reflect BA2. The NSUAREB-approved DCRR shall be placed into effect with bills rendered on and after the effective date...

AI summary The Balance Adjustment (BA) is updated annually to reflect BA1 and at the end of each Approved DSM Term to reflect BA2. The NSUAREB-approved Dispatch Cost Recovery Rider (DCRR) is implemented with bills after its effective date, ensuring alignment with regulatory approvals.

2025 DSM Cost Recovery Rider Charges Effective: January 1, 20265January 1, 2026 The Demand Side Management Cost Recovery Rider (DCRR) charges, along with its components, (PCR) and (BA), for the period from the approved effective date of Ja...

AI summary The 2025 DSM Cost Recovery Rider (DCRR) charges, including Program Cost Recovery (PCR) and Balance Adjustment (BA), apply from January 1, 2025, to December 31, 2025. The BA2 calculation for 2023, based on revenue versus DSM costs, will be applied annually from 2028–2031. The Approved DSM Term refers to the full DSM Plan period (e.g., 2023–2026, 2027–2031).

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) Page 3 of 5 Applicable Tariff PCR (cents per kWh) BA (cents per kWh) DCRR (cents per kWh) Domestic Service, Domestic Service Time-of-Day, Domestic Service Time-of-Use, Domestic Service Crit...

AI summary The document outlines the Demand Side Management Cost Recovery Rider (DCRR) with various applicable tariffs and associated rates, including Program Cost Recovery (PCR) and Balance Adjustment (BA) for different service categories. The table provides specific monetary values per kWh for each category.

DSM Cost Allocation MethodApproach There are 3 kinds of cost benefits resulting from DSM: - (1) System avoided future infrastructure and related costs, reduced fuel costs, and contribution to achieving environmental and emissions restricti...

AI summary The text outlines three types of benefits from DSM: system-wide, class-based, and participation-specific. It argues that DSM cost recovery should align with the benefits received by customer classes, with those receiving more benefits bearing higher costs. However, precise allocation is deemed impractical due to DSM program complexities.

Method - Step 1 Allocate the system benefits to all applicable customer classes, as 25% of the total Approved DSM program costs, in accordance with the COSS methodology per the most recent rate case decision. - Step 21 Allocate the class a...

AI summary The method outlines a five-step process for allocating system and class benefits from DSM programs, recovering costs via bundled service rates or direct billing, and annually adjusting allocations based on prior two years' data. It references COSS methodology and BA1/BA2 for true-up adjustments.

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) Page 5 of 5 - For bundled service customers other than those who take service in the Wholesale Market (whether in whole or in part), this approach applies to classes as a whole (not to indi...

AI summary The DCRR applies differently based on customer service type: classes as a whole for non-wholesale market customers, and individual customers for those in the wholesale market. Total Approved DSM costs are subject to this approach.

2 Q PLEASE DESCRIBE NS POWER'S PROPOSED ELID TARIFF FOR PHP. 3 A NS Power is requesting approval of an Extra Large Industrial Dispatchable ("ELID") 4 Tariff for PHP, to be available on, or before, January 1, 2027, following the termination...

AI summary NS Power proposes an ELID Tariff for PHP, replacing the expiring ELIADC Tariff. The ELID includes a Dispatchable Rider allowing NS Power to curtail PHP's load above 8 MW to reduce system costs and ensure reliability. PHP retains 8 MW firm demand rights, with NS Power prioritizing other customers during curtailments.

The ELID Energy Charge will apply to all delivered energy to PHP in excess of the subject Energy Amount deemed to have been provided, pursuant to the Power Sales Agreement issued under section 4 AA of the Electricity Act. 7 Energy credit w...

AI summary The ELID Energy Charge applies to excess energy delivered to PHP beyond a specified amount, with energy credits estimated annually. The ELID Demand Charge is based on a 'PHP demand determinant' set during the GRA process or other proceedings, with a stated demand price of $14.31/KVA-month in 2027. NS Power designates this as a 'fixed charge,' distinguishing it from other demand charges. The ELID Interruptible Service and Credit terms are similar to LIIR but with a 10% premium for PHP due to priority interruption.

15 Q HOW WILL NS POWER PROPOSE TO PASS ON THE BENEFITS OF THE DR AND 16 INTERRUPTIBLE SERVICE TO PHP? 17 A There will be two credits made to PHP cost of service. First, NS Power will provide a 18 billing determinant demand charge credit eq...

AI summary NS Power proposes passing benefits of DR and interruptible service to PHP via two credits: a demand charge credit (matching LIIR interruptible rates plus a 10% premium) and a power supply credit based on modeled savings from dispatching PHP load during high-cost periods. This reduces NS Power's supply costs, benefiting PHP while maintaining costs for ATL customers.

1 2 PHP and NS Power communicate energy requirements and availability on an 3 annual, monthly, daily and hourly basis that aligns with the Active Demand Control 4 Energy Supply Protocol. PHP and NS Power also meet weekly to discuss current...

AI summary PHP and NS Power communicate energy requirements and availability on various timeframes, aligning with the Active Demand Control Energy Supply Protocol. PHP has been under the ELIADC Tariff since 2020, providing system benefits through load flexibility, similar to a dispatchable power generation facility.

1 PHP has made its load available to be actively managed by NS Power Fuels, Energy 2 and Risk Management ("FERM") and the NSPSO according to the Active Demand 3 Control Energy Supply Protocol. DA and RT Schedules can range from longer peri...

AI summary PHP's load is actively managed by NS Power FERM and NSPSO under the Active Demand Control Energy Supply Protocol. PHP faces challenges due to unpredictable grid conditions and dispatch uncertainty, which affect operational planning and decisions. PHP has adapted its operations to accommodate the ELIADC tariff structure and provides grid reliability services through ADC.

2 Q. Please provide further details regarding PHP's operations during the time 3 of NS Power's winter month system coincident demand peaks over the past 4 number of years. 5 1 6 A. PHP cannot anticipate the exact timing of when a peak load...

AI summary PHP cannot predict NS Power's winter peak demand times and relies on NS Power/NSPSO for load dispatch. ELIADC's ADC mechanisms allow load reduction during peaks but were not designed for peak avoidance. PHP's historical load data is unsuitable for demand charges due to NSPSO's dispatch authority.

9 The total smoothed revenues of the transmission-connected customers, billed under the 10 LIIR Tariff, are forecast to go down by 5.3 percent in 2027. It is important to note the 11 costing and pricing of the LIIR Tariff does not incorpor...

AI summary The forecasted total smoothed revenues for transmission-connected customers under the LIIR Tariff are expected to decrease by 5.3% in 2027. The LIIR Tariff does not include the load from PHP, and it is not expected that PHP's demand or energy under the LIIR Tariff would match that under the ELID Tariff.

NSPI Responses to BW Information Requests 1 Request IR-9: 2 3 Please refer to Exhibit N-1, page 10 lines 5-7 and section 2.5. 4 5 (a) Please identify "the cost of providing DR service" that "is borne by PHP." Is this a 6 reference to the C...

AI summary NSPI responds to BW's information requests regarding the ELID Tariff, addressing dispatch instructions, cost allocation, enforcement mechanisms, and exogenous factors affecting PHP's consumption. Questions focus on cost recovery, dispatchability, and tariff compliance.

EXHIBIT 6 PAGE 6 OF 6 (1) INTERR. RIDER DMD ADJ. (2) (3) Peak Dmd. in KWs (at Generator) 69,594 (4) Int Credit Amount 11,165 (5) (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (8) Demand Usage Annual Credit Amount Calculation (9) Winter Month k...

AI summary The text presents a table related to demand adjustment calculations, including peak demand, credit amounts, and priority interruption adjustments, as part of a tariff attachment. The table includes values for demand usage, power factor adjustments, and credit calculations, though many values are zero or redacted.

NOVA SCOTIA POWER INC. SALES, GENERATION AND DEMAND ANALYSIS (1) MWH (2) ENERGY LINE (3) ENERGY SALES LOSSES REQUIREMENT DMD. (KW) (4) CLASS NON- SYSTEM (5) FACTOR (6) SYSTEM DEMAND SYSTEM COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK C...

AI summary The document presents a detailed analysis of Nova Scotia Power Inc.'s sales, generation, and demand across various customer classes. It includes metrics such as energy consumption, losses, demand factors, and contributions to system demand. The data is organized into multiple columns, providing insights into energy usage patterns and efficiency across different sectors.

FOR JANUARY 2026 (1) MWH (2) ENERGY LINE (3) ENERGY (4) CLASS NON- COINCIDENT (5) SYSTEM COINCIDENT (6) SYSTEM COINCIDENT (7) DEMAND LINE (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSSE...

AI summary The document presents a detailed table of energy sales, losses, and demand factors across various customer classes in January 2026. It includes metrics such as energy line, class non-coincident, system coincident demand, and losses for different categories like domestic, industrial, and municipal. The table also includes subtotals and totals for energy usage and demand factors.

FOR FEBRUARY 2026 (1) MWH (2) ENERGY LINE (3) ENERGY (4) CLASS NON- COINCIDENT (5) SYSTEM COINCIDENT (6) SYSTEM COINCIDENT (7) DEMAND LINE (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSS...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for various customer classes in February 2026. It includes data on energy usage, losses, and demand factors for domestic, industrial, and other categories, as well as subtotals and totals for the period.

FOR MARCH 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT...

AI summary The document presents a table with various metrics related to energy sales, losses, and demand for different customer classes in March 2026. It includes figures for MWH sales, energy losses, energy requirement, demand, and other related factors. The data is categorized by customer type, such as domestic, industrial, and municipal, and includes totals and subtotals for different segments.

FOR APRIL 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics categorized by customer class for April 2026. It includes data on energy sales losses, energy line losses, demand losses, and system peak demand factors across various customer segments such as domestic, industrial, and municipal. The data is presented in a structured format with multiple columns, including system coincident demand and load factor.

FOR JULY 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT D...

AI summary The text presents a detailed table with energy-related metrics, including sales losses, energy line losses, demand losses, and system factors for different customer classes and categories. It includes data for various sectors such as domestic, industrial, municipal, and others. The table also includes sub-totals and totals for different categories, as well as a note about redacted information.

FOR AUGUST 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT...

AI summary The document presents a table containing various metrics related to energy sales, losses, demand, and system performance for August 2026, including energy losses, demand factors, and system peak demand. It also includes a redacted section related to the ELID Tariff CA IR-2 Attachment 1.

SALES, GENERATION AND DEMAND ANALYSIS FOR SEPTEMBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8...

AI summary The document provides a detailed analysis of sales, generation, and demand for September 2026, including metrics such as energy sales, losses, demand factors, and system performance across various customer classes and sectors.

FOR OCTOBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDEN...

AI summary The document presents a table with various metrics related to energy sales, losses, and demand factors across different customer classes in Nova Scotia for October 2026. The table includes data on MWH sales losses, energy line losses, energy requirements, demand factors, and system peak demand factors. It also includes subtotals and totals for different categories, such as domestic, industrial, and municipal customers.

FOR NOVEMBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDE...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for different customer classes in November 2026, including energy line losses, demand losses, and system coincident demand factors. The data includes totals and subtotals for various categories, with some entries marked as redacted or confidential.

FOR DECEMBER 2026 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LINE LOSSES ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDE...

AI summary The table presents energy sales, losses, and demand data across various customer classes for December 2026, including metrics such as line losses, energy requirements, and demand factors. The data includes domestic, small general, general, large industrial, and other categories, highlighting energy consumption patterns and system performance.

FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) TOTAL (3) SMALL (4) (5) GENERAL (6) (7) SMALL MEDIUM LARGE (8) (9) (10) (11) (12) SHORE (13) (14) (15) (16) REAL TIME MONTH COMPANY DOMESTIC GENERAL GENERAL LARGE INDUST. INDUST. INDUST. ELI 2P...

AI summary This document presents a table of demand data across various months and categories for the year ending December 31, 2026, including figures for different company types and demand categories such as small, general, and large. It also includes total summed demand and 3 C/P demands and average demands.

DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW DEMAND FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (14) (15) (16) TOTAL SMALL GENERAL SMALL MEDIUM LARGE SHORE REAL TIME MONTH COMPANY DOMESTIC...

AI summary This document details monthly coincident kW demand across various customer classes in Nova Scotia for 2026, including breakdowns for small, medium, large industrial, and municipal sectors. It highlights demand patterns, interruptions, and firm large industrial demands, relevant to regulatory proceedings on energy management and tariff structures.

REDACTED ELID Tariff CA IR-2 Attachment 1 Page 89 of 94 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Line # AVERAGE RATE BASE RATE BASE 2025 RATE BASE 2026 (206) POWER PRODUCTION - HEAD OFFICE (207) POWER PRODUCTION - GEN. SERV. 2,583.0 (20...

AI summary The document presents a table outlining various rate base components for the years 2025 and 2026, including power production, purchased power, overhead expenses, and demand-side management (DSM) expenses. The table includes line items such as fuel procurement, biomass, wind, and imports, with corresponding figures for each year.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 (55) CLASS NON-COINCIDENT DMD EXPORT SALES (56) SYSTEM COINCIDENT DMD DOMESTIC 0 0 1,315,928 1,275,166 1,072,148 0 0 892,737 0 690,370 0 567,667 0 587,067 0 652,308 0 539,018 0...

AI summary The text provides a table with allocation factor information, including various demand categories and their associated values across different calendar months of system peak. The table includes data for non-coincident demand export sales, small general, general, large industrial, medium industrial, and industrial large demand categories.

EXHIBIT 6 PAGE 1 OF 6 (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION (10) OPER. & MAINT HYDRO (11) OPER. & MAINT WIND 2,092 7,450 1,383 4,926 73 261 380 1,353 44 155 40 142 46 164 78 27...

AI summary This exhibit presents a detailed breakdown of operational and maintenance costs across various energy generation and transmission categories, including hydro, wind, biomass, and others, along with depreciation and interest expenses. It also includes allocations related to demand-side management and regulatory affairs.

(IN THOUSANDS OF DOLLARS) Depreciation 172,385 61,484 49,872 283,741 (1) INTERR. RIDER DMD ADJ. (2) (5) (3) Dmd. in KWs (4) Int Credit Amount 69,857 11,207 (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (8) Demand Usage Annual Credit Amount Cal...

AI summary The document presents a table with depreciation figures and details related to demand adjustment calculations, including winter month demand, power factor adjustments, and credit amounts. It also references a redacted tariff attachment.

DEVELOPMENT OF ALLOCATION FACTORS (1) TOTAL (2) COMPANY DOMESTIC GENERAL GENERAL (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) PHP (10) (11) MUNICIPAL UNMETERED (12) ALLOCATION FACTOR (...

AI summary The document presents a detailed table outlining the development of allocation factors across various categories, including demand, generation, and purchase metrics, with percentages of responsibility assigned to different segments such as domestic, small, medium, and large industrial. It includes various data points and percentages related to demand and generation across different sectors.

FOR FEBRUARY 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LINE LOSSES ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDE...

AI summary The document presents energy usage and system demand statistics for February 2027, including details on energy sales, line losses, and demand factors across various customer classes and sectors in Nova Scotia.

FOR MARCH 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT...

AI summary The document presents a table with energy sales, losses, and demand metrics categorized by customer class for March 2027. It includes data on energy requirement, system coincident demand, and losses, as well as system peak demand and load factor. The table is part of a regulatory proceeding document and contains redacted information.

FOR APRIL 2027 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT...

AI summary The text presents a table with various metrics related to energy sales, losses, and demand factors across different customer classes and special programs in April 2027. It includes data on energy losses, demand factors, and system peak demand, but no explicit arguments or discussion of policy, regulation, or stakeholder positions are present.

NOVA SCOTIA POWER INC. SALES, GENERATION AND DEMAND ANALYSIS FOR MAY 2027 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMA...

AI summary The document presents a detailed breakdown of Nova Scotia Power Inc.'s sales, generation, and demand analysis for May 2027, including energy sales, losses, demand factors, and system performance metrics across various customer classes and programs.

FOR JUNE 2027 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT D...

AI summary The document presents a table with various energy metrics, including sales losses, energy line losses, demand line losses, and system factors, categorized by different customer classes and services. It includes totals and subtotals for different segments, such as domestic, industrial, and municipal, as well as special cases like Shore Power and ELIADC.

FOR JULY 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH LINE ENERGY COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSSES D...

AI summary The document presents a table with energy sales, losses, and demand metrics categorized by different customer classes for July 2027. It includes data on energy usage, losses, and demand factors across various sectors such as domestic, industrial, and municipal. The table also includes subtotals and totals, providing a comprehensive overview of energy consumption and distribution.

FOR SEPTEMBER 2027 (1) (2) (3) (4) (5) (6) (7) (8) (9) MWH ENERGY LINE ENERGY CLASS NON- COINCIDENT SYSTEM COINCIDENT SYSTEM COINCIDENT DEMAND LINE SYSTEM SYSTEM COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOS...

AI summary The document presents a table with energy sales, losses, and demand data categorized by customer class for September 2027. It includes metrics such as energy line losses, system coincident demand, and load factor, with data spanning various customer segments like domestic, industrial, and municipal.

FOR OCTOBER 2027 (1) (2) (3) (4) (5) (6) (7) (8) (9) ENERGY CLASS NON- SYSTEM SYSTEM DEMAND SYSTEM SYSTEM MWH LINE ENERGY COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSSE...

AI summary This table presents energy sales, losses, and demand data across various customer classes in Nova Scotia for October 2027, including metrics such as energy line losses, system requirement, and demand factors. It provides a detailed breakdown of energy usage and system performance across domestic, industrial, and other categories.

FOR DECEMBER 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH LINE ENERGY COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSS...

AI summary The document provides a detailed breakdown of energy sales, losses, and demand metrics across various customer classes for December 2027. It includes data on domestic, small general, general, industrial, and other categories, with percentages for losses and demand factors. The table also includes a subtotal and total for energy sales and demand, highlighting key metrics such as system losses and demand factors.

FOR THE YEAR ENDING DECEMBER 31, 2027 (1) (2) TOTAL (3) SMALL (4) (5) GENERAL (6) (7) SMALL MEDIUM LARGE (8) (9) (10) (11) (12) SHORE (13) (14) (15) (16) REAL TIME MONTH COMPANY DOMESTIC GENERAL GENERAL LARGE INDUST. INDUST. INDUST. ELI 2P...

AI summary This document presents a detailed table of demand data for various customer categories and months, including total demand, small, general, large, and shore categories, with specific values for each month from January to December 2027. It includes data for different types of demand, such as firm and interruptible rider demands.

DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW DEMAND FOR THE YEAR ENDING DECEMBER 31, 2027 (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (14) (15) (16) TOTAL SMALL GENERAL SMALL MEDIUM LARGE SHORE REAL TIME MONTH COMPANY DOMESTIC...

AI summary The document presents a detailed breakdown of monthly system coincident demand (in kW) across various customer classes (e.g., Small General, Large Industrial) for the year ending December 31, 2027, including totals and specific rider demands such as interruptible and firm large industrial demands.

PARTIALLY CONFIDENTIAL 1 Beyond the SA provisions, the notion that PHP would be assigned demand-related costs based on 2 8 MW would be clearly unfair and result is cost transfers to other classes and inconsistent with 3 long-established pr...

AI summary The text argues that assigning PHP a demand-related cost based on 8 MW would be unfair and inconsistent with Nova Scotia's established practices, as PHP's actual load and peak load are significantly higher than this figure, and it would avoid transmission cost responsibility.

NOVA SCOTIA POWER INC. (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION (8) BUTU CAPACITY CREDIT (8) OPER. & MAINT STEAM $0 60,953 - 30,438 - 2,062 - 12,906 - 2,031 - 1,481 - 2,523 - 3,89...

AI summary The document presents a detailed breakdown of operational and maintenance costs for various energy generation and management activities by Nova Scotia Power Inc., including capacity credits, hydro, wind, biomass, and other generation sources, along with DSM and FCR deferral allocations. It references specific cost allocations and board orders.

FOR THE YEAR ENDING DECEMBER 31, 2026 (1) MWH (2) ENERGY LINE (3) ENERGY (4) CLASS NON- SYSTEM (5) COINCIDENT COINCIDENT COINCIDENT (6) (7) LINE (8) SYSTEM DEMAND SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT (10) 3CP (11) 3CP % SALES LOSSES REQ...

AI summary The text presents a table with various energy-related metrics for the year ending December 31, 2026, including energy sales, losses, demand, and contribution factors. The table appears to be part of a regulatory proceeding related to energy usage and management.

FOR FEBRUARY 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEA...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for February 2026, categorized by customer class, including domestic, industrial, and municipal sectors. It includes metrics such as energy sales, energy losses, demand factors, and system demand, with totals and subtotals provided for different categories.

FOR MARCH 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEAK C...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for March 2026, categorized by different customer classes and sectors. It includes data on energy requirements, demand factors, and losses, providing a comprehensive overview of Nova Scotia Power Inc.'s sales, generation, and demand analysis for the month.

FOR APRIL 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEAK C...

AI summary The document presents a table with various metrics related to energy sales, losses, and demand factors categorized by customer class for April 2026. It includes data on MWH sales losses, energy line losses, demand line losses, and system peak load factors for different customer segments.

FOR JUNE 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEAK CO...

AI summary The document presents a detailed table of energy sales, generation, and demand analysis for June 2026, including metrics such as MWH sales losses, energy line losses, demand losses, and system factors for various customer classes and special programs.

FOR JULY 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEAK CO...

AI summary This document presents a detailed table of energy sales, generation, and demand analysis for July 2026, including metrics such as MWH sales losses, energy line losses, demand losses, and system factors for various customer classes and programs. It includes totals and subtotals for different categories, such as domestic, industrial, and special programs like ELIADC and EBS/RTR.

FOR AUGUST 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEAK...

AI summary This document presents a detailed analysis of electricity sales, generation, and demand for August 2026, including metrics such as MWH sales losses, energy line losses, demand losses, and system factors across various customer classes and special programs.

FOR SEPTEMBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PE...

AI summary The document presents a detailed table of electricity sales, generation, and demand analysis for September 2026, including metrics such as MWH sales losses, energy line losses, demand losses, and system factors across various customer classes and programs. It provides a breakdown of domestic, industrial, and special programs like ELIADC and EBS/RTR.

FOR OCTOBER 2026 (1) MWH (2) ENERGY LINE (3) ENERGY (4) CLASS NON- COINCIDENT (5) SYSTEM COINCIDENT (6) SYSTEM COINCIDENT (7) DEMAND LINE (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSSE...

AI summary The document presents a detailed breakdown of energy sales, generation, and demand analysis for October 2026, including various categories such as domestic, industrial, and municipal usage, along with metrics like losses, demand factors, and energy line requirements.

FOR NOVEMBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM DMD. (KW) (9) SYSTEM COIN. PEA...

AI summary This document presents a detailed table of energy sales, generation, and demand analysis for November 2026, including metrics such as MWH sales losses, energy line losses, demand losses, and system coincident demand factors across various customer classes and programs.

FOR DECEMBER 2026 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LINE LOSSES ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES DMD. (KW) COIN. PEA...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for different customer classes in December 2026, including domestic, industrial, and municipal sectors. It also includes subtotals for various programs and services such as ELIADC and EBS/RTR.

NOVA SCOTIA POWER INC. DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW PEAK DEMAND FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) TOTAL (3) SMALL (4) (5) GENERAL (6) (7) SMALL MEDIUM LARGE (8) (9) (10) (11) (12) SHORE (13) (14) (15) (16) REAL...

AI summary The document provides detailed monthly data on the peak demand for different classes of customers by Nova Scotia Power Inc. for the year ending December 31, 2026. It includes breakdowns by month, customer class, and demand categories such as small, general, and industrial.

DETAILED LISTING OF C.O.S.S. INPUT INFORMATION (197) POWER PRODUCTION (221) BUTU CAPACITY CREDIT 301.8 (222) OTHER OVERHEAD EXPENSES 7,377.5 6,487.4 890.13 System Planning and ECI (223) CURRENT YEAR INCENTIVE PLAN PAYOUT 0 (224) DSM EXPENS...

AI summary The table provides a detailed listing of C.O.S.S. input information, including various expenses and depreciation related to power production, DSM expenses, and generation assets. It includes figures for capacity credits, overhead expenses, incentive plan payouts, and depreciation for different energy sources such as hydro, wind, solar, and gas turbines.

FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (491) 539,847 565,309 562,705 (492) (493) AVERAGE CUSTOMERS - INDUSTRIAL LARGE (Transmission Connected) 8 (494) 2023 Test COSS (495) VOLTAGE LEVEL DMD. REDUCTION SEC GENERAL 9...

AI summary The text presents a table with data related to average customers, demand reduction percentages, and loss factor percentages for different voltage levels and customer categories. It also includes customer weighting factors for service drop investment, indicating varying weights assigned to different customer types.

(17) Int Credit Amount - PHP 558 (2) (5) (1) INTERR. RIDER DMD ADJ. (3) Dmd. in KWs (4) Int Credit Amount 69,857 11,207 (7) (6) PHP DEMAND ADJUSTMENT CALCULATION (8) Demand Usage Annual Credit Amount Calculation (9) Winter Month kW Coincid...

AI summary The document presents a table detailing an interruptible credit amount calculation, including demand usage, annual credit amount, and priority interruption premium calculations. It includes figures related to kilowatts, kilovolt-amps, and monetary values.

FOR THE YEAR ENDING DECEMBER 31, 2027 (1) TOTAL (2) COMPANY DOMESTIC GENERAL GENERAL (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) PHP (10) (11) MUNICIPAL UNMETERED (12) ALLOCATION FACT...

AI summary The document presents a detailed breakdown of demand, responsibility percentages, and energy generation and purchase data across various customer categories for the year ending December 31, 2027. It includes tables with figures and percentages, as well as references to different demand and generation categories.

FOR FEBRUARY 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LINE LOSSES ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDE...

AI summary This document presents a detailed analysis of energy sales, generation, and demand for February 2027, including metrics such as MWH sales, line losses, energy requirements, and demand factors across various customer classes and sectors.

FOR MARCH 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LINE LOSSES ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDENT...

AI summary The document presents a table with energy sales, line losses, energy requirements, and demand factors across various customer classes in March 2027. It includes data for domestic, small general, general, large industrial, and other categories, providing insights into energy usage and losses.

FOR JUNE 2027 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT D...

AI summary The document presents a table with various metrics related to energy sales, losses, and demand factors across different customer classes in June 2027. It includes data on MWH sales losses, energy line losses, demand losses, and system peak demand factors for different customer categories.

FOR AUGUST 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LOSSES LINE ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDENT...

AI summary The document presents energy data for August 2027, including sales losses, line losses, energy requirements, and demand factors across various customer classes. It provides a detailed breakdown of energy usage and losses for different sectors such as domestic, industrial, and municipal.

FOR SEPTEMBER 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH LINE ENERGY COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOS...

AI summary The document presents energy sales and demand data across various customer classes in September 2027, including metrics such as MWH sales, line losses, system energy requirements, and demand factors. The data includes breakdowns for domestic, small general, general, large industrial, and other categories, highlighting energy usage patterns.

FOR NOVEMBER 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LOSSES LINE ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDE...

AI summary The document presents a detailed analysis of energy sales, generation, and demand across various customer classes in Nova Scotia for November 2027. It includes metrics like MWH sales losses, line losses, energy requirements, and demand factors, categorized by domestic, industrial, and other classes.

FOR DECEMBER 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDE...

AI summary The table provides detailed data on energy sales, losses, and demand factors across different customer classes in December 2027. It includes metrics such as energy sales, energy losses, energy requirements, demand factors, and system peak demand. The data is categorized by customer type, including domestic, industrial, municipal, and others.

NOVA SCOTIA POWER INC. DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW PEAK DEMAND MONTH (1) TOTAL (2) COMPANY DOMESTIC GENERAL GENERAL (3) SMALL (4) (5) GENERAL LARGE (6) (7) SMALL MEDIUM LARGE (8) (9) (10) (11) INDUST. INDUST. INDUST. ELI 2...

AI summary The document presents a detailed table of monthly class system coincident kilowatt peak demand data for Nova Scotia Power Inc. over a 12-month period, including various categories such as domestic, small, large, and industrial demands, along with total summed demand and average demand figures.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (1) TOTAL (2) TOTAL (3) UNIT COST (4) TOTAL (5) (6) (7) VARIANCE CALC (233) OTHER OVERHEAD EXPENSES (234) CURRENT YEAR INCENTIVE PLAN PAYOUT 7,886.5 6,978.0 908.56 System Plan...

AI summary The document provides a financial summary of overhead expenses, incentive plan payouts, and various DSM expenses, including depreciation and accretion, for the year ending December 31, 2027. It includes data on generation-related assets and total generation expenses.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 January February March April May June July August September October November December Total (37) CLASS NON-COINCIDENT DMD DOMESTIC (38) CLASS NON-COINCIDENT DMD SMALL GENERAL (3...

AI summary The text presents a table detailing allocation factor information for different classes of non-coincident demand across various calendar months, including total figures. It provides data on domestic, small general, general demand, and small industrial demand categories.

EXHIBIT 6 PAGE 6 OF 6 (2) (5) (7) (1) INTERR. RIDER DMD ADJ. (3) Peak Dmd. in KWs (at Generator) (4) Int Credit Amount (6) PHP DEMAND ADJUSTMENT CALCULATION 69,594 11,165 (8) Demand Usage Annual Credit Amount Calculation (9) (10) Winter Mo...

AI summary The document presents a table with various demand adjustment calculations, including peak demand, credit amounts, and power factor adjustments. It includes values related to winter month demand, kilovolt-amps (kVA), and associated financial figures. The table also references priority interruption demand adjustments and associated credit amounts.

DEVELOPMENT OF ALLOCATION FACTORS (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION COMPANY DOMESTIC GENERAL GENERAL LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL PHP MUNICIPAL UNMETERED FACTOR (...

AI summary The document presents a table detailing the development of allocation factors across various categories, including demand, generation, and purchase responsibilities, along with percentages and associated codes for different sectors and customer types.

FOR JANUARY 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM...

AI summary This document presents a detailed table of energy sales, losses, and demand metrics for January 2026, categorized by customer class and including totals for various sectors such as domestic, industrial, and municipal. It provides insights into energy usage patterns, losses, and demand factors across different segments.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 January February March April May June July August September October November December Total (39) CLASS NON-COINCIDENT DMD SMALL GENERAL (40) CLASS NON-COINCIDENT DMD GENERAL DEM...

AI summary The text presents a table detailing allocation factor information across different classes of non-coincident demand for various months, including total values. The data reflects demand metrics for small general, general demand, large general, small industrial, and medium industrial classes.

38.463 (37) 1,013 973 5 272 4,451 30,284 744.230 37,743 (1) (2) SHORE GEN.REPL POWER LOAD FOLL. ELIADC BUTU SPILL (3) (4) (5) (6) PRICING (6) REAL TIME REAL TIME REAL TIME PRICING (6) PRICING (7) OATT (8) TOTAL BTL (22) (23) TOTAL ENTERPRI...

AI summary The text contains a table with various financial figures and categories, including enterprise services, human resources, other expenses, COGS, DSM expenses, FCR deferral, grants in lieu of taxes, and depreciation. These figures are likely related to a regulatory proceeding involving cost and expense reporting.

CLASSIFICATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (1) INTERMEDIATE CLASSIFICATION (20) DEPRECIATION 55,951 36,022 1,907 9,896 1,134 1,037 1,196 2,032 1,683 776 268 EXH 6D (21) INTEREST NET...

AI summary The document provides a classification of operating expenses for the year ending December 31, 2027, including depreciation, interest, taxes, and various adjustments related to demand management and other revenue streams.

DEMAND CLASSIFICATION (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (9) (10) (11) ALLOCATION (14) TOTAL - EHV 159,120 102,420 5,430 28,178 3,221 2,953 3,397 5,774 4,781 2,204 761 (15) (16) TOTAL TRANSMISSION 15...

AI summary The document presents a detailed breakdown of demand classification, including various categories such as operating and maintenance costs, depreciation, interest, and corporate taxes. It includes figures for different segments like small, general, medium, and large, along with associated exhibits and references.

SALES, GENERATION AND DEMAND ANALYSIS FOR THE YEAR ENDING DECEMBER 31, 2027 (1) MWH (2) ENERGY LINE (3) ENERGY SALES LOSSES REQUIREMENT DMD. (KW) (4) CLASS NON- SYSTEM (5) FACTOR (6) SYSTEM DEMAND SYSTEM COINCIDENT COINCIDENT COINCIDENT LI...

AI summary The document provides a detailed analysis of sales, generation, and demand for the year ending December 31, 2027, including metrics such as MWH, energy sales losses, system demand, and contribution percentages across various classes and pools.

-1A (13) OPER. & MAINT OTHER CT's 0 0 0 0 0 0 0 0 0 0 0 E-1A (14) OPER. & MAINT GENERATION BATTERIES 0 0 0 0 0 0 0 0 0 0 0 E-1A (15) OPER. & MAINT RADIAL TO GENERATION TRANS. 1,549 774 52 328 52 38 64 99 114 18 11 E-1A (16) DSM 0 See DSM A...

AI summary The document presents financial data for Nova Scotia Power, including operational and maintenance costs, depreciation, interest, taxes, and revenue from steam and ash sales. It also includes figures related to demand-side management (DSM) and regulatory affairs expenses.

FOR MAY 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT DM...

AI summary The document presents a detailed table with data on energy sales, losses, demand, and system factors for different customer classes in Nova Scotia for May 2026. It includes metrics such as MWH sales losses, energy line losses, demand losses, and system coincident demand factors, categorized by customer type and overall totals.

DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW DEMAND FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (14) (15) (16) TOTAL SMALL GENERAL SMALL MEDIUM LARGE SHORE REAL TIME MONTH COMPANY DOMESTIC...

AI summary The document presents monthly data on system coincident kilowatt demand for various customer classes in Nova Scotia for the year ending December 31, 2026. It includes detailed breakdowns of demand across different categories such as small general, medium large industrial, and others, with totals and interruptions listed at the end of the year.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 (38) CLASS NON-COINCIDENT DMD DOMESTIC (39) CLASS NON-COINCIDENT DMD SMALL GENERAL 1,567,908 87,055 1,440,464 78,286 1,226,893 71,125 1,030,722 57,863 850,197 53,355 593,240 51,...

AI summary The document presents a table with allocation factor information, including non-coincident demand data for various classes and months, providing detailed breakdowns across different sectors and demand categories.

(140) Class Non-Coincident Dmd (at cutomer's meter) Calendar Month of System Peak 1 (108) REQUIREMENTS - GENERAL 432,607 426,373 367,087 294,769 265,519 281,558 305,354 277,951 305,996 315,700 356,039 347,137 1,206,116.4 (109) REQUIREMENTS...

AI summary The document presents data on non-coincident demand across various customer classes in Nova Scotia, including requirements for different sectors such as general, large, industrial, municipal, and others. The data spans multiple calendar months and includes specific values for each category.

15 350 348 4 81 1,328 9,033 200 11,370 (33) (34) COGS - - - - - - - - - - (35) (36) DSM EXPENSES - - - - - - - - - - (37) (38) FCR DEFERRAL - - - - - - - - - - (39) (40) OTHER EXPENSES - - - - - - - - - - (41) (42) CAPITAL RELATED EXPENSES...

AI summary The text presents a financial and operational breakdown, including expenses related to DSM, FCR deferral, and depreciation across various energy generation and distribution assets such as steam, hydro, wind, and transmission lines.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL (7) MEDIUM INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) ELI 2P-RTP (10) (11) MUNICIP...

AI summary This table outlines operating and maintenance costs for various energy generation and management activities in Nova Scotia for the year ending December 31, 2027, categorized by different company types and sectors. It includes costs related to wind/biomass, LM6000, other generation units, radial transmission, demand-side management (DSM), and Fuel Cost Recovery (FCR) deferral.

NOVA SCOTIA POWER INC. ALLOCATION OF OPERATING EXPENSES Depreciation 172,149 61,713 49,872 (IN THOUSANDS OF DOLLARS) 283,734 (2) (1) INTERR. RIDER DMD ADJ. (3) Dmd. in KWs 69,857 (4) Int Credit Amount 11,207 (5) (6) PHP DEMAND ADJUSTMENT C...

AI summary The document provides a table and exhibit related to the allocation of operating expenses by Nova Scotia Power Inc., focusing on depreciation, demand adjustments, and credit amounts. It includes various calculations and figures related to energy usage and financial adjustments.

DEVELOPMENT OF ALLOCATION FACTORS (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION COMPANY DOMESTIC GENERAL GENERAL LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL PHP MUNICIPAL UNMETERED FACTOR (...

AI summary This section provides a detailed breakdown of allocation factors across various categories, including demand, generation, and customer data. It includes percentages of responsibility and numerical values for different segments such as small, general, and large industrial, as well as municipal and unmetered categories.

CLASSIFICATION OF OPERATING EXPENSES (1) INTERMEDIATE CLASSIFICATION (19) REG. AFFAIRS - ADVOCACY EXPENSE 628 305 48 247 0 28 0 0 0 0 0 R-2 (19) GRANTS IN LIEU 10,222 6,567 335 1,819 207 186 240 372 307 142 48 P-7 (20) DEPRECIATION 52,732...

AI summary The document presents a classification of operating expenses, including depreciation, interest, taxes, and various adjustments related to demand and revenue. Specific line items include advocacy expenses, grants in lieu, and allocations for demand adjustments.

NOVA SCOTIA POWER INC. ALLOCATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) INTERR. RIDER DMD ADJ. (3) Peak Dmd. in KWs (at Generator) 69,594 (4) Int Credit Amount 11,165 (5) (6) PHP DEMAND A...

AI summary The document presents Nova Scotia Power Inc.'s allocation of operating expenses for the year ending December 31, 2026, including tables and calculations related to demand adjustments and interruption credit amounts.

EXHIBIT 9C Page 1 of 3 MONTH (1) (2) TOTAL COMPANY DOMESTIC GENERAL GENERAL (3) SMALL (4) (5) GENERAL LARGE (6) (7) SMALL MEDIUM LARGE (8) (9) (10) (11) INDUST. INDUST. INDUST. ELI 2P-RTP MUNICIPAL UNMETERED POWER GRLF ELIADC BUTU PRICING...

AI summary The document presents a table with monthly energy demand data across various categories, including domestic, small, large, and industrial sectors. It includes specific metrics such as total company domestic general general, small, large, and industrial demand, as well as specific pricing categories like ELIADC and BUTU. The data spans from January to December and includes totals and averages for demand across these categories.

(300) Total 100.00% (301) (302) METER DATA SERVICES ALLOCATORS (480) AVERAGE CUSTOMERS - DOMESTIC (SEASONAL) 12,080 24,346 23,974 (481) AVERAGE CUSTOMERS - DOMESTIC (TOTAL) 488,926 490,213 487,639 (482) AVERAGE CUSTOMERS - SMALL GENERAL 27...

AI summary The text presents a table with various metrics related to meter data services allocators, including average customer numbers across different categories and voltage level demand reduction percentages, along with loss factor percentages for different power levels.

(IN THOUSANDS OF DOLLARS) NOVA SCOTIA POWER INC. DETAILED LISTING OF C.O.S.S. INPUT INFORMATION FOR THE YEAR ENDING DECEMBER 31, 2026

AI summary Nova Scotia Power Inc. provides a detailed listing of C.O.S.S. input information for 2026, including financial and operational data points such as capital works in progress, transmission and distribution costs, asset retirement obligations, demand-side management, and fuel cost recovery. The document outlines key inputs for regulatory analysis.

NOVA SCOTIA POWER INC. (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL (7) MEDIUM INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) ELI 2P-RTP (10) (11) MUNICIPAL UNMETERED (12) ALLOCATION FACTOR (8) B...

AI summary The document presents a detailed breakdown of operating and maintenance costs for various energy sources and categories under Nova Scotia Power Inc. It includes line items for steam, hydro, wind, biomass, and other generation types, as well as DSM and FCR deferral costs, with references to specific accounting entries and allocation factors.

(IN THOUSANDS OF DOLLARS) Depreciation 173,942 59,927 49,872 283,741 (1) INTERR. RIDER DMD ADJ. (2) (3) Dmd. in KWs 69,857 (4) Int Credit Amount 11,207 (5) (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (16) Sum of Monthly Demands in KVAs (at t...

AI summary The text provides a table and figures related to depreciation and demand adjustment calculations, including values for demand in kilowatts and credit amounts. These figures are likely part of a regulatory proceeding related to utility costs and adjustments.

(15) (8) Demand Usage Annual Credit Amount Calculation Winter Month kW Coincident Power Factor Adjustment Winter Month kVA Coincident Sum of 12 Month kVA LIR Int Credit ($/kVA) Base Amount % Premium For Priority Priority Premium Preimum Am...

AI summary The text presents a table related to demand usage and credit amount calculations, including winter month kW and kVA coincident demand, power factor adjustments, and priority interruption credits. It includes figures such as 727,660 kW and 57,000 kVA, along with credit amounts and percentages.

DEVELOPMENT OF ALLOCATION FACTORS (1) TOTAL (2) COMPANY DOMESTIC GENERAL GENERAL (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) PHP (10) (11) MUNICIPAL UNMETERED (12) ALLOCATION FACTOR (...

AI summary The document presents a table detailing the development of allocation factors, including various demand and generation metrics across different categories such as domestic, small, medium, and large industrial sectors, as well as municipal and PHP (Peak Hour Pricing) categories. Each row provides numerical data and percentages of responsibility for different allocation factors.

DETERMINATION OF CLASS NON-COINCIDENT KW DEMAND BY VOLTAGE LEVEL INDUSTRIAL INDUSTRIAL INDUSTRIAL ELI 2P-RTP MUNICIPAL UNMETERED 0 21,982 0 778 0 22,760 14,918 22,760 77 870 14,995 23,631 14,995 23,631 19 226 15,014 23,856 3.54% 3.54% 0.51...

AI summary The document presents data related to the determination of class non-coincident KW demand by voltage level, including numerical figures and percentages across different categories such as industrial, municipal, and unmetered. The data appears to be part of an exhibit submitted in a regulatory proceeding.

NOVA SCOTIA POWER INC. ALLOCATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL (7) MEDIUM INDUSTRIAL INDUSTRI...

AI summary The document presents an allocation of operating expenses for Nova Scotia Power Inc. for the year ending December 31, 2026, detailing various adjustments and allocations across different categories and customer segments, including items like demand adjustments and transmission costs.

NOVA SCOTIA POWER INC. (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL (7) MEDIUM INDUSTRIAL INDUSTRIAL INDUSTRIAL (8) LARGE (9) ELI 2P-RTP (10) (11) MUNICIPAL UNMETERED (12) ALLOCATION FACTOR (8) B...

AI summary The document presents a detailed breakdown of various operational and maintenance costs across different categories and customer segments for Nova Scotia Power Inc., including specific line items such as capacity credit, hydro, wind/biomass, biomass, and other generation-related expenses, along with references to allocation factors and related documents.

(1) (2) (3) (4) (5) (6) (7) (8) (9) ENERGY CLASS NON- SYSTEM SYSTEM DEMAND SYSTEM SYSTEM MWH LINE ENERGY COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDENT MWH LINE ENERGY COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDEN...

AI summary The text presents a table with energy class data including MWH, line losses, energy requirement, and demand factors for various categories such as domestic, small general, general, and industrial sectors. The table includes metrics for different energy classes and their respective percentages and values.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 (64) SYSTEM COINCIDENT DMD MUNICIPAL 30,554 31,787 29,574 21,281 15,211 15,569 15,996 14,852 15,466 21,694 23,770 27,793 30,554.2 (65) SYSTEM COINCIDENT DMD UNMETERED 10,903 4,0...

AI summary The text presents a table with data on system coincident demand across different categories, including municipal, unmetered, shore power, and interruptible demand, for various months. The data includes values for different demand types and their totals, indicating variations in demand over time.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (11) (12) (13) OPER. & MAINT BIOMASS OPER. & MAINT LM6000 OPER. & MAINT OTHER CT's 6,547 629 0 3,454 332 0 238 23 0 1,440 138 0 231 22 0 169 16 0 273 26 0 443 43 0 167 16 0 80...

AI summary The document presents a detailed financial table for the year ending December 31, 2027, outlining operating and maintenance costs across various energy generation and management categories, including biomass, LM6000, other combined cycle turbines, generation batteries, and radial transmission. It also includes entries related to Fuel Cost Recovery (FCR) deferral, regulatory affairs, and grants in lieu, with specific allocations noted for DSM.

NOVA SCOTIA POWER INC. SALES, GENERATION AND DEMAND ANALYSIS FOR JANUARY 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7)...

AI summary The document provides a detailed analysis of Nova Scotia Power Inc.'s sales, generation, and demand for January 2027, including metrics such as energy sales, losses, and demand factors. The data is presented in a tabular format with various categories and subtotals.

NOVA SCOTIA POWER INC. SUMMARY OF SYSTEM DEMAND LINE LOSSES FOR THE YEAR ENDING DECEMBER 31, 2027

AI summary This document provides a summary of system demand line losses for Nova Scotia Power Inc. for the year ending December 31, 2027. It outlines the performance of the electrical distribution system in terms of energy losses.

DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW PEAK DEMAND MONTH (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUST. (7) MEDIUM INDUST. (8) LARGE INDUST. (9) ELI 2P-RTP (10) MUNICIPAL UNMETERED (1...

AI summary The document presents a detailed breakdown of monthly system coincident kilowatt peak demand by class across various months in a year, including data for different customer segments such as domestic, general, industrial, and others, as well as specific charges like ELIADC and real-time pricing.

REVENUE TO EXPENSE COMPARISON (1) TOTAL DMD.RELATED (2) TOTAL ENG.RELATED (3) UNIT COST ENG.RELATED (4) TOTAL CUST.RELATED (5) TOTAL OPER. (6) TOTAL RATE (7) % REVENUE VARIANCE CALC (220) PURCHASED POWER - Imports (221) BUTU CAPACITY CREDI...

AI summary The document presents a revenue-to-expense comparison, including various categories such as purchased power, overhead expenses, DSM expenses, depreciation, and generation costs. It details figures for different types of expenses and their adjustments, providing a comprehensive financial overview for analysis.

ALLOCATION FACTOR INFORMATION ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 (78) PHP INTERRUPTIBLE COINCIDENT DEMAND AT GENERA January 0 February 0 March 0 April 0 May 0 June 0 July 0 August 0 September 0 October 0 November...

AI summary The document presents allocation factor information, including demand line loss adjustments for different customer categories across various months. It includes data on interruptible coincident demand, voltage level demand reduction, and loss factor percentages for secondary, primary, and transmission levels.

(IN THOUSANDS OF DOLLARS) FOR THE YEAR ENDING DECEMBER 31, 2027 ALLOCATION FACTOR INFORMATION ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 January February March April May June July August September October November Decemb...

AI summary The document presents allocation factor information for the year ending December 31, 2027, including details on demand line loss adjustments and interruptible coincident demand at various voltage levels. The data spans different months and includes figures related to loss factors and reductions in demand.

DEMAND CLASSIFICATION (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (9) (10) (11) ALLOCATION (16) TOTAL TRANSMISSION 139,467.00 92,342 4,721 25,616 2,914 2,625 3,366 5,225 0 1,991 668 (17) (18) DISTRIBUTION (19...

AI summary The text presents a detailed breakdown of demand classification, including various categories such as transmission, distribution, operating and maintenance costs, depreciation, interest, and corporate taxes. It includes figures for different classifications like small, general, medium, and large, along with associated expenses and revenues.

NOVA SCOTIA POWER INC. ALLOCATION OF OPERATING EXPENSES (1) INTERR. RIDER DMD ADJ. (2) (3) (4) Peak Dmd. in KWs (at Generator) Int Credit Amount 69,594 11,165 (5) (6) (7) PHP DEMAND ADJUSTMENT CALCULATION (8) Demand Usage Annual Credit Amo...

AI summary The document presents a table related to Nova Scotia Power Inc.'s allocation of operating expenses, specifically focusing on demand adjustment calculations and priority interruption credit amounts. The table includes data on peak demand, power factor adjustments, and credit calculations, though many fields are populated with zeros or missing information.

CLASS : LARGE GENERAL CLASS : LARGE GENERAL RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fixed Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy Customer Generation (1) Usage (Energy) $53,102 $24,...

AI summary The document presents a detailed breakdown of costs related to generation, transmission, and distribution, including variable and fixed costs, unit costs, and energy and demand metrics. It outlines the financial structure of the rate base and provides figures for fuel, operating, capital, and return costs.

CLASS : UNMETERED CLASS : UNMETERED 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) $11,743 $5,458 $561 $833 $411 $1,806...

AI summary The text presents a detailed breakdown of costs for the 'UNMETERED' class, including generation, transmission/distribution, and various cost components such as fuel, operating, capital, and return. It includes metrics like unit costs, energy sales, and demand figures.

DETAIL OF MONTHLY CLASS SYSTEM COINCIDENT KW PEAK DEMAND FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) (12) (13) (14) (15) (16) MONTH TOTAL COMPANY DOMESTIC SMALL GENERAL GENERAL GENERAL LARGE SMALL IN...

AI summary The document presents a detailed breakdown of monthly class system coincident kilowatt (KW) peak demand for the year ending December 31, 2026, categorizing demand by different classes such as domestic, small general, large industrial, and others. The data includes total demand, average demand, and specific rider demands for different sectors.

(IN THOUSANDS OF DOLLARS) (401) REAL TIME PRICING (402) OATT (403) EBS 1,277.0 625.1 10,878.3 70,801,052.523 1,277.0 625.1 10,878.3 0.000 0.000 (452) RETAIL SALES - SMALL INDUST. (453) RETAIL SALES - MEDIUM INDUST. (454) RETAIL SALES - LAR...

AI summary The document presents a detailed financial breakdown of various revenue and cost categories related to electricity services in Nova Scotia, including real-time pricing, retail sales, and cash working capital distribution, along with percentages and figures for different customer segments and services.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (14) (15) OPER. & MAINT GENERATION BATTERIES OPER. & MAINT RADIAL TO GENERATION TRANS 0 1,960 0 1,061 0 73 0 442 0 71 0 52 0 84 0 136 0 0 0 25 0 16 E-1A E-1A (16) (17) (18) (1...

AI summary The document presents financial data for the year ending December 31, 2027, including operational and maintenance costs for generation batteries, radial transmission, and other related expenses. It also includes details on demand-side management (DSM), deferred charges (FCR deferral), regulatory affairs, and grants in lieu.

ALLOCATION OF OPERATING EXPENSES Depreciation 173,663 60,064 49,869 283,596 (1) INTERR. RIDER DMD ADJ. (2) (3) (4) Dmd. in KWs Int Credit Amount 69,857 11,207 (5) (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (8) Demand Usage Annual Credit Amo...

AI summary The document presents a table related to the allocation of operating expenses, including depreciation and demand adjustment calculations. It includes details on demand usage, credit amounts, and interruptions, with specific figures and calculations for different months and categories.

NSPI Responses to Industrial Group Information Requests 1 Response IR-11: 2 3 (a) Please refer to Attachment 1. Please also refer to SBA IR-2 part (i). 4 5 (b) The Nova Scotia Power System Operator internal interruptible procedures are fou...

AI summary NSPI responds to information requests regarding industrial group inquiries. The response includes references to internal procedures, the lack of analysis on Priority Interruptible (PI) service value, and the continuation of PHP's PI service commitment under the ELIADC Tariff. Evaluation of the impact of discontinuing this service is proposed for the next General Rate Application.

Background – What is Interruptible Load? - The value of interruptible load to the System Operator is its ability to alleviate capacity shortfall in 10-minutes, a period rooted in reliability standards which require returning interties to s...

AI summary Interruptible load is valuable to the System Operator for quickly addressing capacity shortfalls within 10-minutes, aligning with reliability standards requiring interties to return to scheduled values within 15-minutes of a resource contingency. Priority interruptible load is prioritized in addressing these shortfalls.

Background – Value of Interruptible Load - Interruptible load is non-firm load which NS Power excludes from long-term resource planning. - Interruptible load is served when the energy is available on the system. If a capacity shortfall occ...

AI summary Interruptible load is non-firm load that NS Power excludes from long-term planning. It is served when energy is available, but may be interrupted during capacity shortfalls. Customers with Telemetry & Control can be included in real-time reserve metrics and may avoid interruptions during reserve deficiencies.

ELIIR (introduced in 2003) – M05656 - Designed to: - o enhance operational flexibility by allowing more immediate access to large blocks of interruptible load; - o reduce fuel and purchased power costs through economic interruptibility, li...

AI summary The ELIIR program, introduced in 2003, aims to enhance operational flexibility and reduce costs by offering lower rates to large customers in exchange for higher interruption risk. Priority was given to SEB (Stora Enso & Bowater) over other interruptible customers. The program incentivized high load factors and improved customer satisfaction through cost control.

ELIIR-2 (introduced in 2006) – M05550 - Board Decision stated priority interruptibility has value for: - o Historical value and system-wide benefits. - o System reliability ("keeping the lights on") - o Planning flexibility and avoided pea...

AI summary The Board Decision emphasizes the value of priority interruptibility under ELIIR-2, highlighting its contributions to system reliability, planning flexibility, and reduced interruption risk. A 15% premium for priority interruptibility is introduced, with the cost to be allocated to all other customers.

Current Order of Interruptibility As provided in the Extra Large Industrial Active Demand Control Tariff: - In the event an interruption call is required in order to avoid shortfalls in system electricity supply, interruptible load will be...

AI summary The Extra Large Industrial Active Demand Control Tariff outlines the order in which interruptible load will be called upon to provide capacity to NS Power during system electricity supply shortfalls. The order is: Generation Replacement and Load Following (GRLF) Tariff, Extra Large Industrial Active Demand Control Tariff, Shore Power Tariff, and Interruptible Rider to the Large Industrial Tariff.

Value Assessment – Illustrative Example 1 - Scenario NSPSO is reserve deficient and experiences an unexpected loss of a large generator in the NS balancing area resulting in a contingent flow of power from NB to NS on the intertie. - Under...

AI summary In a scenario where Nova Scotia Power Inc. (NSPI) faces a reserve deficiency due to a generator loss, the system must quickly restore balance by activating load management procedures. All interruptible customers are treated equally in terms of load relief, with no incremental value assigned to any specific class of customer.

Value Assessment – Illustrative Example 2 - Scenario NSPSO experiences a capacity shortfall and reserve deficiency due to load exceeding forecast, resulting in the need to shed interruptible customers. - NSPSO implements load management pr...

AI summary This example illustrates a scenario where NSPSO faces a capacity shortfall and must interrupt load, prioritizing GRLF and ELIADC customers to avoid interrupting lower rank-order customers, including Shore Power and Large Industrial Interruptible Customers, without providing incremental value to the power system.

Conclusions - NS Power concludes that there is no system need or benefit for Priority Interruption all forms of 10-minute interruptible load provide the same level of load management capability. - There may be benefit provided by higher ra...

AI summary NS Power concludes that 10-minute interruptible load does not provide additional system benefits and that while higher rank-order customers may benefit from less frequent interruptions, this benefit is not universal across all customers.

Recommendation • Review conclusions with PHP to determine whether Priority Interruption services should be maintained.

AI summary The recommendation suggests reviewing conclusions with PHP to determine if Priority Interruption services should be maintained, indicating a focus on demand-side management and regulatory considerations.

NSPI Responses to Industrial Group Information Requests 1 Request IR-12: 2 3 (a) Where PHP's load under ELIADC was optimized along with other supply resources 4 in the development of the day-ahead dispatch plan to provide the least cost di...

AI summary NSPI responds to questions about the optimization of PHP load under ELIADC and ELID DR, confirming that PHP load is economically dispatched and not counted as synchronized reserve if already part of other demand response programs. It also confirms that ELID DR provides full authority for dynamic dispatch of PHP.

Part A – Definitions ADC: Active Demand Control. ADC Dispatchable Rider Operating Procedure (Operating Procedure): This Pprocedure document maintained by Nova Scotia Power System Operator (NSPSO) and Nova Scotia Power Energy & Risk Managem...

AI summary This section defines key terms related to Nova Scotia's electricity management, including ADC (Active Demand Control), Dispatchable Rider, and CBL (Customer Baseline Load). It outlines procedures for managing load and calculating benefits under the ELID Tariff.

Part B – Protocol Forecasting and Operation - (1) Annually, no later than the seventh business day of NovemberQuarterly, NS Power will forecast the Monthly Demand Schedule, Weekly Demand Schedule, and monthly and weekly limits based on PHP...

AI summary NS Power is required to provide regular forecasting and operational coordination with PHP, including monthly and weekly demand schedules, updates during the year, and advance notice of shutdowns for both parties. These processes ensure alignment in system planning and operational efficiency.

Part C – Conditions - (9) Subject only to reasons of health, safety, environmental, system reliability, equipment failures, and Force Majeure events, PHP must not deviate from the NS Power/NSPSO final demand schedule. NS Power/NSPSO must c...

AI summary Part C outlines conditions for PHP's operations, emphasizing compliance with demand schedules, communication during disruptions, tracking deviations, and collaboration between NS Power, NSPSO, and PHP. It includes procedures for maintaining 24/7 operations teams, handling outages, and ensuring dispatch decisions align with system needs and agreed schedules.

Part D – Operating Mode Characteristics Schedule For the purpose of planning, dispatch and forecasting, PHP's loading levels will be separated into seven (7)9 distinctive operating modes. Only one mode will be able to operate at any given...

AI summary Part D outlines the Operating Mode Characteristics Schedule, which divides PHP's loading levels into seven operating modes for planning, dispatch, and forecasting purposes. The schedule includes details on operating levels, ramp rates, outages, pulp storage, and line modes, and is used for calculating CBL incremental costs and ADC benefitDispatchable Rider Credit.

CONFIDENTIAL (Attachment Only) - The requested timeline for each event where a customer has been provided with an Advisory, Alert, or Interruption request, including showing the dispatch of NS Power resources and PHP load under the ELIADC...

AI summary NS Power explains that detailed timelines for customer advisories, alerts, and interruptions under the ELIADC Tariff are not readily available due to data complexity. They also clarify that no interruption calls have been initiated under the ELIADC Tariff since 2020 and that only interruptible customers with Telemetry & Control are held in reserve.

NSPI Responses to Industrial Group Information Requests 1 Request IR-15: 2 3 (a) Given the DR enables NSPI to actively manage PHP's load in real time in response to 4 system conditions, please identify the specific incremental system capab...

AI summary NSPI is responding to an inquiry from an industrial group regarding the differences between priority interruptibility and DR dispatch, including the incremental system capability, calculation models, and conditions under which priority interruptibility may be used separately from DR.

NON-CONFIDENTIAL 1 (AGC) volumes will be included on PHP's bill as appropriate and PHP will be 3 (a) Using NSPI's spreadsheet (N-1(i), Att.1), provide a class-level breakdown showing 4 how fuel-cost allocation decisions under the ELID tari...

AI summary The document discusses how changes in fuel costs and dispatch flexibility under the ELID tariff affect FAM allocations for LI and MI customers. It also explores the impact of overestimating annual savings on FAM costs. The DR rider isolates FAM customers from changes in system fuel costs due to PHP load adjustments.

NON-CONFIDENTIAL 1 Tariff, if PHP adopts this tariff) load are already counted as part of 10-minute operating 2 1 reserve. 3 4 The rationale for this approach is that interrupting a T&C customer at this point does not 5 increase the amount...

AI summary This text discusses the capacity emergency procedure in Nova Scotia, focusing on how load interruption is managed to maintain 10-minute operating reserve. It explains that interrupting T&C customers does not increase reserve but converts load to generation reserve. ELIADC/ELID Tariff load is prioritized for interruption during reserve activation to meet energy demands or assist neighboring entities.

NON-CONFIDENTIAL (b) The benefit of load shifting is calculated by comparing the annual realized PHP hourly load pattern to an equivalent annual Customer Baseline Load (CBL) hourly load pattern. The CBL load consists of a flat PHP base loa...

AI summary NS Power explains that the benefit of load shifting is calculated annually by comparing the actual PHP load to a randomized CBL load. Interim metrics based on deviations from optimal dispatch are used as a transparent indicator until year-end. Non-compliance with dispatch requests can be tracked and reported quarterly, but the Dispatchable Rider credit is calculated annually and subject to FAM audit.

18 Table 1 – 2024-2025 Historical PHP 3CPs, updated for Demand Losses Date Hour Net System Requirement (kW) PHP Load (kW) Loss adjusted PHP Load (kW) 2024-01-19 1800 2,014,636 2024-02-21 0800 2,088,113 2024-12-22 1800 2,072,986 2025-01-30...

AI summary Table 1 presents historical data on 2024-2025 PHP 3CPs, adjusted for demand losses, including dates, hours, and net system requirements in kW. The table shows specific instances of system load at different times, but lacks detailed information on adjustments or analysis.

NSPI Responses to NSEB Information Requests 1 Request IR-1: 12 provided in the Application, "NS Power proposes that priority interruptible service and the 13 compensation to PHP, as modeled, be maintained until it can be revisited in the n...

AI summary NSPI provides responses to NSEB information requests regarding proposed priority interruptible service and compensation to PHP. The cost of service for 2026 and 2027 is outlined, with values to be reviewed in the next GRA. System planning and operations benefits from PHP's PI service are to be examined.

NSPI Responses to NSEB Information Requests 1 cost to serve the NS Power dispatched PHP load. (i.e. the credit for DR will equal the 2 benefit of DR, returning the FAM to the same result as if PHP had run flat without DR.) 3 4 (c) Per the...

AI summary NSPI responds to NSEB information requests regarding the cost of serving PHP load, the allocation of savings from demand response, and concerns about the proposed ATL tariff. NSPI explains that under the ELIADC Tariff, PHP would accrue full benefits from dispatching load, and highlights concerns about the ATL tariff's impact on PHP.

NSPI Responses to Port Hawkesbury Paper Information Requests 1 Request IR-1: 2 3 Reference: Application, page 5, lines 15-17. 4 5 "In accordance with the Company's Cost of Service Study (COSS), demand 6 7 related costs are proposed to be a...

AI summary NSPI responds to information requests related to the allocation of demand-related costs to the ELID Tariff class based on PHP assigned demand at the time of three coincident peaks (3CP), and the unavailability of data on hourly Net Load breakdown by customer class due to a cyber incident.

NSPI Responses to SBA Information Requests 1 Request IR-1: 2 3 Refer to M12661, Exhibit N-1, the Application for Approval of an Above-the-Line Tariff 4 applicable to Port Hawkesbury Paper (the "Application"), Section 2.2 Demand Charge, 5 s...

AI summary NSPI is responding to SBA information requests regarding the Application for Approval of an Above-the-Line Tariff applicable to Port Hawkesbury Paper. The request includes questions about demand charge rationale, definitions, historical 3CP data, and billing practices.

NON-CONFIDENTIAL Request IR-3: Regarding interruptible events since 2020, please provide the following separately for both PHP and LIIR customers: (a) The number of events (b) The MW reduction below 65MWs for PHP, and the MW reduction for...

AI summary The response to Request IR-3 indicates that there have been no interruption-related load reductions initiated for PHP customers since 2020. For LIIR interruptions, details are provided in confidential attachments. No interruption hours were capped due to tariff restrictions, and there were no non-performance issues.

NON-CONFIDENTIAL 1 randomized throughout the year to simulate the non-dispatched and thus unpredictable 2 customer load, which would not be concentrating full-day outages in high price periods to 3 achieve an economic benefit. The comment...

AI summary The text discusses the ELID Tariff and the Dispatchable Rider (DR) for PHP, emphasizing alignment of ATL customer interests. It notes the need for randomized outage simulations to avoid economic biases and references Synapse and SBA documents. The DR aims to credit PHP fully for load dispatch, ensuring cost alignment.

NSPI Responses to Synapse Energy Economics, Inc. Information Requests 1 Request IR-1: 15 16 (d) Please provide the timing (date and hour) and load reductions (MW) of direct control 17 actions of PHP in 2022, 2023, 2024, and 2025. 18 19 (e)...

AI summary The document outlines several information requests directed at NSPI, seeking details on load reductions from PHP during specific years, non-NS Power tariff-related load shifting actions, system peak load data, and whether PHP load was curtailed while LIIR customers were not interrupted.

REDACTED 1 (d) Please refer to Confidential Attachment 2. Note the Cause Code "NDN" identifies the 2 down dispatches initiated by the Nova Scotia Power System Operator. 3 4 (e) There are no non-NS Power tariff related load shifting actions...

AI summary The text discusses load reductions initiated by Nova Scotia Power and the Nova Scotia Power System Operator (NSPSO) for PHP under the ELIADC Tariff, noting that these reductions are not classified as 'gray area reductions' and are governed by the ELIADC Tariff Protocols. It references attachments containing details on dispatch codes, load shifts, and operating procedures.

1 (h) For all 25 instances where LIIR customers were interrupted in the period 2022-2025 2 inclusive, PHP's load was either dispatched down by NS Power Energy Marketing ahead 3 of time due to forecasted system conditions or dispatched down...

AI summary The document discusses 25 instances of LIIR customer interruptions between 2022-2025, where PHP's load was dispatched down by NS Power Energy Marketing or NSPSO due to system conditions. Under the ELID Tariff, LIIR interruptions are anticipated during capacity shortfalls, with potential reductions in load if capacity issues worsen.

Part A – Definitions ADC : Active Demand Control. ADC Operating Procedure : Procedure document maintained by Nova Scotia Power System Operator (NSPSO) that describes the operation and usage of ADC for the NSPSO for Current Hour, Operating...

AI summary Defines key terms including Active Demand Control (ADC), Customer Baseline Load (CBL), and Dispatchable Hours, with references to Nova Scotia Power (NS Power), Nova Scotia Power System Operator (NSPSO), and Port Hawkesbury Paper LP (PHP). Establishes procedures for demand scheduling and tariff structures.

Part C – Conditions - (9) Subject only to reasons of health, safety, environmental, system reliability, and Force Majeure events, PHP must not deviate from the NS Power/NSPSO final demand schedule. NS Power/NSPSO must comply with the weekl...

AI summary Part C outlines conditions for PHP's adherence to demand schedules, collaboration with NS Power/NSPSO, handling deviations, and maintaining communication. It emphasizes compliance with system reliability, health/safety, and Force Majeure events, with adjustments tracked and reconciled quarterly. ADC credits may be adjusted based on system cost impacts.

Part D – Operating Mode Characteristics Schedule For the purpose of planning, dispatch and forecasting, PHP's loading levels will be separated into 9 distinctive operating modes. Only one mode will be able to operate at any given time. The...

AI summary PHP's operating modes are structured into 9 distinct levels for planning and dispatch, with NS Power and NSPSO required to adhere to these schedules. The schedule includes parameters like ramp rates, energy requirements, and ADC benefits, and can be modified by agreement between PHP and NS Power.

CONFIDENTIAL (Attachment Only) 1 Request IR-6: 2 3 Refer to the Application, p. 3, regarding the ELID tariff being based on the Large Industrial 4 tariff. 5 6 (a) In Excel with working formulas and all billing determinants, please provide...

AI summary The document requests Nova Scotia Power Inc. (NSPI) to provide detailed bill calculations for Port Hawkesbury Paper LP (PHP) under the Large Industrial (LI) and Real Time Pricing tariffs for 2023-2024, including load differences and impacts on billing. It also asks whether PHP's load would have varied under these tariffs and how that would affect costs.

NSPI Responses to Synapse Energy Economics, Inc. Information Requests 1 Request IR-7: 2 3 Refer to the Application, p. 3, lines 13-15. Are there any differences between the 4 "Dispatchable Rider" under the ELID tariff and the "Active Deman...

AI summary NSPI responds to Synapse Energy Economics, Inc.'s information requests regarding differences between the Dispatchable Rider under the ELID tariff and Active Demand Control under the ELIADC Tariff, and the derivation of PHP's firm load at 8MW for 3CP and the 65 MW of firm plus interruptible load.

Date Filed: April 10, 2026 NSPI (Synapse) IR-19 Page 2 of 2 1 Request IR-20: 2 purpose of calculating the Threshold Penalty, NS Power applied the following 3 assumptions: 4 5 • Firm billing is calculated using the proposed ELID Tariff rate...

AI summary The document outlines the assumptions used by NS Power in calculating the Threshold Penalty, including the use of the ELID Tariff rates, a zero DSM Cost Recovery Rider, and assumptions about peak demand, energy consumption, and power factor. Attachments provide detailed calculations of the Threshold Penalty and hypothetical weekly bills under the ELID Tariff.

Account Number: Billing Determinants Monthly Bill (for the purposes of calculating the Threshold Penalty, to be added to the end-of-month weekly bill) kWh Total Actual Load 40,000,000 Net Load 40,000,000 Charges Monthly Charges Customer Ch...

AI summary This table outlines the monthly billing details for a customer, including charges such as customer charge, demand charge, energy charge, and various riders. The total amount after HST is listed as approximately 5,575,609.02.

$ 9,380,745.43 Total Amount After HST 1 Request IR-22: 2 3 Refer to the Application, ELID Tariff Attachment 1, p. 6. 4 5 (a) Please provide a list of penalty payments incurred by PHP in 2022, 2023, 2024 and 6 2025. Please provide the date...

AI summary The document discusses penalty payments and interruptibility orders related to PHP under the ELID Tariff. It notes that no penalties were incurred by PHP from 2022 to 2025, and provides context on the Order of Interruptibility, including capacity tiers and dispatchability considerations.

REDACTED 1 The Shore Power Tariff, listed as third in the order on interruptibility, is available to cruise 2 ships docked in ports during non-winter months. As is the case with the customers under 3 the GRLF Tariff, cruise ships have thei...

AI summary The Shore Power Tariff is available to cruise ships during non-winter months and provides priority interruptibility status, exempting them from demand-related costs. Winter peak load reduction data is referenced in Attachment 1, though actual load relief may differ from stated values.

1 There is currently only one customer on the GRLF tariff (also taking service under the LIIR) who provides GRLF load relief on the order of several hundred kilowatts, a small amount which is not considered material in the Capacity and Ene...

AI summary The document notes that there is only one customer on the GRLF tariff who provides a small amount of load relief, which is not considered material in emergency procedures. This customer's GRLF load is combined with its LIIR load and interrupted during LIIR interruption calls for operational simplicity.

Tier 4 – LIIR Tariff[2](#page-61-0) 3 : Please refer to Synapse IR-5 part (j). 4 5 (d) Dispatchability and Interruptibility are two separate and distinct concepts within the ELID 6 Tariff construct. Dispatchability refers to the capability...

AI summary The text discusses the distinction between dispatchability and interruptibility within the ELID Tariff construct, noting that dispatchability involves re-dispatching PHP load by NS Power or NSPSO, while interruptibility refers to the ability to interrupt non-firm load during system emergencies. It also mentions that PHP is typically dispatched down during periods of expected capacity shortfall.

CONFIDENTIAL (Attachment Only) would be completed at the end of the year to account for not just load shifting between hours but also months. Please see Synapse IR-16 part (a) for a calculation of DR credit methodology and can be used as a...

AI summary The text outlines methods for calculating DR credits, fuel cost savings from PHP's load management under the ELID Tariff, and two scenarios (A and B) explaining billing impacts. It references Synapse IR-16 and a Settlement Agreement, noting that fuel cost savings require annual dispatch comparisons in PortOps, not Excel.

NOVA SCOTIA POWER INC.

AI summary The document pertains to Nova Scotia Power Inc., a utility company involved in regulatory proceedings. It includes acronyms and contextual information relevant to energy management, pricing, and regulatory frameworks in Nova Scotia.

EXHIBIT 3 PAGE 1 OF 5 (1) TOTAL COMPANY (2) DOMESTIC GENERAL (3) SMALL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) LARGE INDUSTRIAL (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATION FACTOR (1) DEMAND CL...

AI summary This document presents a table with various demand classification categories, including Total Company, Domestic General, Small, General, Large, Small Industrial, Medium Industrial, Large Industrial, PHP, Municipal, and Unmetered, along with an Allocation Factor column. The table is part of Exhibit 3, Page 1 of 5.

NOVA SCOTIA POWER INC. (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL ELI 2P-RTP MUNICIPAL UNMETERED (9) (10) (11) (12) ALLOCATION FACTOR (13)...

AI summary The document presents a table with various operational and maintenance costs categorized across different business segments of Nova Scotia Power Inc., including demand-side management (DSM) and other operational costs. The table includes allocation factors and specific line items such as batteries, radial transmission, and DSM.

NOVA SCOTIA POWER INC. ALLOCATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) INTERR. RIDER DMD ADJ. (2) (3) Peak Dmd. in KWs (at Generator) 69,594 (4) Int Credit Amount 11,165 (5) (6) PHP DEMA...

AI summary The document presents a table outlining the allocation of operating expenses for Nova Scotia Power Inc. for the year ending December 31, 2026, including details on demand adjustment calculations and credit amounts related to peak demand and interruptions.

NOVA SCOTIA POWER INC.

AI summary The document pertains to Nova Scotia Power Inc., a utility company involved in regulatory proceedings. It includes acronyms and contextual information relevant to energy management, pricing, and regulatory frameworks in Nova Scotia.

NOVA SCOTIA POWER INC.

AI summary The document pertains to Nova Scotia Power Inc., a utility company involved in regulatory proceedings. It includes acronyms and contextual information relevant to energy management, pricing, and regulatory frameworks in Nova Scotia.

DEVELOPMENT OF ALLOCATION FACTORS (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION COMPANY DOMESTIC GENERAL GENERAL LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL PHP MUNICIPAL UNMETERED FACTOR (...

AI summary The document presents a detailed breakdown of allocation factors related to demand, generation, and purchase across various categories such as small, general, and industrial sectors. Percentages of responsibility are calculated for each category, with specific values and exhibits referenced for further details.

NOVA SCOTIA POWER INC. SALES, GENERATION AND DEMAND ANALYSIS (1) MWH (2) ENERGY LINE (3) ENERGY SALES LOSSES REQUIREMENT DMD. (KW) (4) CLASS NON- SYSTEM (5) FACTOR (6) COINCIDENT COINCIDENT COINCIDENT LINE COIN. PEAK COINCIDENT (7) (8) SYS...

AI summary The document presents a detailed breakdown of energy sales, generation, and demand analysis for Nova Scotia Power Inc., including metrics such as MWH, energy losses, demand factors, and system demand. The data focuses on HV transmission service for large industrial customers.

FOR JANUARY 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDEN...

AI summary The text presents a table with various energy metrics for January 2026, including energy sales, losses, demand factors, and other related figures categorized by different customer classes and special programs. It includes sub-totals and totals, with some data redacted and marked as confidential.

FOR FEBRUARY 2026 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LINE LOSSES ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDE...

AI summary The document presents a table with energy sales, losses, and demand metrics across different customer classes in February 2026. It includes data on energy requirements, coincident demand, and line losses, with percentages and totals provided for each category.

FOR MARCH 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for March 2026, categorized by customer class and including specific entries such as ELID Tariff, IR-30, and other specialized categories. It includes aggregated totals and percentages, reflecting system performance and energy distribution across various sectors.

FOR APRIL 2026 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM MWH SALES LOSSES LINE ENERGY REQUIREMENT COINCIDENT DMD. (KW) COINCIDENT FACTOR COINCIDENT DMD. (KW) LINE LOSSES COIN. PEAK COINCIDENT...

AI summary The document presents a table with energy data for April 2026, categorizing different classes of energy usage and losses across various sectors, including domestic, industrial, and municipal. The data includes metrics such as MWH sales losses, energy requirements, and demand factors. The table also includes a section labeled 'REDACTED ELID Tariff Synapse IR-30 Attachment 1 Page 74 of 96 REDACTED (CONFIDENTIAL INFORMATION REMOVED).'

FOR MAY 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT DM...

AI summary The table presents detailed energy sales, losses, and demand data for various customer classes in May 2026, including metrics like energy line losses, system coincident demand factor, and demand line losses. The data is categorized by customer class and includes sub-totals and totals for different segments.

FOR JUNE 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDENT D...

AI summary This table presents data related to energy sales, losses, and demand factors across various customer classes for June 2026. It includes metrics such as MWH sales losses, energy line losses, demand losses, and system coincidence factors. The data is categorized by customer type, including domestic, industrial, and municipal classes, and includes subtotals and totals for different categories.

FOR SEPTEMBER 2026 (1) (2) (3) (4) (5) (6) (7) (8) (9) MWH ENERGY LINE ENERGY CLASS NON- COINCIDENT SYSTEM COINCIDENT SYSTEM COINCIDENT DEMAND LINE SYSTEM SYSTEM COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOS...

AI summary The table presents energy sales, losses, and demand data across various customer classes for September 2026, including metrics such as energy line losses, demand factor, and system coincident peak demand. The data is categorized by customer type, with detailed breakdowns for domestic, industrial, municipal, and other classes.

FOR OCTOBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDEN...

AI summary The document presents a table with various metrics related to energy sales, losses, demand, and system factors across different customer classes in October 2026. The table includes figures for MWH sales losses, energy line losses, demand losses, system coincident demand factors, and other related metrics. The data is categorized by customer class, such as domestic, industrial, and municipal. The table also includes subtotals and totals for different categories, as well as a note about redacted information.

FOR NOVEMBER 2026 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM (9) SYSTEM COIN. PEAK COINCIDE...

AI summary The document presents a table with various metrics related to energy sales, losses, and demand factors across different customer classes in November 2026. The table includes data on MWH sales losses, energy line losses, energy requirement, class non-coincident demand, system coincident factor, system coincident demand, demand line losses, system peak coincident demand, and load factor. The data is categorized by customer types such as domestic, small general, general, large industrial, and others.

FOR DECEMBER 2026 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTE...

AI summary The document presents a table with energy sales, losses, and demand metrics categorized by customer class for December 2026. It includes data on energy requirement, system coincidence factor, and demand line losses, along with totals and subtotals for different classes and special cases like Shore Power and ELIADC.

FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) TOTAL (3) (4) SMALL (5) GENERAL (6) (7) SMALL MEDIUM LARGE (8) (9) (10) (11) (12) SHORE (13) (14) (15) (16) REAL TIME MONTH ( 1) JANUARY COMPANY DOMESTIC GENERAL GENERAL 2,305,127 1,501,844 76,...

AI summary The document presents a detailed table of demand data across various categories and months for the year ending December 31, 2026. It includes different classifications such as small, general, large, and industrial demands, with specific figures for each month and overall totals.

REDACTED ELID Tariff Synapse IR-30 Attachment 1 Page 91 of 96 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Line # AVERAGE RATE BASE RATE BASE 2025 RATE BASE 2026 (217) PURCHASED POWER - MARITIME LINK (218) PURCHASED POWER - WIND (ERIS) (219...

AI summary The text presents a table outlining various rate base components for 2025 and 2026, including purchased power, capacity credits, overhead expenses, DSM expenses, and depreciation and accretion. The data includes figures related to different energy sources and financial adjustments.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 (39) CLASS NON-COINCIDENT DMD SMALL GENERAL 87,055 78,286 71,125 57,863 53,355 51,498 59,024 55,955 53,433 50,406 66,114 64,837 87,054.8 (40) CLASS NON-COINCIDENT DMD GENERAL DE...

AI summary The table provides allocation factor information for various classes of non-coincident demand across different calendar months, detailing demand figures for small general, general demand, large general, small industrial, medium industrial, and industrial large classes, along with DMDELI 2P-RTP.

REDACTED ELID Tariff Synapse IR-30 Attachment 2 Page 14 of 15 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Category Usage Data 62,638 53,212 48,588 46,920 53,118 49,047 56,555 43,151 54,132 54,184 56,426 42,967 158,818 ATL Classes BTL Class...

AI summary The document presents a table containing usage data categorized by various classes such as ATL, BTL, BUTU, and GRLF, along with associated numerical values for different months and an annual total. This data appears to be related to energy usage and distribution metrics.

(16) Sum of Monthly Demands in KVAs (at the Meter) 0 (17) Int Credit Amount - PHP 0 (2) (5) (7) (1) INTERR. RIDER DMD ADJ. (3) Dmd. in KWs (4) Int Credit Amount (6) PHP DEMAND ADJUSTMENT CALCULATION 69,857 11,207 (8) Demand Usage Annual Cr...

AI summary The document presents a table related to demand adjustment calculations, specifically focusing on the PHP (Port Hawkesbury Paper LP) demand adjustment, with values such as kW and kVA demands, power factor adjustments, and credit amounts. It includes references to the ELIADC tariff and Synapse Energy Economics, Inc.

NOVA SCOTIA POWER INC.

AI summary The document pertains to Nova Scotia Power Inc., a utility company involved in regulatory proceedings. It includes acronyms and contextual information relevant to energy management, pricing, and regulatory frameworks in Nova Scotia.

FOR THE YEAR ENDING DECEMBER 31, 2027 (1) MWH (2) ENERGY LINE (3) ENERGY SALES LOSSES REQUIREMENT DMD. (KW) (4) CLASS NON- SYSTEM (5) COINCIDENT COINCIDENT COINCIDENT FACTOR (6) SYSTEM DEMAND SYSTEM (7) LINE (8) DMD. (KW) LOSSES DMD. (KW)...

AI summary The document presents a detailed table of energy usage and demand metrics across various customer classes for the year ending December 31, 2027, including energy consumption, losses, demand factors, and contribution percentages. It provides a comprehensive overview of energy sales and system demand across different sectors.

FOR JANUARY 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM...

AI summary The document presents a table with various metrics related to energy sales, losses, and demand factors across different customer classes in January 2027. It includes data on energy sales, energy losses, energy requirements, demand factors, and system peak demand across different customer categories, such as domestic, industrial, and municipal.

FOR FEBRUARY 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTE...

AI summary The document presents a table with energy sales, losses, and demand metrics across various customer classes for February 2027. It includes data on energy requirement, demand losses, and system peak demand. The table also provides subtotals and totals for different categories, such as shore power and real-time pricing, and concludes with an overall total.

FOR MARCH 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM C...

AI summary The document presents a table with energy sales, losses, and demand metrics for different customer classes in March 2027. It includes data on energy requirement, system demand, and load factors across various categories such as domestic, industrial, and municipal. The table also includes subtotals and totals for energy sales and exports.

FOR APRIL 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM C...

AI summary The text presents a table with energy sales, losses, and demand metrics across different customer classes for April 2027. It includes totals and subtotals for various categories such as domestic, industrial, and municipal, along with percentages for energy losses and demand factors. The table is part of a redacted attachment from a regulatory proceeding.

FOR JUNE 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM CO...

AI summary The document presents a detailed table of energy sales, losses, and demand metrics for different customer classes in June 2027. It includes data on MWH sales, energy losses, demand factors, and other related metrics categorized by customer type.

FOR JULY 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM CO...

AI summary The text presents a table with various metrics related to energy sales, losses, and demand factors categorized by different customer classes and subtotals. It includes data on MWH sales, energy losses, demand factors, and system peak demand for multiple categories such as domestic, industrial, and municipal, along with subtotals and totals.

FOR AUGUST 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM...

AI summary The document presents a table with data on energy sales, losses, and demand factors across various customer classes for August 2027. It includes metrics such as energy losses, demand factors, and total energy requirements. The data is categorized by customer type, and there are subtotals and totals provided for different sections of the table.

FOR SEPTEMBER 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYST...

AI summary The text presents a table with various energy metrics categorized by different customer classes, including MWH sales, energy losses, demand factors, and other system performance indicators. The data spans multiple categories such as domestic, industrial, and municipal users, and includes totals and subtotals for different segments of energy usage and system performance.

FOR OCTOBER 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTEM...

AI summary The document presents a table with various energy metrics, including sales, losses, and demand factors, categorized by different customer classes and sectors. The data includes metrics such as energy sales, energy line losses, energy requirement, and system coincident demand factors for multiple customer categories. The table also includes subtotals and a total for energy metrics, with some entries marked as redacted.

FOR NOVEMBER 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTE...

AI summary The text presents a table with energy sales, losses, and demand metrics across various customer classes for November 2027. It includes data on energy requirement, demand losses, and system peak demand, categorized by customer type. The table also shows subtotals and totals, with some entries marked as redacted or confidential.

FOR DECEMBER 2027 (1) MWH SALES (2) ENERGY LINE LOSSES (3) ENERGY REQUIREMENT (4) CLASS NON- COINCIDENT DMD. (KW) (5) SYSTEM COINCIDENT FACTOR (6) SYSTEM COINCIDENT DMD. (KW) (7) DEMAND LINE LOSSES (8) SYSTEM COIN. PEAK DMD. (KW) (9) SYSTE...

AI summary The text presents a table with energy sales, losses, and demand metrics categorized by customer class for December 2027. It includes data on energy sales, energy losses, demand factors, and other related metrics, with subtotals and totals provided for different customer segments.

NOVA SCOTIA POWER INC. DETAILED LISTING OF C.O.S.S. INPUT INFORMATION FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (207) (232) BUTU CAPACITY CREDIT (233) OTHER OVERHEAD EXPENSES 393.8 7,886.5 6,978.0 908.6 System Plannii...

AI summary The document provides a detailed listing of input information for Nova Scotia Power Inc.'s Cost of Service Study (COSS) for the year ending December 31, 2027, including expenses related to capacity credit, demand-side management (DSM), depreciation, and various generation sources such as hydro, wind, solar, and gas turbine.

Request IR-2: 1 Please refer to Exhibit N-3, page 3 lines 18-20. Please elaborate on the "seasonal fluctuations" and its impact on PHP energy demand.

AI summary The text requests an explanation of 'seasonal fluctuations' and their impact on PHP energy demand, referencing Exhibit N-3, page 3 lines 18-20.

1 Response IR-1: - (a) If the Board adopts an 8 MW demand allocator, the resulting rates will only reflect the costs of providing firm service. In this scenario, because PHP is not being charged for the system capacity required to serve it...

AI summary The response discusses the implications of adopting an 8 MW demand allocator on rates and interruptible credits for PHP, contrasting scenarios where the allocator exceeds 8 MW. It also rejects the proposed ELID tariff, citing inconsistencies with PHP's position on cost causation and credit pricing. The analysis centers on tariff design, demand-side management, and cost recovery mechanisms.

And further: NS Power estimates its marginal cost of adding production resource capacity during its 3-CP peak periods to be $13.107/KVA. Hence, to the extent the Board approves the use of a demand charge applicable to PHP's interruptible l...

AI summary NS Power estimates its marginal cost of adding production capacity during peak periods at $13.107/KVA, arguing that PHP's interruptible load credit should reflect this avoided cost. PHP questions whether setting the credit at this rate would make its coincident peak parameter in the COSS reasonable for both firm and interruptible demand.

Preamble: NSPI's evidence states that optimal dispatch of PHP's load could yield system savings of $7–$11 million annually – which would accrue to PHP under the DR credit – but that realized savings may be approximately half that amount. (...

AI summary NSPI claims that optimal dispatch of PHP's load could result in system savings of $7–$11 million annually, but realized savings may be about half. The request asks PHP and BAI to assess the reasonableness of this range and identify key assumptions and constraints affecting the difference between optimal and realized savings.

Request IR-7: - Reference: N-3, Evidence of PHP, page 9, ADC Energy Supply Protocol. - (a) Provide the Active Demand Control ("ADC") Energy Supply Protocol in its entirety, including all appendices, schedules, and amendments. - (b) Identif...

AI summary Request IR-7 seeks the full ADC Energy Supply Protocol, amendments under the proposed ELID tariff, and quantification of operational constraints affecting PHP's ability to respond to electronic dispatch. The request includes evidence from N-3, page 9.

Request IR-9: Reference: N-3, Evidence of PHP, page 12. Unless PHP's areas of concern are addressed by the Board in a satisfactory 13 manner it is unlikely PHP will proceed to accept service under the ELID tariff. 14 PHP would need to unde...

AI summary PHP seeks Board approvals for ELID tariff modifications and a below-the-line alternative. It threatens to reject ELID if changes aren't made, emphasizing the need for a tailored tariff meeting the mill's operational needs.

Response IR-9: (a) PHP is currently seeking approval of the ELID tariff modified to address the concerns raised in its Evidence, Exhibit N-3, at page 8, lines 18-31. (b) Please refer to PHP's response to CA IR-5. (c) Generally a below-the-...

AI summary PHP seeks approval for a modified ELID tariff, emphasizing a cost-based ATL rate. The response addresses concerns about tariff impacts on financial sustainability and references prior submissions. Request IR-10 questions PHP about dispatch events, load curtailment, and the rationale for setting the 3CP value at 8 MW despite a recorded low of 9 MW.

Response IR-10: - (a) Real time schedules are sent out in advance of the next several hours, and do not account for any immediate system disturbances. NS Power sends out real time dispatches that are informed by the best available system i...

AI summary NS Power clarifies that real-time dispatches do not account for immediate system disturbances, citing specific dispatch examples for PHP. It argues that interruptible demand does not require incremental capacity, as NS Power reserves capacity only for PHP's 8 MW firm demand. Dispatch records from 2020-2025 show load adjustments during peak periods, with some instances showing significant load reductions.

Request IR-11: - Reference: N-3, Evidence of PHP, pages 12-13. - Preamble: PHP states that there are aspects of PHP's load flexibility that are not being - captured in the ELID filing, and that the benefits from the February 13, 2026, Mari...

AI summary PHP argues that its load flexibility and the February 13, 2026, Maritime Link event's ancillary service value are not fully captured in the ELID filing. It seeks compensation for this value beyond ADC and priority interruptible, requesting a tariff mechanism and cost allocation. PHP also asks to quantify the system value of off-protocol curtailments under ELIADC, including methodology.

4 Response IR-2: 6 Please refer to PHP's response to NS Power IR-1(c). Request IR-3: Reference: Direct Evidence of Port Hawkesbury Paper LP, page 3. A. Port Hawkesbury Paper is Nova Scotia's largest industrial electricity consumer, in some...

AI summary Port Hawkesbury Paper LP (PHP) is Nova Scotia's largest industrial electricity consumer, requiring 24/7 energy use. PHP assumes the ADC component of the ELID tariff will remain intact with amendments and will make load available for dispatch. The document requests confirmation of PHP's 2026 load forecasts and energy demand expectations for 2027.

nterruptible service and the compensation to PHP, as modeled, be maintained until it can be revisited in the next GRA. [emphasis added] Reference: Direct Evidence of Port Hawkesbury Paper LP, page 9. The ELIADC was not designed to specific...

AI summary The document discusses the ELIADC and ELID Tariffs, focusing on the reduction of PHP's load during peak events and the compensation for Priority Interruptible service. It emphasizes that the ELIADC was not designed as a peak avoidance tariff but includes mechanisms to reduce load during peak hours, benefiting system reliability. The request seeks confirmation on the financial and reliability benefits of these mechanisms.

Request: Please confirm, or explain otherwise, if it is BAI's understanding that under the proposed ELID Tariff: (a) System energy cost savings produced by the dispatch of PHP load will accrue solely to PHP, not other customers. (b) PHP is...

AI summary BAI requests confirmation that under the proposed ELID Tariff: (a) system energy cost savings from PHP load dispatch accrue solely to PHP; (b) PHP is compensated for avoided generation capacity via interruptible credits, using the same methodology as Large Industrial Interruptible Rider customers; and (c) transmission savings from PHP's interruptible load are minimal, as NS Power's transmission capacity is designed for total system load, not just interruptible loads.

1 2  Differences in the extent to which demand and energy charges applicable to 3 each of the classes are aligned with the costs of energy and demand services 4 in the COSS for these two classes. 5 6  The effect of fuel-related rate-smoo...

AI summary The text discusses differences in energy and demand charges between the LI and ELID rate classes, the effect of fuel-related rate-smoothing, and the potential for credits to PHP from dispatching its load under the ELID tariff. It also references the ELID's role in system power supply savings and its interruption limitations compared to the LIIR tariff.

Request IR-13: Reference: Direct Evidence of Port Hawkesbury LP, page 12. Q. Aside from ADC and being priority interruptible, are there other aspects of PHP's load flexibility that are not properly being captured in the ELID tariff filing?...

AI summary PHP raised concerns that the NSPSO did not follow the Active Demand Control Energy Supply Protocol during a February 13, 2026 system disturbance when it requested a load drop. PHP claims the NSPSO did not use the interruption protocol specified in the ELIADC tariff and instead gave a direct instruction to reduce load.

PHP INFORMATION REQUEST RESPONSES To: Small Business Advocate From: Port Hawkesbury Paper LP ("PHP") Copies: 1 electronic copy (PDF searchable) Contact Person: James MacDuff McInnes Cooper 1300 – 1969 Upper Water Street Purdy's Wharf, Towe...

AI summary Port Hawkesbury Paper LP (PHP) requests Nova Scotia Power (NSP) to provide details on events from 2020 to present, including reasons for NSP-initiated load reductions (e.g., ADC, interruptible rider), event durations, base load impacts, and 5-minute interval load data under the ELID tariff. The request references M12661 and Exhibit N-3.

Refer to M12661, Exhibit N-2, Evidence of Colin T. Fitzhenry and Michael G. Gorman on behalf of PHP, page 18, lines 5-23 and page 19, lines 1-6. specifically, the use of three coincident peak ("3-CP") and cost-causation principle guidance...

AI summary The text references a regulatory proceeding (M12661) and requests information from PHP regarding the application of NARUC guidelines on interruptible capacity, cost-causation principles, and 3-CP allocation methods. It also asks about performance obligations, penalties for non-performance, and statistical methods for allocating capacity.

Response IR-5: (a) The Electric Utility Cost Allocation Manual, January 1992, (NARUC Manual). The NARUC Manual doesn't use the term interruptible, but it does recognize the concept of shifting demands on the system to avoid generation capa...

AI summary The NARUC Manual (1992) discusses cost allocation principles, emphasizing shifting demand to avoid generation capacity costs and attributing costs to customers causing them. It highlights the utility's flexibility in matching supply with demand using base load facilities and the regulatory purpose of cost allocation to fairly assign costs based on customer impact.

Response IR-6: (a) No, avoided transmission and production capacity costs should primarily be captured through the interruptible credit or through an appropriate demand allocation. (b) No. While PHP believes that the Dispatchable Rider doe...

AI summary PHP responds to questions about capacity cost recovery, stating that avoided transmission and production costs should be captured through the interruptible credit or demand allocation. It disagrees with NS Power's proposed DR credit, which would not include capacity cost savings. PHP has not reviewed a finalized methodology for calculating DR benefits related to energy dispatch savings.

s PHP's energy forecast for the test years in Section V at page 27, line 2 to page 28, line 9. PHP's testimony discusses its updated forecast energy requirements at page 9, line 26 to page 10, line 7. c) The dollar value of the Interruptib...

AI summary The text discusses PHP's energy forecasts, the Interruptible Credit for interruptible load, Active Demand Control (ADC) cost recovery proposals, and the Dispatchable Rider. PHP and NS Power will analyze ADC's value for a proposed rate rider, while BAI addresses interruptible credit calculations. The Dispatchable Rider's role in capturing load flexibility is highlighted.

- Refer to the Direct Evidence of Fitzhenry and Gorman, p. 16. 18 - Please provide a reference to the Direct Evidence of Bevan Lock and John Esaiw. - Response IR-5: - Please see page 9 of Exhibit N-3, specifically the response to the Quest...

AI summary The text references direct evidence from Fitzhenry and Gorman, and requests further evidence from Bevan Lock and John Esaiw. It also points to specific pages in Exhibit N-3 regarding PHP's operations and load flexibility in relation to NS Power's winter demand peaks and the ELID tariff filing.

Part A – Definitions ADC : Active Demand Control. ADC Operating Procedure : Procedure document maintained by Nova Scotia Power System Operator (NSPSO) that describes the operation and usage of ADC for the NSPSO for Current Hour, Operating...

AI summary This section defines key terms and procedures for Active Demand Control (ADC) and Customer Baseline Load (CBL) under Nova Scotia's energy regulations. It outlines operational protocols, dispatchable hours, demand schedules, and roles of entities like Nova Scotia Power (NS Power), Nova Scotia Power System Operator (NSPSO), and Port Hawkesbury Paper LP (PHP). Definitions include ADC operating procedures, demand scheduling timelines, and regulatory frameworks like the NS Market Rules.

- (a) With respect to forecast PHP annual capital shutdowns, PHP will provide a minimum of one month's advance notice of the timing and duration of the shutdowns; and - (b) With respect to forecast PHP regular maintenance shutdowns, PHP wi...

AI summary The text outlines protocols for Port Hawkesbury Paper LP (PHP) regarding advance notice for shutdowns, demand schedule adjustments during significant events, intra-day updates by NS Power, and NSPSO's authority to modify demand schedules. It also references NS Power's potential rate adjustments with NSUARB approval if CBL Energy Charge discrepancies arise.

Part D – Operating Mode Characteristics Schedule Effective: January 1, 2026 For the purpose of planning, dispatch and forecasting, PHP's loading levels will be separated into 9 distinctive operating modes. Only one mode will be able to ope...

AI summary PHP's Operating Mode Characteristics Schedule defines 9 operating modes for load management, including parameters like ramp rates and storage levels. NS Power and NSPSO must dispatch PHP's load according to this schedule, which impacts ADC benefits and CBL incremental costs. The schedule is developed by PHP with NS Power and may be amended by mutual agreement.

In respect of the DR (previously ADC), the Tariff (page 8 of Attachment 1 to N-1) indicates: "NS Power will be able to actively manage the Customer's load in accordance with the terms and conditions to be set out in an Operating Procedure"...

AI summary The document discusses Nova Scotia Power's (NSP) ability to manage customer load under the DR (Demand Response) program, specifically whether NSP can force consumption profiles or if PHP can ignore DR price signals. It also questions why an Interruptible Rider is needed if NSP already has dispatch authority.

Responses to IG Consultant (Bowman) Questions – 2 of 4 Question NS Power Response Please also refer to 2. The PHP related savings from optimizing load are indicated to be already included in the COS from the GRA. NSP indicates this means t...

AI summary The document discusses responses from NS Power to questions raised by an IG consultant regarding demand response (DR) savings and the Customer Baseline Load (CBL) calculation. It explains that if PHP does not optimize load, the costs would be absorbed by NS Power, and the CBL is based on a high-load factor annual profile to ensure optimal energy use.

Responses to IG Consultant (Bowman) Questions – 3 of 4 Question NS Power Response Please also refer to 4. NSPI(IG) IR-27(b) indicates: "Any attempt to more precisely quantify monthly benefits before the annual load is known and the PortOps...

AI summary NS Power explains that implementing the ELID rate partway through a year, such as mid-2026, would require settling the ELIADC Tariff first. The CBL would be based on PHP's actual energy consumption during the ELID service period, and outage days would be randomized for comparison on an equivalent-energy basis.

Responses to IG Consultant (Bowman) Questions – 4 of 4 Question NS Power Response Please also refer to 5. NSPI (IG)-20 shows a sample calculation for one day of how the DR would be calculated. But the example in question shows a case where...

AI summary NS Power explains that the Customer Baseline Load (CBL) is based on actual load data, not forecasts, and clarifies that demand response (DR) credits are calculated based on load optimization, not overall load reduction. NS Power also details how the Fuel Adjustment Mechanism (FAM) will allocate costs from the Goose Harbour wind farm directly to PHP.

Responses to CA Questions and Topics – 2 of 3 Question NS Power Response Please also refer to 2. PHP Deferral in the context of ELIADC extension beyond 2026. • At paragraph 353 of the Board GRA Decision, the following is provided: "Further...

AI summary NS Power explains that PHP deferral account transfers depend on Board-approved tariffs for 2026/2027 and adherence to GRA assumptions. Variances between tariff assumptions and actual outcomes may qualify for deferral, but require Board approval and prudency review. The response references NSEB IR-6 and other cited documents.

Responses to SBA Questions – 3 of 4 Question NS Power Response Please also refer to Governance Questions: a) While the pass-through nature DR (Dispatchable Rider) credit does make it cost neutral, retroactive audits do not substitute for c...

AI summary NS Power responds to governance questions about transparency in DR (Dispatchable Rider) protocols and PHP's participation in DR. It claims draft protocols align with ELIADC Tariff and argues performance metrics for PHP are unnecessary due to DR design. Cross-references include IG and NSEB interventions.

NON-CONFIDENTIAL 1 Request IR-20: 2 3 Reference: N-1, ELID Application, page 17. 4 5 6 In addition to [fixed cost recovery], the ELID tariff will affect fuel costs borne by other customer classes in two respects: 7 8 9 10 11 12 13 14 15 16...

AI summary The text discusses how the ELID tariff affects fuel costs for different customer classes, particularly focusing on the impact of DR service on PHP and ATL customers. It outlines scenarios where marginal costs are above or below average and explains how this affects cost distribution and the role of the FAM in addressing these effects.

3.1 NSP APPLICATION NSP is applying to the Board for approval of the Extra Large Industrial Dispatchable (ELID) Tariff, an above-the-line (ATL) tariff available to Port Hawkesbury Paper LP (PHP). NSP states it is intended that PHP will sub...

AI summary NSP seeks Board approval for the ELID Tariff for PHP, replacing the expiring ELIADC Tariff. The proposed tariff includes customer, demand, and energy charges, interruptible service, and provisions for wind farm energy. NSP cites a settlement agreement (SA) with PHP for cost modeling, while InterGroup highlights load characteristics and credit calculations in the SA. Alternative plans are needed if approval fails.

dispatchable rider, where there is no "penalty" for non-compliance other than the foregone opportunity that would have been realized by PHP had PHP followed NS Power's dispatch plan.[36](#page-13-0) In practical terms, however, no PHP load...

AI summary The document discusses NSP's proposed ELID Interruptible Rider, noting that PHP has not participated in load reductions under the ELIADC Tariff since 2020. NSP asserts that during capacity shortages, PHP load is already dispatched down, making interruption unnecessary. It argues that IR and DR services are distinct, requiring separate compensation tracking for planning and operational cost relief.

- the value of the DR credit, NSPI will conduct an ex post production cost simulation model run to - determine the total system FAM costs using "actual system conditions that occurred throughout the year," - but assuming PHP would consume...

AI summary NSPI proposes a method to calculate the DR credit by comparing actual system costs with a scenario assuming high load factor consumption by PHP. The DR credit would be recovered from all above-the-line customers, but concerns are raised about the credit's accuracy as a proxy for marginal price signals.

Approval of an Above-the-Line Tariff Applicable to Port Hawkesbury Paper (M12661) Bates White Evidence – Confidential Version 1 much energy to consume. During high-priced periods, price-responsive demand can reduce consumption 2 and theref...

AI summary The document discusses concerns raised by Port Hawkesbury Paper (PHP) regarding the ELID Tariff and the DR credit mechanism. PHP argues that the fixed ELID Energy Rate reduces its incentive to respond to price signals, while the DR credit does not provide immediate compensation for load adjustments. PHP also highlights operational challenges, such as equipment wear and tear, associated with load shifting.

- maintenance periods may be identifiable, though some questions remain about the verifiability of this data - (addressed below). However, NSPI proposes to then "randomize" the outages throughout the year,[87](#page-23-0) a - subjective ex...

AI summary The document discusses concerns regarding the accuracy and verifiability of data related to maintenance periods and load-shifting services by PHP. It highlights that factors beyond energy prices, such as operational constraints and external variables, may influence PHP's load profile, raising questions about the fairness of FAM customers bearing the cost of these changes.

1 V. Treatment of Goose Harbour Output 112 Goose Harbour PSA, page 7. 113 NSPI Application, page 13, lines 30-31. 2 Q. Please summarize how Goose Harbour generation is treated with respect to PHP and NPSI. 3 Goose Harbour is being develope...

AI summary The Goose Harbour output is treated under a Power Purchase Agreement (PPA) and a Power Sale Agreement (PSA) with NSPI. The PSA allows PHP to offset higher-cost energy with lower-cost Goose Harbour energy, potentially undermining PHP's status as an Above-the-Line (ATL) customer under the ELID. The output is deemed to serve PHP's load, and any excess is carried forward to future billing periods.

VI. Recommendations 2 Q. Please summarize your recommendations with respect to NSPI's Application. 3 A. We recommend that NSPI file additional evidentiary support for its proposed Customer Charge. 4 Absent this, we recommend NSPI set the C...

AI summary The recommendations include requiring NSPI to provide additional evidence for the Customer Charge, setting it at a midpoint if not supported, and ensuring reconciliation of ELID Tariff administration costs. The ELID Energy Charge and DR credit are not approved as proposed due to concerns over clarity, verifiability, and risk of mismatch.

II. SUMMARY OF CONCLUSIONS AND RECOMMENDATIONS Q. Please describe your conclusions and recommendations. A. NS Power's proposed tariff is generally reasonable and represents an appropriate transition from a below-the-line to an above-the-li...

AI summary NS Power's proposed ELID tariff is generally reasonable but requires modifications to address concerns about capacity costs and equitable benefit allocation. PHP, the largest electricity customer, has raised issues regarding interruptible credit compensation and demand charge calculations. The ELID tariff aims to replace the expiring ELIADC tariff and ensure PHP pays its incremental costs while allowing NS Power to manage load for system reliability and cost reduction.

NS Power ELID Application, page 14. 1 subject to future recovery from ATL customers, subject to Board approval. These 2 differences may include final approved tariff design, PHP's participation, or related cost 3 12 and load assumptions. 4...

AI summary The ELID tariff is based on NS Power's existing Large Industrial (LI) tariff, with an Interruptible Rider and a Dispatchable Rider. Key elements include monthly customer charges, demand and energy charges, and various riders such as the fuel adjustment mechanism and demand-side management cost recovery.

Component NS Power's proposed ELID Tariff PHP's Proposed Adjustments PHP's Core Revenue-to-Cost Ratio 1.04 1.00 Proposal Energy Sales Forecast Forecast provided by PHP for GRA Revised 2026 and 2027 energy sales forecasts PHP's Preferred Op...

AI summary The document compares NS Power's proposed ELID Tariff with PHP's adjustments, focusing on revenue-to-cost ratios, energy sales forecasts, demand charges, and interruptible credits. PHP proposes a lower revenue-to-cost ratio and revised energy sales forecasts, along with adjustments to demand charges and interruptible credits.

IV. DEMAND CHARGE AND INTERRUPTIBLE CREDIT on PHP's firm load level of 8 MW, with no interruptible credit? A. No. PHP's consultants, Mr. Fitzhenry and Mr. Gorman of Brubaker and Associates (BAI), argue that NS Power's ability to curtail PH...

AI summary The discussion revolves around the appropriate basis for calculating PHP's demand charge and interruptible credit. PHP argues that its interruptible load does not contribute to NS Power's generation and transmission costs, but NS Power counters that transmission costs are driven by both interruptible and firm load, and that PHP's proposal would shift costs to other customers. NS Power also argues that compensating PHP at the full marginal cost would overstate its benefit to other customers.

Second, setting the interruptible credit equal to the full marginal cost would allocate all of the benefits of avoided capacity to PHP, leaving other customers no better Ibid. 1 off than if an equivalent amount of generation capacity had b...

AI summary The text discusses the allocation of benefits from avoided capacity to the Public Health Program (PHP) and suggests that setting the interruptible credit equal to the full marginal cost would leave other customers worse off. It recommends that the credit should be set at a level that encourages PHP participation while ensuring other customers share in the benefits and continue to bear responsibility for system costs.

rict of Columbia Department of Energy and Environment. Whited, M., C. Roberto. 2019. Multi-Year Rate Plans: Core Elements and Case Studies. Synapse Energy Economics for Maryland PC51 and Case 9618. Knight, P., E. Camp, C. Odom, E. Malone,...

AI summary The text lists various publications by Synapse Energy Economics and its collaborators, focusing on energy policy, rate design, equity in solar adoption, transportation electrification, and energy efficiency. These works were commissioned by organizations such as the Natural Resources Defense Council and Advanced Energy Economy Institute.

ct testimony of Melissa Whited regarding Nova Scotia Power Inc.'s proposed time-varying pricing tariff application. On behalf of Counsel to the Nova Scotia Utility and Review Board. February 24, 2021. Newfoundland and Labrador Board of Com...

AI summary The text outlines Melissa Whited's testimony in various regulatory proceedings across different provinces, including Newfoundland and Labrador, Georgia, Maine, and Rhode Island, concerning utility rate structures, customer charges, non-wires alternatives, and distributed energy resources. These testimonies were provided on behalf of multiple regulatory bodies and advocacy groups.

PRESENTATIONS Whited, M. 2024. "Benefits of Offshore Wind in New England" Webinar presentation sponsored by Sierra Club, June 24, 2024. Whited, M. 2021. "Evolution of Net Metering in Hawaii." Presentation to the NARUC Winter Policy Summit....

AI summary The document lists a series of presentations by Michael Whited on various energy and utility-related topics, including offshore wind, net metering, rate design, demand charges, performance incentive mechanisms, and energy policy. These presentations were delivered at conferences, summits, and workshops across North America.

Extra Large Industrial Active Demand Control (ELIADC) Tariff 2025 Annual Report (NSEB M12768) NSPI Responses to BW Information Requests Request IR-3: 2 3 Please refer to PDF page 3, "Operation Summary." 4 5 (a) Did the cyber event have any...

AI summary The document discusses the impact of a cyber event on the scheduling of Peak Hour Pricing (PHP) by Nova Scotia Power Inc. (NSPI), including the use of PLEXOS to create optimized hourly load schedules in the absence of PortOps. It also references the suspension of the Open Access Transmission Tariff (OATT) Standards of Conduct.

NON-CONFIDENTIAL 1 Request IR-5: 2 3 Please refer to PDF page 3, "Load Variations." Did PHP's lower-than-forecasted demand 4 increase system costs, such as through retention of higher capacity, higher reserves, greater 5 unit commitment, o...

AI summary The response to Request IR-5 explains that PHP's lower-than-forecasted demand did not impact NS Power's long-term procurement decisions, such as gas and power RFPs, as PHP's load is not currently included in these decisions. Modeling from PortOps shows that PHP pays for all generation serving its demand.

Extra Large Industrial Active Demand Control (ELIADC) Tariff 2025 Annual Report (NSEB M12768) NSPI Responses to IG Information Requests 1 Request IR-1: 6 1 TWh (1,000 GWh). The 2025 actual benefit ($4.4 million) falls below this forecast r...

AI summary The 2025 ELIADC Tariff Annual Report highlights that the actual benefit of $4.4 million fell below the 2019 forecast due to fuel price volatility from 2021-2024. However, the benefit represents a 30% increase compared to the 2021-2024 average and 60% of the 2020 result. Approximately $2.8 million of the benefit is attributed to fixed cost recovery.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 1 of 7 Schedule 1: Active Demand Control Energy Supply Protocol Part A – Definitions ADC : Active Demand Control. ADC Operating Procedure : Procedure document maintained by Nova Scot...

AI summary The document outlines the definitions and procedures for the Extra Large Industrial Active Demand Control (ELIADC) Energy Supply Protocol, including terms like ADC, CBL, and dispatchable hours, as well as the roles of Nova Scotia Power System Operator (NSPSO) and Nova Scotia Power (NS Power) in managing demand control and energy forecasts.

2025 ELIADC IG IR-3 Attachment 1 Page 2 of 7 REDACTED (CONFIDENTIAL INFORMATION REMOVED)

AI summary The document is a redacted attachment from a 2025 ELIADC IG IR-3 proceeding, which includes confidential information. It is part of a regulatory process involving Nova Scotia Power Inc. and the Nova Scotia Energy Board.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 2 of 7 Schedule 1: Active Demand Control Energy Supply Protocol by NS Power. Refer to Part B. The results of these runs will be presented and shared with PHP as ADC Schedule 1. NS Ma...

AI summary This document outlines the Extra Large Industrial Active Demand Control Tariff, including schedules and protocols related to energy supply, demand forecasting, and operational procedures involving Nova Scotia Power and Port Hawkesbury Paper LP.

Part B – Protocol Forecasting and Operation - (1) Annually, no later than the seventh business day of November, NS Power will forecast the Monthly Demand Schedule, Weekly Demand Schedule, and monthly and weekly limits based on PHP's demand...

AI summary NS Power is required to provide regular demand forecasts and schedules to PHP and NSPSO, including monthly, weekly, and daily demand schedules, as part of the system day-ahead planning process. These forecasts are used to optimize PHP's demand within the NS Power portfolio.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 3 of 7 Schedule 1: Active Demand Control Energy Supply Protocol - (a) With respect to forecast PHP annual capital shutdowns, PHP will provide a minimum of one month's advance notice...

AI summary This section outlines the procedures for adjusting demand schedules and communication protocols under the Extra Large Industrial Active Demand Control Tariff, including advance notice requirements for shutdowns, intra-day schedule updates, and conditions for rate adjustments based on cost differences.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 4 of 7 Schedule 1: Active Demand Control Energy Supply Protocol 7.8. PHP discrete line operation (i.e. what lines are in and out of service in a period) – PHP. NS Power and PHP agree...

AI summary The document outlines the terms of the Extra Large Industrial Active Demand Control (ELIADC) Tariff, focusing on the provision of system information to PHP for efficient response to dispatch schedules and unplanned system changes, and the annual calculation of ADC benefits based on the Customer Baseline Load (CBL).

Part C – Conditions - (9) Subject only to reasons of health, safety, environmental, system reliability, and Force Majeure events, PHP must not deviate from the NS Power/NSPSO final demand schedule. NS Power/NSPSO must comply with the weekl...

AI summary This section outlines conditions for PHP and NS Power regarding adherence to demand schedules, restoration of operations after disruptions, and communication protocols following Force Majeure events or other disruptions. It also specifies tracking and updating of deviations from dispatch plans and filing updates with the NSUARB.

2025 ELIADC IG IR-3 Attachment 1 Page 5 of 7 REDACTED (CONFIDENTIAL INFORMATION REMOVED)

AI summary The document is a redacted attachment from a 2025 ELIADC IG IR-3 proceeding, indicating that confidential information has been removed. It likely contains details related to the Extra Large Industrial Active Demand Control program and its implications for Nova Scotia's energy sector.

EXTRA LARGE INDUSTRIAL ACTIVE DEMAND CONTROL TARIFF Page 5 of 7 Schedule 1: Active Demand Control Energy Supply Protocol - (12) Subject to available generation or load, as the case may be, efforts will be made to reconcile variances in a t...

AI summary This section outlines the Active Demand Control Energy Supply Protocol, detailing how variances in generation or load will be reconciled, the roles of NS Power, PHP, and NSPSO in scheduling and operations, and the alignment of this Protocol with NS OATT and NS Market Rules. It also covers annual planning and dispatch responsibilities.

Part D – Operating Mode Characteristics Schedule For the purpose of planning, dispatch and forecasting, PHP's loading levels will be separated into 9 distinctive operating modes. Only one mode will be able to operate at any given time. The...

AI summary PHP's load will be divided into nine operating modes for planning and dispatch purposes. The Operating Mode Characteristics Schedule outlines parameters such as ramp rates, outage planning, and energy requirements. NS Power and NSPSO must dispatch PHP's load according to this schedule, and it can be modified with agreement between PHP and NS Power.

CONFIDENTIAL (Attachment Only) 1 Request IR-5: 2 3 Reference: 2025 Annual Report, Exhibit N-1, p. 3/9, Load Variations 4 5 PHP's initial 2025 forecast totalled 811 GWh. There were revisions to PHP's 6 7 load forecast through the year, with...

AI summary The document contains a request for information regarding PHP's 2025 load forecast, including initial forecasts, revisions, and the impact of forecast divergence on dispatch optimization and the CBL energy charge. It also references the ELIADC Tariff 2025 Annual Report and a matter number (NSEB M12768).

REDACTED 1 incentive for PHP to follow dispatch and retain its 25 percent share of the ADC Load 2 Shifting Differential. In 2021-2024, the ADC Load Shifting Differential was negative, and 3 therefore no Off-Schedule Charges were applied. 4...

AI summary The text discusses the ADC Load Shifting Differential and Cause Code tracking issues in 2025, including the lack of Off-Schedule Charges due to a negative differential and the need for normalization of data during incomplete tracking periods. NSPI's assessment of ELIADC performance is also addressed.

1 Request IR-1: 12 (c) A small deviation in MWh for an individual hour, in tandem with potentially short 13 durations of a given Cause Code event (i.e. as short as one hour), can create circumstances 14 in which the model would be unable t...

AI summary The text discusses challenges in modeling short-term energy events, highlighting that small deviations in MWh and short durations of Cause Code events can create resolution issues. It also notes that modeling forecast scenarios differs from modeling after-the-fact scenarios and that existing scheduling processes have proven flexible in handling system contingencies.

1.1 Findings and Recommendations - The proposed ELID rate is complicated and unusual in utility rate regulation. No comparable rate could be - identified in Canada, particularly for a major customer on a regulated utility system. - Despite...

AI summary The proposed ELID rate is criticized for being complex and unfair, failing to reflect service costs or value. Recommendations include adjusting capacity values, limiting PHP's DR credits, rejecting interruptibility credits, and ensuring transparency in operating procedures. The ELID's predecessor, ELIADC, is acknowledged as beneficial but requires reforms to address inequities in cost allocation and dispatchability.

rating in a manner that is more optimal than a defined theoretical Customer Base Line ("CBL"). The CBL is designed under the assumption that the customer, absent the DR, would operate at a very high-load factor (i.e., a very flat load thro...

AI summary NSP's ELID rate proposal discusses a credit mechanism for PHP based on a Customer Base Line (CBL) assumption, with 8 MW of PHP's 12 MW peak load attributed to native demand after accounting for biomass plant contributions. Exhibits from Matter M12661 reference PHP's projected energy consumption and load factors.

3.2 Issues Associated With Application of the DR - The DR is a highly accommodating and beneficial aspect of the ELID rate to PHP. It also appears to be - unprecedented in Canada. - Not only does PHP secure the ability to access approximat...

AI summary The Dispatchable Rider (DR) under the ELID rate provides PHP with significant benefits, including compensation for load variation and access to NSP's embedded resources. The DR is unprecedented in Canada and allows PHP to shift load without obligation, though NSP retains dynamic dispatch rights. This arrangement is clarified in a 2026 Technical Conference.

nt actual experience arose under the ELIADC with the existing dispatch rights and the existing - (priority) IR credit, at a time when NSP only held the power to dispatch PHP using economic incentives. Matter M12661, Exhibit N-10, pdf page...

AI summary The text references issues with the proposed Integrated Resource Plan (IR) under the ELIADC program, highlighting conflicts arising from dispatch rights and IR credit when NSP had limited dispatch authority over PHP. Cited exhibits from Matter M12661 support these claims.

3.4 Issues Regarding Transparency and Reporting - The DR mechanism is new and complex. The benefits of the ELID can only be understood with a detailed - comparison of a hypothetical CBL load, as compared to actual PHP load, with the varian...

AI summary The text critiques NSP's proposal to reduce regulatory oversight and reporting for the ELID/DR mechanism, arguing that the complexity of the DR mechanism requires stronger Board oversight. It recommends quarterly reporting on DR status and approval of Operating Procedures by the Board to ensure transparency and accountability.

4.0 ADDITIONAL PROPOSALS FROM THE EVIDENCE OF PHP - PHP has submitted their own proposals for the ELID tariff which vary from the structure and principles - espoused by NSP. - The basic outline of the ELID is accepted by PHP, but with the...

AI summary PHP proposes modifications to the ELID tariff structure, including updated load forecasts, revised peak load definitions, 100% cost-based rate recovery, and ancillary services credits. These differ from NSP's GRA-based proposals, focusing on tariff design, cost recovery, and load management adjustments.

BOWMAN ECONOMIC CONSULTING INC., WINNIPEG, MANITOBA 2020 – current – Principal Consultant Conduct consulting assignments as Principal Consultant of new economic consulting firm, focused on utility regulation. Member, Society of Depreciatio...

AI summary Bowman Economic Consulting Inc. provides regulatory consulting services to industrial energy users in Manitoba and Newfoundland, focusing on rate design, revenue requirement reviews, cost of service, and demand-side management initiatives. They assist with General Rate Applications, cost-of-service analyses, and represent clients in regulatory proceedings.

Request IR-4: - Reference: Testimony, Section VI, page 35, lines 23-25. "… we recommend that a true-up - mechanism be created to address substantial deviations of PHP net load from expectations…" - (a) Please quantify the term "substantial...

AI summary The text requests clarification on the definition of 'substantial' in the context of a true-up mechanism for PHP net load deviations, whether the mechanism operates in both directions, and how NSP determines forecast energy usage for LIIR customers.

Response IR-4: - (a) The Bates White evidence documents that PHP annual net load may well be 60% lower than assumed by NSPI (page 15, lines 15-16), which we would consider substantial. We do not offer any lower bound on what might be consi...

AI summary The response to IR-4 discusses concerns regarding the accuracy of NSPI's assumptions about PHP's annual net load, the need for a symmetric true-up mechanism, and the lack of documentation on how NSPI forecasts energy usage for LIIR customers.

1 Response IR-1: 2 (a) Mr. Bowman cannot quantify the specific impact of each proposal on the 3 proposed ELID tariff with any precision, given that Mr. Bowman does not 4 have an operable version of NSP's Cost of Service Model, among other...

AI summary Mr. Bowman acknowledges limitations in quantifying the impact of proposals on the ELID tariff due to lack of access to NSP's Cost of Service Model. He adopts a 120 MW value for ELID projected demand but recommends it be updated with accurate information. He references a prior model showing impacts of changing peak load and compares it to his recommendation.

30 Added peak demand to 120 MW: $9.4 million (may be less, pending NSP analysis) 1 multiple places, NSP indicates that effectively no PHP is load is typically 2 on the system at coincident peaks, as it will have already been curtailed 3 un...

AI summary The text discusses the impact of adjusting the peak demand and interruptible load valuation for PHP (Port Hawkesbury Paper) under NSP's (Nova Scotia Power) proposal. It highlights a potential overvaluation of PHP's interruptibility credit, with calculations showing varying monthly credits based on different demand levels, and recommends eliminating the priority interruptible credit due to its lack of system value.

Request IR-3: - Reference: Testimony, page 9, lines 20-23. "The capacity value used in the COS for PHP - should be representative of the expected PHP average demand based on total forecast - energy requirements (prior to non dispatchable w...

AI summary The text discusses a request for clarification regarding the capacity value for PHP in the COS, including whether PHP can operate at the CBL, its impact on costs, and the use of the 'capacity value' in place of the current 3-CP demand allocator. It also asks for the firm and interruptible load parameters Mr. Bowman suggests for PHP.

26 Response IR-3: 27 (a) Under the NSP proposal, PHP is always permitted to operate as required 28 for its business purposes, outside of the narrow conditions of utility-29 triggered interruptions. However, if PHP operated at 120 MW all ye...

AI summary The NSP proposal allows PHP to operate as needed for its business, except during utility-triggered interruptions. If PHP operated at 120 MW year-round, it would consume 1,051 GW.h, which is compared to load projections.

1 2 wind, PHP will consume 305 GW.h, so that scenario does not appear relevant. 3 4 (b) If PHP operated at 120 MW all year, and consumed 1,051 GW.h of energy, then yes, the system costs would go up. 5 (c) Yes. 6 7 8 9 10 11 (d) No. The 3-C...

AI summary The text discusses the impact of PHP's energy consumption and demand scenarios on system costs and rate-setting. It outlines considerations for determining capacity value, load factors, and the use of different demand approaches, such as 3-CP, for establishing ATL rates, particularly for PHP.

Reference: Testimony, pages 12-13, lines 25-2. "The DR dollar value credit proposed to be allocated 100% to PHP risks over-crediting PHP for the value of DR, and harming other customers. This arises in part because the theoretical CBL agai...

AI summary The testimony raises concerns about the proposed DR credit allocation to PHP, suggesting it may over-credit PHP and harm other customers. It highlights the need for benefit sharing, similar to the current ELIADC tariff, and questions whether the DR calculation includes capacity cost savings and how these savings are passed on to PHP.

25 Response IR-4: 26 (a) The question poses an interesting hypothesis, as nowhere in the materials 27 did Mr. Bowman see a discussion of outcomes that could lead to the DR 28 being a net charge to PHP. Specifically, the ELID Tariff page 8...

AI summary The response discusses the DR mechanism and its implications for PHP, noting that there is no evidence supporting a net cost to PHP from DR. The DR is not intended to credit capacity cost savings to PHP, and the mechanism is recommended for review after the first year of operation.

1 Request IR-6: 2 Reference: Testimony, page 15, lines 6-9. "There is no basis for providing PHP with a 3 priority interruptibility credit, given (a) PHP is rarely if ever interruptible in practice under 4 the IR, and (b) the priority inte...

AI summary The text discusses whether interrupting a customer class prior to others would result in operational cost savings for other interruptible classes and whether it would increase interruption opportunities for non-interrupted classes, referencing testimony and a specific customer (PHP).

1 Request IR-7: - 2 Reference: Testimony, page 15, lines 6-9. "The Board should not adopt the proposals - 3 from PHP to alter the rate as proposed by NSP. This includes adjusting the PHP peak load - 4 to 8 MW in the COS study, adjusting th...

AI summary The document includes a request (IR-7) asking for explanations regarding how PHP is compensated for ancillary services and operating reserves through the DR, and what the firm demand level for PHP would be under Mr. Bowman's proposals, which set its capacity value at 120 MW with limited credit for interruptibility.

16 Response IR-7: 17 (a) The quoted sentence from the Bowman evidence is potentially unclear. 18 Through the DR, PHP is compensated for any contribution it makes 19 towards operating cost efficiencies and dispatch savings. PHP, however, 20...

AI summary The response discusses the limitations of PHP's participation in the DR program, noting that its voluntary participation does not meet the rapid response requirements for ancillary services. It also clarifies that PHP's interruptible load credits are based on typical load patterns, not operational restrictions.

number of peak hours, without regard for whether such lowered capacity levels are consistent with sustainable business operations, are likely to result in an underallocation of costs to that customer. One set of options to address this as...

AI summary InterGroup discusses challenges in cost allocation for interruptible customers, proposing objective baseline verification methods like ERCOT's approaches. They agree the CBL baseline could be considered but note PHP's exclusion from capacity allocation risks cost shifting. Alberta's rate design recommendations are referenced as potential solutions.

And, in its Recommendations at p. 2/pdf p. 4: Recommendation 2: InterGroup recommends that the Board consider the reasonableness of the DR savings proposed to be credited to PHP. a) Please identify the specific factors or criteria that Int...

AI summary InterGroup recommends the Board assess the reasonableness of DR savings credited to PHP, considering ELIADC's ADC mechanism issues, benefit-sharing arrangements, and using VCC percentages as a proxy for credit sharing.

IG Request IR-4: - Reference: N-19, Evidence of InterGroup, p. 12/pdf p. 14. - Preamble: In s. 6.0, Proposed ELID Interruptible Rider, InterGroup stated: NSP confirmed that PHP can simultaneously receive (i) a DR credit for being dispatche...

AI summary InterGroup raises concerns that PHP may receive duplicate credits under both the Dispatchable Rider (DR) and Interruptible Rider (IR) for the same load reduction, potentially exceeding 100% system benefits and disadvantaging other customers. The proceeding questions whether this represents a design flaw, how to prevent double-counting, and if it supports limiting IR credit value.

CA Response IR-4: a) Yes. - b) InterGroup believes that the proper mechanism should be aligned with key regulatory rate principles, in particular: - Simplicity and understandability; - Freedom from controversies as to proper interpretation...

AI summary InterGroup supports aligning the IR credit mechanism with regulatory rate principles, emphasizes the need to separate interruptible and DR service loads, and approves IR credit for 2026-2027 based on the GRA Settlement Agreement. However, they oppose future IR credit without a mechanism to prevent double-counting DR and IR service values.

such, NSP proposes to examine the value of PHP's PI service in the next General Rate Application (GRA). - a) Given that LIIR customers who are not on Telemetry and Control ("T&C") can be, and in practice are physically interrupted ahead of...

AI summary NSP questions InterGroup about the practical benefits of PHP's Priority Interruptible designation, arguing that PHP is often dispatched down under DR during system constraints, making the PI status redundant and questioning the 10% credit in the 2026-2027 test years.

CA Response IR-5: a) Yes. - b) Yes, and this is supported by NSP statement that it remains to be determined whether Priority Interruptible service provides value to the system. - c) InterGroup notes that the 2026-2027 GRA SA stipulated tha...

AI summary The response confirms Priority Interruptible service's value remains undetermined. InterGroup references a 10% credit in the 2026-2027 GRA SA for priority interruptibility, noting load parameters were agreed upon for NSPI's Above-the-Line tariff in 2026-2027 test years.

IG Request IR-7: - c) Does InterGroup agree that if the review confirms that PHP is essentially never interruptible in practice, having already been optimally dispatched, then the appropriate outcome would be elimination rather than revisi...

AI summary InterGroup addresses questions about the IR credit, recommending elimination if PHP is non-interruptible, opposing reporting obligations for NSPI, and advocating Board approval of Operating Procedures affecting DR credit. It also highlights the complexity of the ELID Tariff requiring a Board review.

CA Response IR-7: - a) Yes, with allowance for future refinements, also subject to the Board approval. - b-c) InterGroup considers that the scope of the first-year review should include testing the performance of each approved ELID Tariff...

AI summary InterGroup agrees to future refinements and supports a first-year review of the ELID Tariff's performance against NSP's targets. They also endorse quarterly reporting on DR status by NSP, aligning with Mr. Bowman's recommendation for transparency in funding estimates.

PHP Request IR-2: Reference: Testimony, page 5: "InterGroup agrees with the concerns raised by NSP that including only the firm 8 MW of load would under-represent the degree to which PHP makes use of and benefits from the transmission syst...

AI summary InterGroup supports NSP's load parameters in the SA but notes that interruptible loads may underrepresent usage. They suggest this is a common issue and that alternative cost allocation methods could address it, though they find the current model reasonable.

PHP Request IR-4: Reference: Testimony, pages 6-7. "As confirmed by NSP in various responses to Information Requests from interveners, the billing demand, used in arriving at $13.107/kVA, equals the fixed 65 MW determinant, minus the 8 MW...

AI summary The text discusses the calculation of interruptible demand levels for PHP and LIIR customers, raising questions about metering practices and the appropriateness of using non-coincident PHP peaks and firm demand levels for calculating interruptible demand.

CA Response IR-4: a) and b) Please see the response to NSPI (SBA) IR-1(h) (Exhibit N-9), where NSP states as follows: [M](#page-3-1)12451, Exhibit N-9, page 10 and 11 of 29. Under the Large Industrial Tariff, billing demand is based on met...

AI summary NSP proposes using the cost of service assumption for billing purposes under the ELID Tariff, while InterGroup argues that PHP's interruptible demand should be calculated based on load characteristics from the Settlement Agreement and historical peak loads for future years.

PHP Request IR-6: Reference: Testimony, page 13. "In InterGroup's view there is a risk the pairing the proposed Dispatchable Rider with the proposed Interruptible Credit credits PHP twice for effectively the same provision." - a) Does Inte...

AI summary InterGroup raises concerns about potential double-counting of benefits if the Dispatchable Rider and Interruptible Credit are paired, as they may both provide savings related to reduced load operations. The questions seek clarification on whether these benefits are distinct and whether the pairing poses a risk.

CA Response IR-6: - a) and b) The stated assertion that the two services are distinct and PHP is being compensated for two separate value streams (IR for planning relief (i.e the avoided cost of building new generation) and DR for operatio...

AI summary The document discusses the potential for duplicate compensation to PHP under two separate mechanisms — the Dispatchable Rider and the Interruptible Credit — due to overlapping load reductions. NSP confirmed that PHP has not been called for load reductions under the ELIADC Tariff and that during capacity scarcity, PHP load is already dispatched down, raising concerns about double-counting of credits.

Reference: N-20, Bates White Evidence, at p. 21, lines 2-6 notes a second concern: Our second concern is that the DR credit is built upon a shaky premise, namely, that PHP's load is sufficiently predictable as to allow for an after-the-fac...

AI summary Bates White Evidence raises concerns about the reliability of PHP's load forecasting for demand response (DR) credits, citing volatility, forecast errors (averaging xxxx/year, peaking at xxx GWh in 2023), and external variables (e.g., equipment performance, macroeconomic factors) that complicate accurate cost-based load (CBL) calculations. It questions NSPI's ability to model CBL without PHP's operational data and highlights risks of cost variability tied to forecast inaccuracies.

Response IR-5: - (a) Yes. - (b) FAM customers. - (c) There may be, but we have not developed one. Our recommendation is that any payments to PHP from FAM customers under the DR credit must be demonstrably tied to PHP deciding to shift load...

AI summary The response addresses demand response (DR) program design, emphasizing that payments to PHP from FAM customers must be tied to load-shifting due to energy prices. It compares the ELID Tariff's ex post demand control calculation to the ELIADC Tariff, noting differences in embedded cost rates and Goose Harbour Wind Farm output. Concerns about exogenous fuel cost fluctuations masking actual DR benefits are highlighted, referencing Bates White's audit.

The market for paper is somewhat seasonal with winter and summer months having generally less demand than spring and fall. - (a) Does Bates White agree that its finding that PHP would have higher demand in winter and summer months is incon...

AI summary The text presents three questions to Bates White regarding inconsistencies in their findings on PHP's demand patterns, potential revisions to their evidence, and the accuracy of CBL mechanics in overstating savings. The focus is on seasonal demand variations and load factor calculations.

Response IR-6: - (a) Yes. PHP's response to BW-IR-2 states: "The market for paper is somewhat seasonal with winter and summer months having generally less demand than spring and fall. PHP's energy demand corresponds to this seasonal varian...

AI summary PHP's energy demand is seasonal, contradicting NSPI's claim of levelized consumption. The DR Credit calculation is deemed inaccurate due to reliance on a flawed premise. Seasonal variance in paper market demand aligns with PHP's energy use patterns.

credit: 2 Reference: N-20, Bates White Evidence, at p. 24, lines 12-13, third concern with the DR In such instances, it would be inappropriate for FAM customers to pay PHP

AI summary The text references a concern related to demand response (DR) and notes that it would be inappropriate for FAM customers to pay PHP, though the context and full implications are not elaborated.

for changes to its load profile that would have been made regardless of the ELID Tariff and its components. - (a) Is Bates White saying that the ELID, or the DR credit specifically, should not pay PHP for load variations that are done for...

AI summary The text raises questions about whether Bates White believes the ELID Tariff, particularly the DR credit, should not reimburse FAM customers for load variations unrelated to NSPI's pricing signals. It also inquires about potential modifications to the ELID Tariff and whether similar issues exist under the ELIADC structure.

Response IR-7: - (a) Yes. - (i) Not applicable. - (b) We have not put forth an alternative tariff mechanism. As we state in our evidence, we do not recommend that the Board approve the DR credit as proposed. We do explain that the DR credi...

AI summary The response to IR-7 states that an alternative tariff mechanism is not proposed, and the DR credit is deemed too vague and unverifiable. The ELIADC Tariff's variable rate differs from the proposed ELID Tariff's fixed rate, with concerns that exogenous factors may obscure load-shifting benefits. The DR credit requires revisions for verifiability.

Request IR-8: 2 Reference: N-20, Bates White Evidence, fourth concern, p.26, lines 3-11. According to NSPI, assuming that "for that [2025] period, if PHP load had been dispatched at 100 percent optimal," the DR credit would have been "appr...

AI summary NSPI estimates that the DR credit for the 2025 period would have been approximately $3.5 to $5.5 million if PHP load had been dispatched at 100% optimal, but discretionary adjustments reduced this amount. These adjustments were based on subjective factors and were not fully available due to a cyber incident.

Response IR-8: - (a) Yes, to the extent the question's reference to "Operating Procedures" is referring to IG-NSPI-IR-12 Attachment 1. - (b) Yes. (c) We have not proposed such a mechanism, nor is it our conclusion that a verification mecha...

AI summary The response confirms reference to a specific operating procedure attachment but denies proposing a verification mechanism for the DR Credit. It outlines requirements for any such mechanism, including full discovery of NSPI's model inputs and stakeholder testimony, with the onus on NSPI to demonstrate the reasonableness of the DR Credit calculation.

1 guardrails or reporting requirement? 2 (d) Under the current ELIADC tariff, load shifting savings are shared 75% to 3 other customers and 25% to PHP. Does Bates White agree that: 4 (i) The 75/25 benefit-sharing arrangement served as a 5...

AI summary The text raises questions about the ELIADC tariff's benefit-sharing arrangement, specifically whether the 75/25 split between other customers and PHP served as a buffer against overestimation of CBL and whether removing it would increase exposure for FAM customers. It also asks if Bates White objects to retaining a benefit-sharing approach in the ELID DR credit.

And p. 33, lines 10 - 18: - Q. Is there a potential scenario in which PHP has zero net load subject to the ELID Energy Charge? - A. Yes. As discussed above, the 653 GWh of output from Goose Harbour is a reasonable estimate of potential gen...

AI summary The text discusses a scenario where PHP (Potential for Higher Performance) could have zero net load under the ELID tariff, leading to no Energy Charge payments. It also raises questions about the true-up mechanism, its methodology, and whether PHP would remain connected to the NSPI system in this scenario.

And: We also recommend NSPI explain the methodology for tracking the costs of administering the ELID Tariff and how NSPI plans to ensure that 100% of the costs incurred above in administering the ELID Tariff are paid by PHP, including thos...

AI summary The text requests NSPI to explain the methodology for tracking the costs of administering the ELID Tariff and how PHP will cover these costs. It also seeks Bates White's opinion on quarterly reporting, the relationship between annual evaluation and true-up mechanisms, and the sequencing of these mechanisms in case of over-generation. Additionally, it asks whether the Board should impose specific reporting obligations.

evidence, setting the interruptible credit equal to the full marginal cost would allocate all of the benefits of avoided capacity to PHP, leaving other customers no better off than if an equivalent amount of generation capacity had been pr...

AI summary The text discusses the impact of setting interruptible credit equal to full marginal cost on PHP and other customers, and references FERC Orders 745 and 745-A regarding demand response compensation. It emphasizes the need for cost-effective alternatives to generation resources that provide net benefits to all ratepayers.

M12661 Date Filed: June 22, 2026 Synapse (IG) Page 10 of 14 1 Request IR-5: 2 3 Reference: N-21 – Synapse Evidence, p. 13/ pdf 15, lines 7-10 and 14-19. 4 5 Q. If PHP's proposal to assess the demand charge on only 8 MW of its 6 demand is n...

AI summary The response to Request IR-5 discusses the theoretical net-avoided-cost figure as an upper bound for negotiated outcomes and confirms that the Board should pre-establish this cap as a condition of negotiation. The respondent also acknowledges the need for further calculation using NSPI's capacity cost data.

(b) Yes. (c) No, Ms. Whited is not currently able to calculate this value. The value depends on the demand-related costs for the Large Industrial (LI) class, the monthly billing determinants for each class, and the value of the interruptib...

AI summary The witness confirms that a calculation is not currently possible due to dependencies on demand-related costs for the Large Industrial class, monthly billing determinants, and the value of the interruptible credit provided to Public Health and Safety.

Q CAN YOU BRIEFLY SUMMARIZE THE RECOMMENDATIONS OF MR. BOWMAN? A Yes. Mr. Bowman makes five recommendations: - 1) The capacity value used in the Cost of Service ("COS") for PHP should be representative of PHP's average demand, rather than...

AI summary Mr. Bowman recommends adjusting PHP's capacity value in the Cost of Service based on its average demand rather than peak demand, and revising the DR credit allocation to prevent over-crediting PHP. NS Power argues that using average demand ignores PHP's efforts to reduce system peak demand and the need for capacity investment.

Q PLEASE EXPLAIN WHY MR BOWMAN'S PROPOSAL TO USE PHP'S AVERAGE DEMAND IN DEVELOPING A DEMAND ALLOCATOR IS DISCRIMINATORY . A. As discussed previously, the proposal to inflate PHP's contribution to the system 3-CP demand by substituting its...

AI summary The response argues that using PHP's average demand instead of its actual peak demand in the demand allocator proposal is discriminatory. It inflates PHP's contribution to system capacity, leading to an overallocation of production and transmission resources, which is not cost-based and unfairly advantages PHP.

Q IS MR BOWMAN'S PROPOSAL CONSISTENT WITH THE BOARD DIRECTIVES THAT COST OF SERVICE AND RATE DESIGN BE BASED ON NON-DISCRIMINATORY RATEMAKING PRINCIPLES? A No. While we are not attorneys, our understating is that the Board operates under a...

AI summary The response argues that Mr. Bowman's proposal is inconsistent with the non-discriminatory rate-making principles mandated by the Nova Scotia Public Utilities Act. It also rejects his recommendation to allocate demand costs to PHP based on its average demand, citing unfair cost distribution. Additionally, the proposal to provide NS Power with practical control of PHP load during constrained conditions is deemed unreasonable, as it disregards PHP's operational constraints.

Q HOW DO YOU RESPOND TO MR. BOWMAN'S THIRD RECOMMENDATION THAT THE 100% ALLOCATION OF DR SAVINGS RISKS OVER-CREDITING PHP FOR THE VALUE OF THE DR? A Mr. Bowman's recommendation to strip PHP of 100% of the calculated DR savings ignores the...

AI summary The response argues that allocating 100% of DR savings to PHP is justified due to its unique load flexibility and the structural changes in the ELID tariff. It also defends the Interruptible Rider credit, emphasizing its role in cost avoidance and system planning.

Q DO YOU AGREE WITH MR. BOWMAN THAT BECAUSE PHP MAY HAVE ALREADY BEEN DISPATCHED DOWN TO REDUCE LOAD UNDER THE DR THAT THEY SHOULD NOT RECEIVE AN IR CREDIT? No. Mr. Bowman's argument ignores the completely distinct benefits of the DR and t...

AI summary The response rejects Mr. Bowman's argument that PHP should not receive an IR credit because it already reduced load under the DR. It emphasizes that DR and IR provide distinct benefits: DR avoids high-cost energy hours, while IR improves system reliability during constraints. The two mechanisms are not conflated despite overlapping timing.

Q PLEASE REPLY TO MR. BOWMAN'S FIFTH RECOMMENDATION TO ELIMINATE THE 10% PRIORITY INTERRUPTIBILITY CREDIT. A Mr. Bowman's recommendation is without merit. PHP is the first customer to be interrupted on the system and thus acts as a resourc...

AI summary The response argues against eliminating the 10% priority interruptibility credit for PHP, stating that PHP's role as the first customer to be interrupted provides value to the grid and other customers. It emphasizes that the tiered interruptibility structure reduces system reliability risk and protects other entities from operational disruptions, making the 10% premium fair and balanced.

Q CAN YOU BRIEFLY SUMMARIZE THE RECOMMENDATIONS OF THE CA WITNESSES? A Yes. InterGroup recommends that the Board rejects all four of PHP's proposed tariff modifications, noting that parameters like the 65 MW 3-CP Demand Allocation and the...

AI summary InterGroup recommends rejecting PHP's proposed tariff modifications, approving the Interruptible Service component for specific test years, mandating a review of the ELID Tariff, evaluating the retention of DR savings, and requiring formal Board approval of PHP's operating procedures to ensure transparency and prevent cost shifting.

Q CAN YOU BRIEFLY SUMMARIZE THE RECOMMENDATIONS OF MS. WHITED? A Synapse witness Melissa Whited recommends that the Board approve the proposed ELID tariff, but subject it to specific, targeted modifications to achieve a more equitable allo...

AI summary Melissa Whited recommends approving the ELID tariff with modifications to ensure fair allocation of capacity costs and system benefits. She opposes PHP's proposal to assess demand charges solely on its 8 MW firm load and rejecting pricing interruptible credit at full marginal cost. Instead, she suggests negotiating a revised credit value to balance PHP's participation and benefit other customers.

It is made clear by the terms of the PSA that only the energy in - 24 excess of the energy purchased under the Ministerial approved PSA is subject to regulated NS - 25 Power tariffs. 1 2627 - Q. At page 28 of Bates White's Evidence, Bates...

AI summary The response explains that PHP follows NS Power's dispatch schedules for load shifting, not based on energy price signals. Load shifting is done to reduce energy consumption during high-cost periods and increase it during low-cost periods, aligning with NS Power's economic dispatch optimization tools. Failure to shift load may reduce potential credits under the ELID.

tions on the system, at any given time, that will constrain PHPs ability to run, regardless of the price of energy on the system. PHP is not responding to price signals, and has no mechanism to do so. 9 See NSPI Application page 8, at foot...

AI summary PHP argues that it cannot respond to price signals under the ELID tariff and emphasizes the need for a cost-based interruptible credit to compensate for the risks of compliance. It highlights the self-policing mechanism of the ELID tariff and its willingness to take on risk in exchange for a financial benefit.

DATE FILED: July 8, 2026 Page 4 of 25 (1) For a new tariff with the unique characteristics and administrative requirements of the ELID Tariff, a Customer Charge is appropriate. In the absence of a concrete cost foundation for this tariff e...

AI summary The document proposes a Customer Charge for the ELID Tariff based on a high-level forecast due to the lack of concrete cost data. It argues that Board approval of DR Operating Procedures is not necessary for ELID Tariff administration, and that current annual reporting is sufficient for transparency and oversight.

2.1.2 Demand Assumptions The Company expressly recognized, in section 2.2. of the Application, the challenge with setting the initial demand assumption for a customer whose load is dispatched by the Company. To address this, NS Power propo...

AI summary The document discusses the challenge of setting initial demand assumptions for a customer with dispatchable load, noting that NS Power proposed revisiting this in future GRAs. The SA prescribes a 65 MW initial demand assumption, but both Bowman and PHP propose different figures based on their operational perspectives.

DATE FILED: July 8, 2026 Page 11 of 25 InterGroup Evidence (CA Consultant), page 6. - operational frameworks applicable to non-firm service for large industrial customers in Nova - Scotia have been in place for decades,[16](#page-11-0) the...

AI summary The text discusses operational frameworks for non-firm service for large industrial customers in Nova Scotia, highlighting the ELID Tariff and its distinction from other tariffs like the PHP Load Retention Tariff and ELIADC Tariff. It notes concerns about potential double-counting of credits if the Dispatchable Rider is paired with the Interruptible Credit. The Company argues that IR and DR services are distinct in their value to the system and how they are regulated.

• As with ADC under the ELIADC Tariff, DR is not mandatory. Under both the ELIADC Tariff and the proposed ELID Tariff it remains the customer's decision to comply with the dispatch direction necessary for the customer to achieve the associ...

AI summary The document discusses demand assumptions related to the ELID Tariff and DR (Dispatchable Rider) service, noting that DR is not mandatory and does not provide capacity-related compensation. It addresses concerns about the infrequency of interruptions and highlights the difference between system planning and operations. The ELID Tariff requires both DR and IR services, and there is a recommendation for stronger dispatch rights for NSP.

owledged in Bowman's evidence, which provides: However, as noted above, it is recommended that new ELID contain stronger dispatch rights for NSP that would make it even more likely that PHP is already Historically, interruptible service cr...

AI summary The document discusses historical data on interruptible service credits and their lack of correlation with interruption events. It references NS Power's responses to various inquiries, highlighting that PHP experienced no interruptions from 2022-2025, while LIIR customers had 25 events over the same period. The document also notes the role of interruptible load in long-term planning and system operations.

ns in a manner that minimizes customer interruptions whenever reasonably possible. Refer to NS Power's responses to Synapse IR-5, Synapse IR-11 parts (a) and (b), Synapse IR-29, and SBA IR-2 part (g).

AI summary The text discusses NS Power's approach to minimizing customer interruptions and references their responses to several inquiries and reports, including Synapse IR-5, Synapse IR-11, Synapse IR-29, and SBA IR-2 part (g).

dispatched to minimal load under conditions likely to lead to calls for interruption than was the case under the ELIADC. [22](#page-13-0) It is true there is some interplay between these two service offerings. As PHP is dispatched down, wh...

AI summary The text discusses the interplay between Interruptible (IR) and Dispatchable (DR) services under the ELID Tariff, noting that while they interact operationally, they are distinct in compensation and purpose. It argues that IR allows for load interruption for reliability, while DR provides dispatch rights without overlapping compensation. The Bowman Evidence is referenced in this context.

e compensation streams are also distinct and appropriate. [25](#page-13-3) Bowman Evidence (IG Consultant), page 14, lines 1-3. DATE FILED: July 8, 2026 Page 14 of 25 Refer to NS Power's responses to SBA IR-2 part (g), Synapse IR-5 part (i...

AI summary The text references evidence and documents related to demand assumptions and resource planning, including NS Power's responses to various inquiries and the distinction between dispatchability and interruptibility in generation resource planning.

Finally, there is a variance in this application with respect to the proposed IR service credit. NS Power recognizes that the established IR credit protocol would produce a larger credit applicable to PHP, if the value of this service was...

AI summary The document discusses discrepancies in the proposed IR service credit, noting that the established protocol would produce a larger credit for PHP if not for the SA. NS Power plans to revisit this in the next GRA. The text also highlights an anomaly in the ATL interruptible service classes, where demand costs are offset by interruptible credits, citing InterGroup evidence that this is unreasonable. The ELID Tariff application is noted for its specific billing methodology.

Synapse Evidence (BCC), page 13, lines 20-21 and page 14, line 1. NSPI (Synapse) IR-10, as provided in footnote 20. InterGroup Evidence (CA Consultant), page 6. Refer to NSPI (CA) IR-9 which provided "[w]hile not expressly addressed in the...

AI summary The text discusses the transition of PHP from the ELIADC Tariff to the ELID Tariff, highlighting the shift from an incremental cost-based tariff to an embedded cost-based tariff. It mentions concerns about the allocation of DR benefits to PHP and the complexity of the ELID Tariff. NS Power argues that the new tariff aligns PHP's interests with other ATL customers and credits DR benefits fully to PHP.

and, as a result, it is proposed the benefits accrue fully to PHP (other than the portion recovered from PHP through the FAM).[36](#page-17-1) While the ELIADC Tariff has a sharing mechanism, this was appropriate because the cost foundatio...

AI summary The text discusses demand assumptions related to the ELID Tariff, highlighting the sharing mechanism and the fixed non-fuel cost component for PHP. It also addresses concerns about the DR credit as an imperfect proxy for marginal price signals and the reasonableness of assuming a high load factor premise for the ELID Tariff.

2.2.3 Concern with ELID Tariff Complexity - Bowman provides: "[t]he proposed ELID rate is complicated and unusual in utility rate regulation. - No comparable rate could be identified in Canada, particularly for a major customer on a regula...

AI summary The document discusses concerns about the complexity of the ELID Tariff, noting that while Bowman finds it complicated, the Company argues it is an evolution of the ELIADC Tariff and not a dramatic change. It also addresses the recommendation for Board approval of DR operating procedures, though no process is proposed for this approval.

Bowman Evidence (IG Consultant), page 15, lines 25-26 and lines 27-28. 1 The Company submits the Board's approval of the Operating Procedures will not limit or expand 18 is not recommended. Further, the Company has recognized that PHP's lo...

AI summary The Company proposes pausing the approval of the Operating Procedures, citing the need for further examination of PHP's load flexibility and PI service value to the system. InterGroup supports this approach but emphasizes that the review should be completed in time for 2028 implementation, separate from the next GRA.

NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act , R.S.N.S. 1989, c. 380 as amended -and- IN THE MATTER OF: AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for approval of an Extra Large Industrial Dispatchable Above-th...

AI summary EfficiencyOne has intervened in a proceeding under the Public Utilities Act regarding an application by Nova Scotia Power Incorporated for an Extra Large Industrial Dispatchable Above-the-Line Tariff for Port Hawkesbury Paper. EfficiencyOne, as the demand-side management franchise holder, will participate in the hearing and has provided contact details for its legal counsel and representatives.

Refer to M12661, Exhibit N-1, the Application for Approval of an Above-the-Line Tariff applicable to Port Hawkesbury Paper (the "Application"), Section 2.2 Demand Charge, starting at page 5 of 19, and please answer the following: - a) Desc...

AI summary The text requests detailed explanations regarding the demand charge structure in the ELIADC Tariff for Port Hawkesbury Paper, including the rationale for specific MW values, definitions of terms like 'judgment', and comparisons with other tariff structures. It also asks about the consistency of billing demand definitions and cost implications.

Request IR-3: Regarding interruptible events since 2020, please provide the following separately for both PHP and LIIR customers: - a) The number of events - b) The MW reduction below 65MWs for PHP, and the MW reduction for each LIIR custo...

AI summary Request IR-3 asks for detailed information on interruptible events since 2020, including the number of events, MW reductions, durations, causes, and whether events were capped or involved non-performance issues for both PHP and LIIR customers.

Request IR-4: - Refer to M12661, Exhibit N-1, the Application submitted by NS Power, Section 2.5 Dispatch Rider, starting on page 9 of 19, and please answer the following: - a) Provide the mathematical formulation of the DR credit. - b) Pr...

AI summary This request (IR-4) asks Nova Scotia Power to provide detailed information on the mathematical formulation of the DR credit, methodology for calculating Customer Baseline Load (CBL), explanations of factors influencing CBL, analyses of savings figures, and clarification on the nature of DR credits, ELID charges, and reporting requirements.

tion including any workbooks with formulas intact. 10. Does NS Power believe that the 10% priority credit captures the value of ancillary services implicitly? Please explain answer. Request IR-3: Regarding interruptible events since 2020,...

AI summary The document requests NS Power to explain the 10% priority credit for ancillary services and provides detailed information on interruptible events since 2020, including event counts, MW reductions, durations, and causes. It also asks for the mathematical formulation of the DR credit and methodology for determining the Customer Baseline Load (CBL), referencing a specific application and exhibit.

ations of the Customer’s major scheduled maintenance periods and other factors as may be appropriate to calculate a representative CBL. please explain what ‘other factors’ may be included in the CBL. 1. Provide the analyses demonstrating t...

AI summary The text outlines several requests for clarification and supporting documentation related to the calculation of the Customer Base Load (CBL), demand response (DR) credits, and tariff structures. Questions focus on savings analyses, DR credit composition, tariff alignment, and potential new tariff development timelines.

Refer to M12661, Exhibit N-3, Direct Evidence of Port Hawkesbury Paper ("PHP") (the "PHP Evidence"). Regarding the statement, on page 5, line 3-6: DA and RT Schedules can range from longer periods of stable load level, to being dispatched...

AI summary The text requests information about specific events from 2020 to the present related to DA and RT schedules, including the reasons for events initiated by NS Power, their duration, base load reduction details, and 5-minute interval load data as defined in the ELID tariff.

Request IR-5: Refer to M12661, Exhibit N-2, Evidence of Colin T. Fitzhenry and Michael G. Gorman on behalf of PHP, page 18, lines 5-23 and page 19, lines 1-6. specifically, the use of three coincident peak ("3-CP") and cost-causation princ...

AI summary Request IR-5 asks for clarification on the use of NARUC Manual guidance related to interruptible capacity allocation, cost-causation principles, and penalty mechanisms for non-performance by PHP. It also requests a statistical method for a 3-CP allocator and an explanation of why historical peak contributions are inappropriate.

Request IR-6: Refer to M12661, Exhibit N-2, Evidence of Colin T. Fitzhenry and Michael G. Gorman on behalf of PHP, regarding the non-fuel savings created by the Dispatchable Rider ("DR"), please answer the following: - a) Does PHP believe...

AI summary PHP is being asked about the Dispatchable Rider (DR) and its components, including avoided transmission and production capacity costs, overlap with interruptible credit, and whether the DR credit fully passes benefits to PHP. A table is requested to show which credit corresponds to each value attribute.

Request IR-8: Refer to M12661, Exhibit N-2, Evidence of Colin T. Fitzhenry and Michael G. Gorman on behalf of PHP, regarding the transmission avoided costs, please answer the following: a) Identify the NS Power studies relied on to claim,...

AI summary The document requests responses to questions regarding NS Power's studies on PHP's demand during system peaks, N-1 contingency assessments for high-voltage system upgrades, and whether PHP is recommending an additional credit for transmission capacity.

M12661 NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S. 1989, c.380, as amended IN THE MATTER OF: Application by Nova Scotia Power Inc. for Approval of an Extra Large Industrial Dispatchable Above-the-Line Tari...

AI summary The Nova Scotia Energy Board has issued information requests to Port Hawkesbury Paper regarding events from 2020 to present related to load reductions and dispatchable events. The requests seek details on the reasons for events, their duration, base load reduction, and 5-minute interval load data.

is duplicative if provided the full avoided cost of capacity? Please explain. 5. Does PHP believe that it provides the same interruptible benefit as LIIR customers? Please explain. Request IR-8: Refer to M12661, Exhibit N-2, Evidence of Co...

AI summary The document contains a series of questions and requests related to PHP's capacity contributions and transmission avoided costs. It asks whether PHP believes its interruptible benefit is the same as LIIR customers and requests clarification on studies and transmission upgrades based on different peak load scenarios.

18 And further: 19 20 NS Power estimates its marginal cost of adding production resource capacity during its 3- 21 CP peak periods to be $13.107/KVA. Hence, to the extent the Board approves the use of a 22 demand charge applicable to PHP's...

AI summary NS Power estimates the marginal cost of adding production resource capacity during peak periods to be $13.107/KVA. It argues that if the Board approves a demand charge for PHP's interruptible load, the ELID interruptible credit should be based on this avoided cost, ensuring fair compensation for PHP's system benefits.

h firm and interruptible demand (8 MW plus 57 MW)? Request IR-4: In its evidence, PHP states: PHP has the following specific areas of concern with respect to the proposed Above-the-Line Tariff: (1) the use of a 57,000 kW winter month syste...

AI summary PHP raises concerns about the ELID tariff, including the use of a specific winter month system coincident demand value, the Interruptible credit value, the R/C ratio, and outdated energy forecast assumptions. PHP also indicates it may not accept the ELID tariff unless its concerns are addressed and may seek a below-the-line tariff with NS Power if needed.

4 Request IR-3: 1 2 3 5 6 7 8 10 11 12 13 14 Reference: Direct Evidence of Port Hawkesbury Paper LP, page 3. A. Port Hawkesbury Paper is Nova Scotia's largest industrial electricity consumer, in some instances the mill's load can represent...

AI summary Port Hawkesbury Paper LP is Nova Scotia's largest industrial electricity consumer, with demand reaching up to 25% of the provincial power grid. The mill requires continuous energy use, even during periods of low production, highlighting the unique load profile and operational demands of the facility.

M12661 – NS Power Application for Approval of the ELID Tariff NSPI Information Requests to PHP 1 2 3 site, that includes approximately 4MW that are needed to maintain the shared services required for the NS Power Port Hawkesbury Biomass Pl...

AI summary The document discusses NS Power's application for approval of the ELID Tariff and includes information requests to PHP regarding interruptible service and compensation. It references the ELIADC tariff and its mechanisms for peak avoidance, including the ADC and Priority Interruptible mechanisms.

INFORMATION REQUESTS To: Port Hawkesbury Paper James MacDuff 1300 – 1969 Upper Water Street Purdy's Wharf, Tower II P.O. Box 730 Halifax, NS B3J 2V1 By email: [[email protected]](mailto:[email protected]) Tel: 9...

AI summary The document is an information request from Synapse Energy Economics, Inc. to Port Hawkesbury Paper, seeking clarifications and supporting references related to cost of service, PHP treatment, and tariff-related matters. The request includes specific page and line references from submitted documents and testimony.

M12661 NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: THE PUBLIC UTILITIES ACT - and - IN THE MATTER OF: AN APPLICATION by NOVA SCOTIA POWER INCORPORATED for approval of an Extra Large Industrial Dispatchable Above-the-Line Tariff applicable t...

AI summary The Nova Scotia Energy Board has issued information requests to Port Hawkesbury Paper in response to Nova Scotia Power Inc.'s application for an Extra Large Industrial Dispatchable Above-the-Line Tariff. The requests pertain to settlement terms, energy supply protocols, and clarification on base load values.

- b. Please provide the workpapers calculating each rate element of the Large Industrial tariff. 1 c. Please explain why the LIIR credit is lower than that which would have been 2 developed in accordance with the Company's established prac...

AI summary The text includes a series of requests related to the Large Industrial Interruptible Rider (LIIR) and the Extra Large Industrial Dispatchable (ELID) tariff, asking for details on load reductions, interruptions, and system peaks. These requests are part of a regulatory proceeding involving Nova Scotia Power (NSP).

does this compare to PHP's request for 8 MW of firm load during the winter peak? 1 f. Please list any specific assets that were designed to accommodate more than 8 MW 2 of firm load from PHP during the winter peak, as well as the PHP firm...

AI summary The text asks whether PHP's request for 8 MW of firm load during the winter peak is comparable to other scenarios, and includes several requests for information regarding assets, interruptible service credits, and avoided costs related to the Port Hawkesbury Biomass plant and system demand.

Request IR-15: Refer to the Application, p. 9, lines 20-24. - a. Please explain if PHP would be incented to reduce load due to priority interruptibility orders if the ELID tariff included the interruptible service credit and priority inter...

AI summary The request seeks clarification on whether the PHP would be incentivized to reduce load under the ELID tariff if the dispatchable rider is excluded, and whether priority interruption depends on the presence of the dispatchable rider. It also asks for an explanation of how past curtailments of PHP load were attributed to interruption credits or the ADC (now the dispatchable rider).

- ii. Can PHP be dispatched for load reduction prior to the first tier of interruptible load being interrupted, that being Generation Replacement and Load 1 Following Tariff. Please provide historical examples of PHP being dispatched 2 pri...

AI summary The text raises questions about the dispatch priority of PHP (a load type) relative to Generation Replacement and Load Following (GR and LF) tariffs, whether PHP load can be split into dispatchable and interruptible portions, and the implications of holding PHP load as Operating Reserve. It also asks for historical examples and workpapers related to these matters.

c. Please describe if the load reduction should have been instituted as a real time 1 b. Please provide the date and time of interruptions and direct control actions for PHP for 2 each of 2022, 2023, 2024, and 2025. Please provide an estim...

AI summary The text includes a request for details on load reduction during specific peak periods, including the dates and times of interruptions and direct control actions for PHP in 2022–2025, and the associated capacity reductions. It also asks about the impact of not reducing load during certain peak hours and the associated costs or benefits.

icing of the interruptible credit ($13.107 per kVA demand coincident with system peak). 5. Refer to the Application, p. 8 regarding interruptible service and the Large Industrial Interruptible Rider (LIIR). 1. Please provide the total load...

AI summary The document contains a series of questions regarding the Large Industrial Interruptible Rider (LIIR) and the Large Industrial Class (PHP) related to load reduction capacity, interruption timing, and system peak data for the past four years. It also requests information on the ELID tariff and its relation to the Large Industrial tariff.

been enrolled in the Large Industrial Interruptible Rider for 2023 and 2024. 7. Refer to the Application, p. 3, lines 13-15. Are there any differences between the “Dispatchable Rider” under the ELID tariff and the “Active Demand Control” u...

AI summary The text outlines a series of questions directed at an applicant regarding the Large Industrial Interruptible Rider (LIIR), the Dispatchable Rider under the ELID tariff, and the Active Demand Control under the ELIADC tariff. It also requests clarification on the derivation of firm and interruptible load calculations, the use of three coincident peaks (3CP) for billing determinants, and differences in how NS Power manages firm and interruptible load.

ts or procurements for firm load relative to interruptible load? In your response, please also explain whether NS Power assumes that 100% of interruptible load will be available when called, or whether some other value is used, and how tha...

AI summary The text contains a series of questions directed at NS Power regarding the assumptions and planning related to firm and interruptible/dispatchable load, specifically for PHP. It asks about historical data, design assumptions, and asset capacities related to PHP’s firm load.

ch service is comparable to interruptible service available to LIIR customers.” On page 8 of the application “the proposed interruptible credit applicable to PHP is the same as proposed for the LIIR.” 1. Please clarify and explain the diff...

AI summary The document requests clarification on the differences between interruptible and dispatchable riders, the necessity of the dispatchable rider despite existing interruptible credits, potential double-counting of credits, and whether the interruptible rider could be adapted to serve the same purpose. An Excel example is also requested to illustrate load changes under each rider.

r each of the following terms within the proposed Tariff, please describe if the PHPW PPA changes the calculation of the value after it enters service. If it does change the calculation of a value after entering service, please provide a w...

AI summary The text requests clarification on how the PHPW PPA affects the calculation of demand charges, minimum charges, and interruptible/dispatchable riders in the ELID Tariff. It also asks for an explanation of NS Power's conclusion regarding the adequacy of firm supply to accommodate an 8 MW increase in 2026.

ruptibility be broken into two components 2-A and 2-B with the riders ordered appropriately? 2. Can PHP be dispatched for load reduction prior to the first tier of interruptible load being interrupted, that being Generation Replacement and...

AI summary The text outlines a series of questions related to load management, interruptible load, and operating reserve in the context of energy regulation. It seeks clarification on the dispatch order of PHP, the splitting of load, the meaning of holding load as Operating Reserve, and the derivation of the ELID priority interruptible credit.

l examples of a comparable priority interruptible credit, if such a credit existed previously. If such a credit previously existed, please provide workpapers deriving the value of the credit. 10. Are the Generation Replacement and Load Fol...

AI summary The document contains a series of questions regarding interruptible and dispatchable load management, including the difference between dispatching and interrupting load, the application of the Interruptible Rider to load above a customer’s firm contracted load, and the calculation of system costs and load factors. Workpapers and Excel spreadsheets are requested for these inquiries.

1. Refer to the Direct Evidence of Port Hawkesbury Paper LP, p. 12, line 15 to page 13 line 9. 1. Please describe if NS Power agrees with the characterization of the event. If not, please provide any corrections. 2. Please describe why the...

AI summary The document contains a series of questions directed at NS Power regarding the implementation of load reductions under the ELIADC tariff, specifically focusing on the 60 MW load reduction event and whether the ADC and interruption protocol were followed. It also inquires about interruptions and direct control actions for PHP during specific peak periods.

during the peak periods of 1/11/2022, 2/15/2022, 12/13/2022, and 12/22/2023? If not, why not? 2. Please provide the date and time of interruptions and direct control actions for PHP for each of 2022, 2023, 2024, and 2025. Please provide an...

AI summary The text includes a series of questions directed at NS Power regarding load interruption events, cost causation related to peak demand, and confidential responses to undertakings and COSS. It focuses on specific dates and the impact of load reduction on resource capacity and grid stability.

2026 M12661 NOVA SCOTIA ENERGY BOARD IN THE MATTER OF: THE PUBLIC UTILITIES ACT and IN THE MATTER OF: An Application by Nova Scotia Power Inc. (“NS Power”) for approval of an Extra Large Industrial Dispatchable Above-the-Line Tariff applic...

AI summary Port Hawkesbury Paper LP is requesting NS Power to provide a breakdown of hourly Net Load by Customer Class, including PHP, from Figures 4 and 5 of the Cold Weather Event Report. This relates to the allocation of demand-related costs under the ELID Tariff class based on PHP assigned demand at the time of the three coincident peaks (3CP).

12-13, Figures 4 and 5. Question: Please provide a breakdown of the hourly Net Load as shown in each of Figures 4 and 5 of the Cold Weather Event Report by Customer Class, including PHP. IR-2 Reference: Application, page 5, line 21 to page...

AI summary The document discusses NS Power's proposal for determining PHP coincident peaks using judgment to represent system usage, and outlines proposed energy charges for 2026 and 2027. It raises questions about the methodology, use of judgment in other rate classes, and frequency of peak adjustments.

2027, would the change impact other FAM customers? Please explain. - b) Please provide the estimated Energy Charge for PHP in 2026 and 2027 assuming PHP's request to update the forecast generation from PHP Wind in 2026 and 2027 is granted....

AI summary The text outlines a series of regulatory inquiries related to PHP's forecast generation and energy demand, their impact on FAM customers, and the ELID Tariff's ability to recover FLG costs. These requests involve assessing NSPI's role, evaluating forecast accuracy, and understanding the implications of various assumptions on energy charges and FAM balances.

25. Please provide PHP’s annual energy demand forecast for 2020, 2021, 2022, 2023, 2024, and 2025. For clarity, this request refers to forecasts developed by PHP and provided to NSPI. 26. Please provide PHP’s actual annual energy demand fo...

AI summary The text contains a series of questions directed at Nova Scotia Power Inc. (NSPI) and Prince Heritage Power (PHP) regarding energy demand forecasts, financial assumptions, and the impact of various scenarios on the FAM balance, as well as inquiries about the ELID Tariff and PHP’s financial condition.

1 (ii) If the 2026 costing is based on partial year load from ELID 2 during 2026, how would the ELID peak load allocation (3CP) 3 be determined? For example, if PHP commences ELID 4 service partway through 2026, ELID load may only be 5 pre...

AI summary The document raises a question regarding the methodology for determining the 3CP (three coincident peak) allocation for ELID (Extra Large Industrial Dispatchable Above-the-Line) if the 2026 costing is based on partial year load, specifically if PHP (Port Hawkesbury Paper) commences ELID service partway through 2026.

1 (b) Please quantify the impact on all other class rates of using 65 MW versus 2 8 MW as the PHP 3CP determinant for both 2026 and 2027. 3 Request IR-4: 4 Reference: N-1, ELID Application, pages 5-6. 5 Preamble: NSPI indicates that the "P...

AI summary The request asks NSPI to quantify the impact on all other class rates of using 65 MW versus 8 MW as the PHP 3CP determinant for 2026 and 2027. It also asks for evidence and details regarding the 8 MW demand determinant and whether it is derived from the 12 MW minus 4 MW as stated by PHP.

1 Request IR-11: 2 Reference: N-1, ELID Application, Page 8 lines 19-26. With respect to the SA priority interruptible service provisions, the Company's initial analysis of the priority interruptible service has determined the primary dire...

AI summary The Company argues that priority interruptible service is valuable for reducing interruption risks and system reliability, citing its low annual cost of $500,000. The request asks for detailed data, internal protocols, economic analysis, and clarification on why discontinuation would be premature.

1 (c) Please confirm that ELID DR gives NSPI full authority to dispatch PHP up 2 and down dynamically at all times, including during system peak? If not, 3 please explain. 4 (d) Please confirm that NPCC Directory 5 Operating Reserve Requir...

AI summary The text requests confirmation on whether ELID DR grants NSPI full authority to dynamically dispatch PHP during system peaks and clarifies the conditions under which PHP is considered available for reserve requirements, referencing the NPCC Directory 5 Operating Reserve Requirement.

17 Request IR-15: - 18 (a) Given the DR enables NSPI to actively manage PHP's load in real time in 19 response to system conditions, please identify the specific incremental 20 system capability that priority interruptibility provides that...

AI summary The request seeks clarification on the incremental system capability provided by priority interruptibility compared to DR dispatch, the calculation of controllable capacity from priority interruptibility, and under what conditions NSPSO would use priority interruptibility separately from DR dispatch.

1 2 (d) Please provide historical and forecasted hours in which NSPI expects priority interruptibility will be: 3 (i) Operationally necessary; 4 (ii) Materially different from DR dispatch; and 5 (iii) Not substitutable with DR load reducti...

AI summary The document includes a request for historical and forecasted hours in which NSPI expects priority interruptibility to occur, and a detailed request (IR-16) concerning the Dispatchable Rider mechanism, FAM accounting, and the review process for FAM supply cost modelling.

1 Request IR-18: 2 Reference: N-1, ELID Application, page 10, lines 9-12. 3 4 5 6 7 8 construct. The cost of the DR service (DR credit) is proposed to be included as a FAM cost for recovery from all ATL customers, including PHP. Subject to...

AI summary The document requests Nova Scotia Power Incorporated (NSPI) to provide estimates of the annual DR credit cost for 2026 and 2027, confirm changes to the FAM Plan of Administration, explain the impact of including DR credit as a FAM cost, and define 'held harmless.' The DR credit is proposed to be recovered from all ATL customers, including PHP.

- 8 (b) If PHP is dispatched down entirely that is, to its firm level of 8 MW 9 through the Dispatchable Rider, will NSPI simultaneously consider that 10 PHP has been "interrupted" within the meaning of the Interruptible Rider? 11 If not,...

AI summary The text raises questions about how Nova Scotia Power Incorporated (NSPI) would handle scenarios where Port Hawkesbury Paper (PHP) is dispatched down under the Dispatchable Rider and whether this would be considered an interruption under the Interruptible Rider. It also inquires if PHP could receive both a DR credit and an interruptible credit for the same load reduction and how NSPI would avoid double-counting.

20 Request IR-24:

AI summary The document outlines Request IR-24, which includes various topics related to energy efficiency, demand response, and regulatory processes. It discusses the need for updated programs and the evaluation of existing initiatives.

21 Reference: N-1, ELID Application, Attachment 1, ELID Tariff, page 7 of 8 In situations in which load of the Customer under this Tariff is held as Operating Reserve, NS Power may change the above order of interruption by interrupting Lar...

AI summary The text discusses a provision in the ELID Tariff allowing NS Power to change the order of interruption, potentially interrupting LIIR customers before PHP. Questions are raised about the circumstances under which this might occur, its interaction with the priority interruptible credit, and whether LIIR customers have been interrupted ahead of PHP under ELIADC in the past.

4 Request IR-25: - 5 (a) Where GRLF is interruptible in advance of ELID, why should ELID be 6 afforded a priority credit above GRLF? - 7 (b) Were other LII customers offered the opportunity to obtain additional credit 8 for priority interr...

AI summary The text presents three questions regarding priority credit for ELID over GRLF, opportunities for other LII customers to obtain credit for priority interruptibility, and the value of PHP compared to other telemetry customers, all in the context of NSPI and DR load shifting.

12 Request IR-26: 13 Reference: N-1, ELID Application, Attachment 1, page 8 of 8. Customers taking service under the ELID Tariff will also be subscribed to this Dispatchable Rider (DR). Under this Rider, NS Power will be able to actively m...

AI summary The text discusses the ELID Tariff and the Dispatchable Rider (DR), which allows NS Power to manage customer load under specific terms and conditions. It requests the specific process or operating protocol NSPI will use to document whether load reductions at PHP are made under the Interruptible Rider or the Operating Procedure under the Dispatchable Rider.

- 2 Reference: N-2, Evidence of C. Fitzhenry and M. Gorman, page 21. - 3 Preamble: Brubaker & Associates, Inc. indicates that the $160.44/kW annual levelized - 4 avoided peaker cost used in determining the proposed $7.661/kVA monthly credi...

AI summary The text references a cost benchmark for interruptibility credits used by NSPI and questions whether it is outdated. It also asks NSPI to comment on potential adjustments to customer rates if a higher avoided cost value is adopted, particularly in the context of the ELID rate and the resolution of M12661.

and 24 LIIR interruptibilty credits are revised upward as part of the 25 resolution of M12661. If so, please indicate how other 26 customer rates may need to be adjusted to implement this 27 outcome. 1 (iii) The PHP proposal is accepted, a...

AI summary The text discusses adjustments to interruptibility credits for LIIR and ELID as part of the resolution of M12661, and requests an analysis of how customer rates may need to be adjusted. It also asks for a discussion on regulatory principles of fairness between classes if the PHP proposal is accepted and the ELID interruptibility credit is based on a higher avoided cost benchmark.

r machine running, there is approximately 12MW of demand on site, that includes approximately 4MW that is needed to maintain the shared services required for the NSPI Port Hawkesbury Biomass Plant”. 1. Please provide all relevant informati...

AI summary The text discusses NSPI's proposal to use the 8 MW 3CP demand determinant for billing purposes, referencing a 12 MW connected load with 4 MW allocated to shared services. It requests evidence for the 8 MW figure and a breakdown of connected loads, as well as past load interruption events.

1. Please provide all data or internal documentation making up NSPI’s “initial analysis” of the priority interruptible service, including details on the interruptions determined to be avoided. 2. Please provide a copy of NSPI’s internal in...

AI summary The document contains a series of questions directed at NSPI regarding its priority interruptible service, including data on interruptions, internal protocols, economic analyses, and the operation of ELID under the ELIADC. It also references a regulatory application and requests clarification on dispatch procedures and compliance with reserve requirements.

es does NSPI consider that PHP will be available? Please provide historic examples. Reference: M12184, Application for a Successive Term for ELIADC, N-4, NSPI (BW) RIR- 11: BW Request IR-11: Please refer to Exhibit N-1, page 9 lines 5 to 7...

AI summary The document asks NSPI to provide historic examples of PHP's availability and its role in avoiding Energy Emergency situations. NSPI responds that it does not track avoided emergencies but notes that PHP has been dispatched down during high load conditions to manage supply and demand.

1. In the above extract, NSPI states PHP is dispatched down to minimum load when the Energy Emergency Response Procedure is activated. Please confirm this means that there is no load left for PHP to interrupt in such circumstances. If not,...

AI summary The document text contains a series of questions directed at NSPI regarding the dispatch and interruption practices of PHP under the ELIADC tariff during energy emergencies and load constraints. It asks for detailed explanations and data on interruptions, customer responses, and the availability of PHP load in various scenarios.

under which PHP (or its predecessor owners of the mill) has taken service and specify the applicable tariff in each case. Reference: N-1, ELID Application, page 9 – Priority Interruptible Credit. 1. Please provide all workpapers, calculati...

AI summary The document requests detailed explanations and supporting calculations regarding the priority interruptible credit values, the derivation of the 10% premium, and the distinction between priority interruptibility and DR dispatch. It also seeks clarification on the conditions under which priority interruptibility might be called upon separately from DR dispatch.

outcomes where ATL customers would not be held harmless? Please explain, and discuss the risk factors including those within or outside the control of NSPI. Reference: N-1, ELID Application, page 11. Consistent with the ELIADC Tariff, PHP...

AI summary The text discusses the ELID Application, focusing on the Operating Procedures for PHP under the DR and how they differ from the ELIADC Tariff. It raises questions about the assurance of holding ATL customers harmless, the public interest in reviewing Operating Procedures, and the timeline for their development.

emand is equal to or less than the contracted firm demand, no interruptible credit shall apply. The billed interruptible demand will be equal to the interruptible demand used for costing the tariff. 1. Please confirm that the "billing dema...

AI summary The text discusses billing demand calculations for interruptible credits, the distinction between being dispatched down under the Dispatchable Rider and being interrupted under the Interruptible Rider, and whether PHP can simultaneously receive both a DR credit and an interruptible credit for the same load reduction. It references the ELID Application and ELID Tariff.

S Power may change the above order of interruption by interrupting Large Industrial Interruptible Rider Tariff customers whose load is not held as Operating Reserve before interrupting the Customer. 1. Please explain in what circumstances...

AI summary The text discusses potential changes to the order of customer interruption under the Large Industrial Interruptible Rider Tariff (LIIR) and Extra Large Industrial Dispatchable Capacity (ELID), raising questions about priority status, credit for interruptibility, and how PHP (Port Hawkesbury Paper) compares to other customers in terms of value and priority.

load after DR load shifting as Operating Reserve, please explain how PHP offers any value over and above any other telemetry customer? Reference: N-1, ELID Application, Attachment 1, page 8 of 8. Customers taking service under the ELID Tar...

AI summary The document discusses the ELID Tariff and Dispatchable Rider (DR) under which NS Power manages customer load, including the distinction between load reductions under the Interruptible Rider and the Operating Procedure. It also outlines the requirement for NS Power to report annually on system savings and provide credits based on cost differentials.

4 Request IR-2: - 5 Preamble : NSPI's evidence states that optimal dispatch of PHP's load could yield 6 system savings of $7–$11 million annually – which would accrue to PHP under the DR 7 credit – but that realized savings may be approxim...

AI summary NSPI claims that optimal dispatch of PHP's load could yield system savings of $7–$11 million annually, but realized savings may be about half that. The request asks PHP and BAI to assess the reasonableness of this range and identify key assumptions and constraints affecting the difference between optimal and realized savings.

10 Reference: N-3, Evidence of PHP, page 9, ADC Energy Supply Protocol. - 11 (a) Provide the Active Demand Control ("ADC") Energy Supply Protocol in its 12 entirety, including all appendices, schedules, and amendments. - 13 (b) Identify, i...

AI summary The document requests the provision of the ADC Energy Supply Protocol in its entirety and asks PHP to identify provisions it intends to retain, amend, or replace under the proposed ELID tariff, as well as operational constraints that may affect PHP's ability to respond to dispatch instructions.

10 Request IR-9:

AI summary The document outlines Request IR-9, which pertains to a regulatory proceeding involving Nova Scotia Power Inc. and the Nova Scotia Utility and Review Board. The request is part of a broader discussion on energy efficiency and demand-side management initiatives.

- 3 Maritime Link trip event and states, "This was neither a real time (RT) schedule dispatch - 4 nor an NSPSO call for interruption." - 5 And Reference: N-2, Evidence of C. Fitzhenry and M. Gorman, page 16, lines 9-11. - 6 Amidst this eve...

AI summary The text references a Maritime Link trip event and questions why PHP concluded it was not a real-time schedule dispatch. It requests a list of load reduction events outside formal protocols, confirmation of dispatch instructions during specific hours, and an explanation of how dispatch control should inform capacity cost allocation under the ELID tariff.

1 Request IR-11: - 2 Reference: N-3, Evidence of PHP, pages 12-13. - 3 Preamble: PHP states that there are aspects of PHP's load flexibility that are not being - 4 captured in the ELID filing, and that the benefits from the February 13, 20...

AI summary PHP argues that aspects of its load flexibility are not captured in the ELID filing and that the benefits from the February 13, 2026, Maritime Link event should be considered as an additional ancillary service value. The request seeks clarification on whether PHP is seeking separate compensation and how this value would be quantified and funded.

Reference: N-1, ELID Application, page 3. Preamble: NSPI’s Application states that "[t]he Tariff costing and billing parameters are applied as noted in the Settlement Agreement (SA) which underpins the Company's 2026-2027 General Rate Appl...

AI summary The document discusses the consistency of the ELID Tariff with the Settlement Agreement (M12451), the reasonableness of estimated system savings from PHP's load dispatch, and the recommended R/C ratio for ELID. It includes questions for PHP and BAI on these topics.

sociates, Inc., states that the current ELID R/C ratio is 1.04373 and recommends an R/C ratio of 1.0 " ensuring PHP pays its cost to serve without subsidizing or being subsidized by other classes. " 1. Please confirm that PHP agreed to an...

AI summary The text discusses the ELID R/C ratio, interruptible credit calculations, and revenue implications of reducing PHP's demand determinant. It includes questions posed regarding regulatory principles, supporting decisions, and financial impacts on various tariff classes.

Preamble: BAI calculates that reducing PHP's demand determinant from 65 MW to 8 MW reduces PHP's revenue requirement by approximately $6.5 million in 2026 and approximately $9.4 million in 2027. 1. Identify precisely where, in NSPI’s COSS,...

AI summary The document requests clarification on the financial impact of reducing PHP's demand determinant, including reallocation of costs to other customer classes and the effects on various charges. It also asks for the ADC Energy Supply Protocol and operational constraints related to PHP's ability to respond to dispatch instructions.

pt service under the ELID tariff. PHP would need to undertake the development of a below-the-line tariff with NS Power that meets the mill’s needs if it chooses to not accept service under the ELID. 1. Please specifically identify what app...

AI summary PHP is seeking approval from the Board for modifications to the ELID tariff or an alternative below-the-line tariff to meet the mill’s needs. If the ELID tariff is not modified, PHP may decline service under it. The document references a specific event where PHP’s demand was significantly reduced during a peak period.

enry and M. Gorman, page 16, lines 9-11. Amidst this event, PHP’s demand was dispatched down to approximately 9 MW, its lowest recorded level during any coincident peak in that two-year window. 1. Why does PHP conclude this was not a real...

AI summary PHP's demand was reduced to 9 MW during a coincident peak, raising questions about dispatch practices and the accuracy of the ELID tariff. PHP argues that its load flexibility and the benefits from the Maritime Link event should be considered in the demand allocator and as an additional ancillary service value.

ing, and that the benefits from the February 13, 2026, Maritime Link event are something that needs to be considered as an "additional ancillary service value" beyond ADC and priority interruptible. 1. Is PHP seeking separate compensation...

AI summary The text discusses the need to consider the benefits from the February 13, 2026, Maritime Link event as an 'additional ancillary service value' beyond ADC and priority interruptible. It asks whether PHP is seeking separate compensation for this value and how it would be funded, as well as how to quantify the system value of off-protocol curtailments provided by PHP.

27 1 2 (b) What factors does Ms. Whited believe make a transition appropriate or not appropriate? 4 5 6 (d) Is it Ms. Whited's understanding that the current proposal is unlikely to result in uptake by PHP based solely on PHP's own evidenc...

AI summary The text includes questions and references related to a regulatory proceeding, focusing on factors influencing a transition, PHP's proposal for demand charges, and references to evidence provided by Synapse. It also raises questions about whether PHP's proposal would lead to uptake based on its own evidence and independent analysis.

33 that PHP was already contributing to some fixed cost recovery via the VCC 1 in the context of the ELID Tariff; and (ii) whether it would produce a demand 23 to PHP. Note that even at a reduced PHP net energy consumption of 304,000 24 MW...

AI summary The text discusses the Variable Capital Charge (VCC) and its role in fixed cost recovery for PHP under the ELID Tariff. It questions whether increasing the DR credit sharing ratio from 25% to 100% is justified, as PHP contributes to fixed system costs. It also asks if InterGroup supports benefit sharing similar to the ELIADC model rather than full allocation of DR savings to PHP.

Preamble: In s. 6.0, Proposed ELID Interruptible Rider, InterGroup stated: NSP confirmed that PHP can simultaneously receive (i) a DR credit for being dispatched down through the Dispatchable Rider and (ii) an interruptible credit for havi...

AI summary InterGroup raises concerns about potential double-counting of credits for PHP under both the Dispatchable Rider and the Interruptible Rider, suggesting this may provide undue benefits to PHP at the expense of other customers. The question asks whether this represents a design flaw and what mechanisms could prevent double-counting.

34 (a) Given that LIIR customers who are not on Telemetry and Control ("T&C") 1 can be, and in practice are physically interrupted ahead of PHP in the 2 dispatch stacking sequence, does InterGroup agree that PHP's designation 3 as a "prior...

AI summary The text raises questions about the practical implications of the Priority Interruptible (PI) designation for PHP customers, given that they are often already dispatched down during system constraints. It also asks for justification for the 10% PI credit in the 2026 and 2027 test years. The Board is recommended to approve the ELID Tariff's Interruptible Service component with a review prior to 2028.

- 9 (c) Bates White identifies that many variables affecting PHP's load are 10 "unrelated to the price of energy in Nova Scotia." Is there a CBL 11 methodology that can reliably separate the price-responsive component of 12 PHP's load vari...

AI summary The text raises questions about the methodology for separating price-responsive load variations from external factors affecting PHP's load and compares the current approach to how demand response was handled under ELIADC.

17 Request IR-6: 18 Reference: N-20 Bates White Evidence, at p. 23, lines 19-23. We are unconvinced that PHP would ever have incentive to levelize its load. PHP itself explains that its load is dependent on its business activity, is subjec...

AI summary The text discusses the argument that PHP (Paper and Pulp) has no incentive to levelize its load due to the nature of its business, which is tied to seasonal fluctuations and order book activity, leading to significant variations in energy consumption throughout the year.

29 (a) Does Bates White agree that its finding that PHP would have higher 30 demand in winter and summer months is inconsistent with PHP's evidence 31 on this proceeding? If not, please explain. 1 2 (b) If confirmed, are there any conseque...

AI summary The text raises questions about Bates White's findings regarding PHP's demand patterns and their consistency with PHP's evidence. It also questions whether a levelized high load factor CBL overstates savings and whether FAM customers should pay PHP for load variations unrelated to NSPI's pricing signals.

Request IR-10: Reference: N-20, Bates White Evidence, p. 27, lines 4-9. Our sixth concern is that the DR credit represents a zero-sum mechanism that, if incorrectly calculated, could harm other FAM customers. Any load "smoothing" exercise...

AI summary The text raises concerns about the DR credit mechanism, suggesting it could be a zero-sum game that may overestimate benefits if not calculated correctly, potentially harming FAM customers by misattributing load variations to PHP rather than system conditions.

And at p. 28, lines 14-21: We do not recommend that the Board approve the DR credit as proposed. To be reasonable, at least two things must be true: (1) any payments to PHP from FAM customers under the DR credit must demonstrably tied to P...

AI summary The text critiques the proposed DR credit mechanism, arguing it is too vague and unverifiable. Bates White outlines concerns and suggests revisions for approval. Questions are raised about the necessity of resolving all six concerns, the impact of benefit-sharing arrangements, and potential tariff amendments to address overestimation risks.

30 reflective of the paper market order book) or retain a benefit-sharing 31 arrangement. Does Bates White have any objection in principle to a form 1 2 3 of benefit-sharing approach as is currently in place under the ELIADC (75/25 in favo...

AI summary The text discusses a benefit-sharing arrangement under the ELIADC and its potential application to the ELID DR credit, as well as the methodology for calculating a true-up mechanism. It also references a zero net load scenario involving Goose Harbour.

inistering the ELID Tariff and how NSPI plans to ensure that 100% of the costs incurred above in administering the ELID Tariff are paid by PHP, including those above the Customer Charge collections. - 13 (a) Would Bates White agree that qu...

AI summary The text discusses the administration of the ELID Tariff and the responsibility of NSPI to ensure that PHP covers all costs incurred above the Customer Charge collections. It also includes questions about reporting requirements, true-up mechanisms, and evaluation processes related to Goose Harbour output and DR credit accruals.

Application by NS Power for Approval of an Extra Large Industrial Dispatchable Above-the-Line Tariff Applicable to Port Hawkesbury Paper (NSUARB M12661) PHP Information Requests to the CA (InterGroup) IR-5 Reference: Testimony, page 10. "I...

AI summary InterGroup raises concerns about the complexity of the proposed ELID Tariff, particularly the change in the DR credit ratio to PHP, suggesting the reasonableness of this change should be further tested. Questions are posed regarding whether benefits and penalties from one customer class should affect others.

energy requirements (prior to non dispatchable wind energy credits) at a high load factor. Absent other values provided by NSP consistent with the concept of a CBL, the value should be set at 120 MW." - (a) Please explain whether under thi...

AI summary The document includes questions regarding the proposed ELID tariff for PHP, focusing on capacity-based load (CBL) operation, energy and capacity cost impacts, and DR credit allocation. It also references concerns about over-crediting PHP for demand response (DR) activities and suggests retaining benefit sharing mechanisms similar to the ELIADC tariff.

terns relied upon by NSPI are representative of what PHP's demand will be during the tariff period, or whether Bowman's average demand methodology can instead be used for this unique tariff structure. A second example of contested issues t...

AI summary The document discusses disputes over the credibility of evidence and factual issues that cannot be resolved solely on the written record. Key issues include the methodology for calculating demand patterns and the Customer Baseline Load (CBL) for load-shifting activities, with concerns raised about potential overvaluation of dispatchable load contributions.