Topic:"System Reliability" in M12661

EXTRA LARGE INDUSTRIAL DISPATCHABLE TARIFF Page 4 of 8 (25,000 kVA and over) Rate Code X - (2) The Company will withdraw the availability of this tariff to any specific firm load only customer, if, on a consistent basis, the customer is no...

AI summary The tariff requires customers to maintain a minimum load of 25,000 kVA, with exemptions for those under the interruptible rider. The company reserves rights to enforce service agreements and operating agreements to ensure power supply integrity, considering factors like reliability and harmonic levels.

Special Conditions (1) The Company reserves the right to have a separate service agreement if in the opinion of the Company, issues not specifically set out herein must be addressed for the ongoing benefit of the Company and its customers....

AI summary The Company reserves the right to impose separate service agreements if necessary for system integrity. The Customer must ensure their load does not harm the power supply system through design or operation, with specific requirements outlined in a written agreement. Factors like reliability, harmonic levels, and voltage flicker are considered when assessing potential system integrity risks.

Order of Interruptibility In the event an interruption call is required in order to avoid shortfalls in system electricity supply, interruptible load will be called upon to provide capacity to NS Power in the following order: - (1) Generat...

AI summary The Order of Interruptibility outlines the priority sequence for interrupting load during electricity supply shortfalls, starting with Generation Replacement and Load Following Tariff, followed by Extra Large Industrial Dispatchable Tariff, Shore Power Tariff, and finally the Interruptible Rider to the Large Industrial Tariff. NS Power may adjust this order if necessary.

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.

3 Q DOES NS POWER RESOURCE PLANNING IDENTIFY HOW PRODUCTION 4 RESOURCE CAPACITY IS IDENTIFIED TO SERVE THE ATL PEAK DEMAND? 5 A. Yes. NS Power's resource planning design specifies targeted resource reliability to 6 achieve a loss of load e...

AI summary NS Power's resource planning ensures a 0.1 days/year loss of load expectation by using effective capacity ratings of generating resources and a 21% planning reserve margin relative to ATL's Firm Peak Load Net of DSM.

10 Q ARE THE INTERRUPTIBLE SERVICE AS CONTAINED IN THE ELID AND THE LIIR 11 COMPARABLE? 12 A No. The LIRR interruptible service is limited to system reliability support. In contrast, 13 the ELID tariff provides interruption for economic an...

AI summary The ELID and LIIR interruptible services are not comparable. LIIR is limited to system reliability support, while ELID serves both economic and reliability purposes. ELID allows NS Power to interrupt PHP supply as a dispatch resource, whereas LIIR has limited interruption hours and is not used as a dispatch resource.

13 Q IS NS POWER'S NEED FOR RESOURCE CAPACITY TO SERVE PEAK DEMAND 14 EXPECTED TO CHANGE GOING FORWARD? 15 A Yes. The obligation for NS Power to retire its remaining coal-fired generation by 2030 16 is a primary driver for an anticipated i...

AI summary NS Power anticipates increased capacity costs due to retiring coal plants by 2030, creating a 'capacity gap.' To address this, investments in natural gas, battery storage, and transmission are required. Operating reserves and dispatchable capacity are critical for reliability, with PHP's interruptible demand becoming increasingly valuable during the energy transition.

Testimony and Regulatory Litigation Support Mr. Fitzhenry has provided expert testimony in utility regulatory proceedings before state commissions in connection with rate cases and various other utility matters. In addition, Mr. Fitzhenry...

AI summary Mr. Fitzhenry has testified in utility regulatory proceedings on topics including capital expenditure prudency, net power cost, multi-year rate plans, and service reliability. He has collaborated with outside counsel on litigation strategies for rate proceedings, including testimony development and legal brief preparation.

Testimony in Utility Regulatory Proceedings Summary of Testimony in Utility Regulatory Proceedings Application Commission Docket/Case No. Subject Ameren Illinois Company Illinois Commerce Commission Docket No. 22-0487 Capital Projects and...

AI summary This table lists various utility regulatory proceedings across multiple states, detailing the applications, commissions, docket numbers, and subjects of each case, including topics like capital expenditures, system reliability, and integrated resource planning.

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.

15 Q. Aside from ADC and being priority interruptible, are there other aspects 16 of PHP's load flexibility that are not properly being captured in the ELID 17 tariff filing? 18 19 A. Yes. For example, on February 13, 2026 at approximately...

AI summary PHP's load flexibility during grid incidents (e.g., Maritime Link trip) is not fully captured in the ELID tariff, as it involved unplanned load reductions outside ADC and priority interruptible protocols. PHP's role in system reliability during such events highlights a gap in ancillary service value recognition within current tariff frameworks.

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 This table presents Nova Scotia Power Inc.'s sales, generation, and demand analysis, including metrics such as MWH, energy losses, system demand, and contribution percentages. It provides a breakdown of various factors impacting energy distribution and demand in the region.

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.

NOVA SCOTIA POWER INC. SUMMARY OF DISTRIBUTION SYSTEM ENERGY LINE LOSSES FOR THE YEAR ENDING DECEMBER 31, 2026

AI summary Nova Scotia Power Inc. provides a summary of distribution system energy line losses for the year ending December 31, 2026, focusing on operational metrics related to energy transmission efficiency.

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.

DETERMINATION OF CLASS NON-COINCIDENT KW DEMAND BY VOLTAGE LEVEL (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) COMPANY DOMESTIC GENERAL GENERAL LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL ELI 2P-RTP MUNICI...

AI summary The text presents a detailed table with data on non-coincident kilowatt demand by voltage level, including losses and sub-totals for different classes of demand. It includes percentages of losses at various stages, such as secondary and primary non-coincident kilowatt demand before and after the bulk power substation.

SUMMARY OF SYSTEM ENERGY LINE LOSSES FOR THE YEAR ENDING DECEMBER 31, 2027

AI summary This document provides a summary of system energy line losses for the year ending December 31, 2027, focusing on the performance of the electricity distribution network.

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 % (34)EHV, HV, DIS...

AI summary The document presents a table with various metrics related to energy and system demand for the year ending December 31, 2026, including values for MWH, energy line, system demand, and percentages related to 3CP. The table includes variances and percentages across different categories, such as EHV, HV, distribution, and municipal subtotals.

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 energy sales, losses, and demand metrics for April 2026, including subtotals and totals for different categories such as Shore Power, Generation Replacement, and ELIADC. It highlights various percentages and values related to energy and demand factors.

NOVA SCOTIA POWER INC. NOVA SCOTIA POWER INC. SUMMARY OF SYSTEM ENERGY LINE LOSSES SUMMARY OF SYSTEM DEMAND LINE LOSSES FOR THE YEAR ENDING DECEMBER 31, 2026 FOR THE YEAR ENDING DECEMBER 31, 2026

AI summary The document presents a summary of system energy line losses and system demand line losses for Nova Scotia Power Inc. for the year ending December 31, 2026. No specific data or analysis is provided in the text, only the title of the report.

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 text presents a table with various energy and demand metrics, including MWH sales losses, energy line, energy requirement, and system demand factors. The table appears to be related to electricity distribution and system performance analysis for June 2027.

FOR SEPTEMBER 2027 (1) (2) ENERGY (3) (4) CLASS NON- (5) SYSTEM (6) SYSTEM (7) DEMAND (8) SYSTEM (9) SYSTEM (17) SUB-TOTAL 60,061 18.1% 61,549 87,442 334.7% 62,968 15.20% 65,119 0.00% (18) TOTAL Bfr EXPORT 709,739 6.3% 754,786 1,508,477.72...

AI summary The document presents a table with various energy-related metrics for September 2027, including energy sales, losses, and demand factors. It provides data on system demand, energy requirements, and export sales, though some values are missing or marked as N/A.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 (132) Distribution BP Substation - LIR 8,309.6 (133) Distribution BP Substation - Municipal (134) Distribution Primary Voltage - LIR 50,427.4 (135) Distribution Primary Voltage...

AI summary The document presents a table with allocation factor information for various distribution and transmission systems, including line losses and demand management data. The table lists different system components and their corresponding values, but no specific arguments or claims are discussed.

FOR AUGUST 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 detailed breakdown of energy sales, generation, and demand across various customer classes in Nova Scotia for August 2026, including metrics like line losses, energy requirements, and demand factors.

FOR MARCH 2027 (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 (1) MWH SALES LOSSES (2) ENERGY LINE (3) ENERGY REQUIREMENT...

AI summary The document presents a table with various energy and demand metrics, including MWH sales losses, energy line, energy requirement, demand losses, and system coincident demand factors. These metrics are categorized under different classes and system conditions, such as non-coincident and coincident demand.

FOR DECEMBER 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) LOSS...

AI summary The table presents energy sales, losses, and demand data categorized by customer class for December 2027. It includes metrics such as energy losses, system demand, and load factor for various customer segments, including domestic, industrial, and municipal.

SYSTEM COINCIDENT DEMAND LINE LOSSES BY RATE CLASS (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) COMPANY DOMESTIC GENERAL GENERAL LARGE INDUST. INDUST. INDUST. UNMETERED 12.56% 14.18% 12.44% 11.18% 6.86% 14.01%...

AI summary The table presents system coincident demand line losses by rate class, showing varying percentages (e.g., 5.70% for large industrial, 14.18% for small domestic) across classes. The data highlights differences in losses between domestic, general, industrial, and unmetered categories, with ELIADC and C/P acronyms referenced.

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 presents a detailed analysis of sales, generation, and demand for the year ending December 31, 2027, including metrics such as MWH, energy losses, system demand, and contribution percentages across various categories and classes.

SUMMARY OF SYSTEM DEMAND LINE LOSSES FOR THE YEAR ENDING DECEMBER 31, 2026

AI summary This document provides a summary of system demand line losses for the year ending December 31, 2026. It outlines the performance and efficiency of the power distribution system during this period.

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 detailed table of energy sales, generation, and demand analysis for October 2026, including metrics such as MWH sales losses, energy line losses, demand losses, and system factors for various customer classes and programs. The data reflects the performance of Nova Scotia Power Inc. across different sectors and programs.

SUMMARY OF SYSTEM ENERGY LINE LOSSES FOR THE YEAR ENDING DECEMBER 31, 2026

AI summary This document provides a summary of system energy line losses for the year ending December 31, 2026. It outlines the key factors contributing to energy losses within the transmission and distribution network.

ALLOCATION FACTOR INFORMATION Calendar Month of System Peak 1 SUMMARY OF SYSTEM LINE LOSSSES 9D

AI summary The document provides a summary of system line losses, with a reference to '9D' in the context of calendar month of system peak. The table structure and heading suggest an analysis related to system performance and losses during peak periods.

FOR NOVEMBER 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 COINCIDE...

AI summary The document presents a detailed table of energy sales, generation, and demand analysis for November 2027, including metrics like MWH sales losses, energy line losses, demand losses, and system coincident demand factors across various customer classes and sectors.

FOR MARCH 2026 (1) (2) (3) (4) (5) (6) (7) (8) (9) (17) SUB-TOTAL 21,547 19.6% 22,150 89,204 178.7% 60,139 16.58% 62,593 0.00% (18) TOTAL Bfr EXPORT 1,063,026 7.8% 1,145,464 2,218,084.14 85.4% 1,894,191 9.16% 2,067,656 74% (19) EXPORT SALE...

AI summary The table presents financial and operational data for March 2026, including sub-total figures, percentages, and export-related metrics. It includes categories such as energy sales, losses, demand factors, and other operational indicators.

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 (9) SYSTEM COIN. PEAK COINCID...

AI summary The document presents a table with various metrics related to energy sales, losses, demand, and system factors for September 2026. It includes subtotals and totals for different categories such as shore power, generation replacement, and real-time pricing. The data highlights percentages and values for energy sales losses, energy line, and system demand factors.

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 detailed table of energy sales, losses, and demand metrics for August 2027, categorized by customer class and including special programs like ELIADC and EBS/RTR. It provides a breakdown of total energy sales, system demand, and related factors, with a focus on various customer segments and special programs.

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 table with various metrics related to energy generation and demand for the year ending December 31, 2027, including total generation, energy losses, demand factors, and related figures.

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 This table presents energy sales, losses, and demand metrics for December 2026, categorized by customer class. It includes data on energy requirement, system demand, and load factors, with a focus on different sectors such as domestic, industrial, and municipal.

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 presents a table with columns related to energy sales, losses, demand, and system factors for Nova Scotia Power Inc. in January 2027. It includes metrics such as MWH sales, energy losses, demand factors, and peak demand levels.

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.

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.

NSPI Responses to Industrial Group Information Requests 1 Request IR-15: 22 shortfall. In this context, there is no forecasting or pre-planned use for Priority Interruptible 23 load. 24 25 Historically, interruptible load has provided sign...

AI summary NSPI explains the historical value of interruptible load in addressing real-time capacity shortfalls and ensuring reliability for firm load customers, while noting that the value of Priority Interruptibility requires further assessment.

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.

NSPI Responses to NSEB Information Requests 1 Request IR-1: 26 While PHP continued to provide PI service under both tariffs, under neither tariff was the value of 27 PI service examined and quantified or the cost of service treatment assoc...

AI summary NSPI responded to NSEB information requests, explaining that it has not conducted a detailed analysis of the value and cost of PI service since the last rate application. Instead, it proposed using a modeled PI valuation of 10 percent as a proxy for reliability benefits.

REDACTED (h) Please explain how often frequently both PHP load was curtailed and LIIR customers were also interrupted over the past four years (2022-2025). (i) Please describe the circumstances required for PHP to be fully curtailed to its...

AI summary The text contains three questions regarding curtailment practices: frequency of PHP load and LIIR customer interruptions (2022-2025), conditions for full PHP curtailment with LIIR customer impacts, and maximum LI curtailment scenarios with customer distribution. These focus on operational procedures and system reliability considerations.

aggregate wind forecast NSPSO; - 7.7. PHP pulp storage levels PHP; and 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 that, in order to (1) assist PHP to efficiently r...

AI summary NS Power and PHP agree to share system data (demand, generation types) for operational coordination and unplanned system changes. NS Power will calculate ADC benefits annually using CBL data. Data use is restricted to operational purposes; misuse may suspend sharing.

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.

Circumstances in which Variances from Scheduled Dispatch Will Be Tracked The variance from the scheduled dispatch results in: - A change in NS Power unit commitment(s) - A need for NS Power to rebalance a fuel position - The redispatching...

AI summary The document outlines scenarios where variances from scheduled dispatch occur, including changes in unit commitment, fuel rebalancing, redispatching from Wreck Cove, lost export/import opportunities, excess energy conditions, and forced dispatch of PHP outside standard operating schedules.

Monthly System Peaks Month NS Peak MW 11-Jan-22 18:00 2216 15-Feb-22 19:00 2112 01-Mar-22 08:00 2024 04-Apr-22 18:00 1720 05-May-22 15:00 1422 27-Jun-22 18:00 1272 24-Jul-22 18:00 1402 07-Aug-22 18:00 1433 14-Sep-22 18:00 1336 31-Oct-22 09...

AI summary The document presents a table of monthly system peak demand (in MW) from 2022 to 2025, showing fluctuations with notable peaks exceeding 2200 MW. It also references NSPI's responses to information requests by Synapse Energy Economics, Inc., indicating regulatory engagement around system load data.

NSPI Responses to Synapse Energy Economics, Inc. Information Requests 1 Request IR-7: 2 firm load from PHP during the winter peak, as well as the PHP firm load amount 3 that the asset was designed to serve. 4 5 (g) What firm load from PHP...

AI summary The document outlines NSPI's response to information requests regarding the Port Hawkesbury Biomass plant's design capacity and the methodology used for identifying investments in generation, transmission, and distribution. The response includes details on load forecasting and system reliability criteria.

REDACTED 1 simultaneously interrupted, such that the remaining load is PHP's firm load 2 at 8 MW. 3 4 (1) If so, please provide a historical example of such splitting. 5 6 (2) If not, please explain how NS Power determines if load will be...

AI summary The text outlines a series of questions regarding load management practices, including load interruption criteria, Operating Reserve definitions, LIIR tariff overrides, and ELID priority interruptible credit calculations. It seeks clarification on NS Power's processes for determining load reduction as interruption vs. dispatch and historical precedents for reserve load handling.

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.

NON-CONFIDENTIAL 1 • System conditions were not stressed at the time of this peak and there were 2 no Advisories, Alerts, or Interruptions in place for non-firm customers, 3 consequently further reduction of load by PHP would not have brou...

AI summary The text states that during the peak period, system conditions were not stressed, and no advisories or interruptions were in place for non-firm customers. Consequently, further load reduction by PHP would not provide resource capacity or grid benefits.

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 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 document presents a detailed table of energy sales, losses, and demand metrics for July 2026, categorized by customer class and including various industrial and municipal segments. It includes metrics such as energy sales losses, energy line losses, demand losses, and system coincidence factors. The table also includes subtotals and totals for different categories, as well as a redacted attachment related to the ELID Tariff Synapse IR-30.

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.

REDACTED ELID Tariff Synapse IR-30 Attachment 2 Page 14 of 15 REDACTED (CONFIDENTIAL INFORMATION REMOVED) Category Usage Data Medium Industrial 37,761,228 34,388,307 37,154,644 34,300,556 36,745,594 38,469,740 38,399,377 35,849,667 35,276,...

AI summary The text presents a table containing usage data categorized by different industrial and municipal sectors, including figures for Medium Industrial, Large Industrial (FIRM and INT), PHP, and Municipal. The data spans multiple years and includes totals for each category.

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 summary of energy-related metrics for the year ending December 31, 2027, including energy usage, demand, losses, and various percentages related to system performance and efficiency.

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.

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, focusing on operational performance and efficiency metrics.

In its evidence, PHP states: These events go unnoticed by the public, yet time and again PHP is called upon as a resource for system reliability that is in a grey area between ADC real time dispatches and the NSPSO interruption protocol. T...

AI summary PHP highlights its role in system reliability between ADC dispatches and NSPSO protocols, arguing for recognition of additional ancillary service value in new ATL Tariff approvals. It seeks guidance on proposals for this value and post-2026 ELIADC tariff expiration planning.

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.

Response IR-7: - (a) See Synapse IR-2 for the Protocol and Appendix. For the Operating Mode Characteristics Schedule and amendments to it, see SBA IR-1(a-c). - (b) PHP agrees with NS Power's comment at page 11 of its Application that the O...

AI summary PHP agrees with NS Power that Operating Procedures (replacing ADC Protocol) are not part of the ELID Tariff and not subject to NSEB approval. Constraints during dispatch require communication with NS Power/NSPSO, with discreet line submissions. The process aligns with the Active Demand Control Energy Supply Protocol.

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.

omponent of the ELID tariff. PHP acknowledges a BTL alternative "may" have embedded cost-based, non-fuel components. It also may not. Request IR-6: Reference: NS Power Application, pages 8-9 of 19. With respect to the SA priority interrupt...

AI summary NS Power argues that maintaining priority interruptible service provisions in the SA is justified due to system reliability benefits, low annual costs (~$500,000), and potential risks from discontinuation during system transformation. The company proposes retaining the service until the next GRA for further review.

Response IR-8: BAI agrees that the application of the interruptible credit, that is that the per unit credit would be multiplied by a fixed, agreed upon, interruptible demand level, in the same manner as the LIIR class. However, that is wh...

AI summary BAI agrees with the interruptible credit structure for ELID but highlights differences in calculation methods compared to LIIR. ELID load is prioritized for interruption, potentially leading to more interruptions. NS Power argues that interrupting PHP load above 8 MW reduces system costs and supports reliability by using interruption as operating reserves.

Response IR-1: (a-c) See Confidential Attachment 1 to SBA IR-1(a-c) for NS Power's rolling dispatch of operating modes for each hour and PHP's load levels from 2020-2025. Note that the PHP load shown in the Attachment is inclusive of NS Po...

AI summary PHP provides data on operating modes and load levels from 2020-2025, noting one system emergency interruption by NSPSO in 2021. Other interruptions resulted from ADC or PHP operational decisions. Load data includes NS Power station service power for the Port Hawkesbury Biomass Plant.

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 The document outlines conditions for PHP's adherence to NS Power/NSPSO dispatch schedules, emphasizing compliance with system reliability, health, and safety standards. Deviations require collaboration to resolve discrepancies, ADC credit adjustments based on system costs, and 24/7 scheduling coordination. NS OATT and NS Market Rules govern obligations, with updates to Appendix 1 if needed.

Circumstances in which Variances from Scheduled Dispatch Will Be Tracked The variance from the scheduled dispatch results in: - A change in NS Power unit commitment(s) - A need for NS Power to rebalance a fuel position - The redispatching...

AI summary The document outlines scenarios where variances from scheduled dispatch occur, including changes in NS Power unit commitments, fuel rebalancing, redispatching from Wreck Cove, export/import value reductions, excess energy conditions, and forced dispatch of PHP outside standard operating schedules.

ble notification processes and penalties for non-compliance.[33](#page-12-3) NSP explains the value and difference of the PHP Interruptible Credit Rider compared to the Dispatchable Rider as follows: - Interruptible rider reduces the Compa...

AI summary NSP outlines the benefits of the ELID Interruptible Rider, emphasizing reduced firm peak demand, planning relief (avoided generation costs), and reliability during capacity shortfalls. It contrasts this with the Dispatchable Rider, noting mandatory compliance and penalties for non-compliance under the Interruptible Rider.

ge Bay and options to serve a new major customer (Canadian High Arctic Research Station). Worked on capital project planning manual development for QEC and organized a training session to QEC's staff. For Northwest Territories Power Corpor...

AI summary The text outlines work on capital project planning for QEC, development of a Low Water Response Plan for NTPC during a 2014 water crisis, and analysis of LNG-based power generation and transmission interconnection feasibility to meet energy demands in the North Slave system.

18 Q. Why is this volatility and unpredictability of PHP's load a concern? 78 NSPI (BW) IR-6 (a-b). 79 NSPI (BW) IR-6 (a-b). 80 PHP Evidence, page 10 lines 1 to 3. 81 PHP Evidence, page 10 line 3.

AI summary The volatility and unpredictability of PHP's load pose challenges for grid reliability and management. The question references evidence from NSPI and PHP, highlighting concerns related to load stability in regulatory proceedings.

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.

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 the day-ahead and real-time scheduling models. The weekly PHP load determines optimal 2 daily levels, which are shaped hourly according to system conditions and requirements. 3 4 (g) 5 (i) The divergence be...

AI summary The text discusses the scheduling and dispatch of PHP's load in 2025, highlighting that actual load diverged from forecasts but was managed economically. The CBL Energy Charge was based on a prior forecast and not revised, leading to variances in actual costs. Adjustments to PHP's energy requirements were influenced by system and market conditions rather than forecast error.

- NSP has estimated that the fully optimized credit could be up to $11 million per year, but is unable to - provide the calculation of this value.[18](#page 1-14) NSP estimates half of this may be reasonably achieved by PHP each - year, bu...

AI summary NSP proposes a Dispatchable Rider (DR) mechanism with PHP, estimating $11M annual savings but lacking detailed calculations. The DR's economic value requires NSP to have control over PHP's load during system stress. The recommendation emphasizes practical dispatch control for NSP during reserve margin periods, with concerns over 100% DR credit allocation to PHP.

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.

that is not yet completed, that would take the total capacity up to 168 MW. Until the second SIS is approved, PHP cannot assume that 168 MW of energy are available to the grid, thus the 130.5 MW level from the approved SIS is being used. A...

AI summary The document discusses the current capacity level at 130.5 MW based on an approved System Impact Study (SIS), with plans to increase to 168 MW once the second SIS is approved. The P90 level for wind generation at 168 MW is estimated at 528 GWh, significantly lower than the 653 GWh estimated by Bates White, indicating a less than 4% increase in expected generation.

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.

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.

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 NS Power is requesting approval for the ELID Tariff and has raised concerns about the premature discontinuation of priority interruptible service, citing its value in reducing interruption risks and supporting system reliability, despite its relatively low annual cost of approximately $500,000.

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.

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.

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.

t and confirm the cost variance anticipated for 2026 and 2027. 2. Please provide all supporting evidence to support the calculation in (a). Reference: N-1, ELID Application, Page 8 lines 19-26. With respect to the SA priority interruptible...

AI summary The Company is being asked to confirm the cost variance for 2026 and 2027 and provide supporting evidence. The Company acknowledges the value of priority interruptible service in reducing risk of interruption but notes its relatively low cost and considers it premature to discontinue the service.

mber of occasions when Advisories, Alerts, and LIIR Interruptions occurred in the past number of years. PHP would have been dispatched down to minimum load for these occasions. [emphasis added]

AI summary The text discusses the frequency of Advisories, Alerts, and LIIR Interruptions over the past several years and notes that PHP would have been dispatched to minimum load during these events.

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.

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.