Topic:"Electricity Generation" in M12661

FUNCTIONALIZATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (1) TOTAL (2) PROD. (3) TRANS. (4) DIST. EXPENSES EXPENSES EXPENSES EXPENSES EXPENSES EXPENSES (5) RETAIL (6) DIRECT (7) ALLOCATION FAC...

AI summary The document provides a detailed breakdown of operating expenses for the year ending December 31, 2027, categorized into production, transmission, distribution, retail, and direct expenses. It includes allocations and depreciation for various energy generation sources such as steam, hydro, wind, solar, and gas turbines.

(154) (143) (151) Distribution BP Substation - Municipal (152) Distribution Primary Voltage - LIR (153) Distribution Primary Voltage - Municipal (144) System Coincident 3CP DMD (145) EHV - LIR (146) HV - LIR (147) HV - Municipal (148) Dist...

AI summary The text presents a table with distribution and system-related data, including voltage levels, substation types, and associated monetary values. It includes terms such as 'Distribution BP Substation,' 'System Coincident 3CP DMD,' and 'EHV - LIR,' along with numerical values indicating financial figures.

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.

FOR THE YEAR ENDING DECEMBER 31, 2026 (1) (2) (3) (4) (5) (6) (7) (8) (9) (10) (11) TOTAL COMPANY DOMESTIC GENERAL GENERAL SMALL GENERAL LARGE SMALL MEDIUM LARGE INDUSTRIAL INDUSTRIAL INDUSTRIAL ELI 2P-RTP MUNICIPAL UNMETERED (1) NON-COIN....

AI summary The document presents a detailed breakdown of non-coincident kilowatt-second and kilowatt-primary data across various customer categories for the year ending December 31, 2026. It includes subtotals, losses, and percentages for different segments such as small, medium, large, and industrial customers, as well as specific programs like ELI 2P-RTP and municipal unmetered.

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 THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) TOTAL (2) TOTAL (3) UNIT COST (4) TOTAL (5) (6) (7) VARIANCE CALC (249) DISTRIBUTION - Easements (250) DISTRIBUTION - Other (251) DISTRIBUTION - Substations 3,065.1 1,358....

AI summary The document presents financial data related to distribution, generation, transmission, and other infrastructure costs for the year ending December 31, 2026, including totals, unit costs, and variances for various categories such as easements, poles, lines, meters, and streetlights.

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 (12) SHORE POWER (13) GEN.REPL./LOAD FOLL. (14) ELIADC (15)...

AI summary The table presents data for March 2027, including energy line items, system coincident demand, and export sales. It shows various categories such as Shore Power, GEN.REPL./LOAD FOLL., ELIADC, and others, with corresponding values and percentages. The data includes sub-totals and total figures for energy and demand lines.

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 breakdown with various expense categories and depreciation details for different energy generation and distribution assets, including steam, hydro, wind, solar, and transmission and distribution infrastructure.

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 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. It categorizes data by customer class and includes sub-totals and totals for various categories.

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.

FOR THE YEAR ENDING DECEMBER 31, 2027 (IN THOUSANDS OF DOLLARS) (1) TOTAL EXPENSES (2) PROD. EXPENSES (3) TRANS. EXPENSES (4) DIST. EXPENSES (5) RETAIL EXPENSES (6) DIRECT EXPENSES (7) ALLOCATION FACTOR (29) (31) (30) TOTAL DIVISIONAL EXPE...

AI summary The document outlines financial details for the year ending December 31, 2027, including various expense categories such as production, transmission, distribution, and retail expenses, along with depreciation and capital-related expenses for different energy generation and infrastructure components.

DEVELOPMENT OF ALLOCATION FACTORS (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION (35) TOT.RATE BASE-DMD. (HV) (36) % RESPONSIBILITY $0 100.00% $0 64.61% $0 3.42% $0 17.75% $0 2.03% $0 1...

AI summary The document presents a table detailing the allocation of responsibility percentages across various categories, including total rate base demand, distribution, and generation, with specific figures and percentages for different customer classes and allocation factors labeled as P-15A, P-15B, P-16, P-16B, and P-17.

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

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 This document presents a detailed analysis of Nova Scotia Power Inc.'s sales, generation, and demand for January 2027, including metrics such as energy sales, losses, demand factors, and system peak demand. The data is organized in a table with various subtotals and categories, including ELIADC and EBS/RTR.

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 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 metrics related to energy sales, losses, demand, and system factors for September 2027. It includes columns such as energy sales, energy losses, energy requirement, demand factors, and system peak demand. The table appears to be part of a regulatory proceeding related to energy billing and real-time pricing.

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.

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 COIN. PEAK DMD. (KW) (9) SYSTEM C...

AI summary The document presents a summary of energy sales, losses, and demand metrics for March 2026, including total MWH sales, energy line losses, energy requirement, and system demand factors.

(IN THOUSANDS OF DOLLARS) (254) DISTRIBUTION - UG Lines (255) DISTRIBUTION - Line Transformers (256) DISTRIBUTION - Services (257) DISTRIBUTION - Meters (258) DISTRIBUTION -Streetlights 2,952.6 28,381.7 4,147.1 8,124.2 4,584.6 0 0 0 0 0 0....

AI summary The document provides a table with financial data related to distribution and real-time pricing, including line transformers, meters, streetlights, and other distribution-related items. It also includes data related to OATT, EBS, and other programs, with figures in thousands of dollars.

ith the terms and conditions to be set out in the Dispatchable Rider Operating Procedures. Excess Energy: Generation which is in excess of the needs of the electric system and which cannot be stored. Force Majeure: Any event or circumstanc...

AI summary The document defines key terms related to energy management and dispatch procedures in Nova Scotia, including 'Excess Energy,' 'Force Majeure,' and 'Hour 1' and 'Hour 2' definitions. It also outlines the roles of NS Power and NSPSO in managing demand schedules and dispatchable hours.

NSPI Responses to Synapse Energy Economics, Inc. Information Requests 1 Request IR-7: 16 loss to the power system, worsening the capacity shortfall situation. 17 18 (d) For planning purposes, PHP firm load for each of the last 10 years has...

AI summary NSPI provides responses to Synapse Energy Economics, Inc. regarding information requests, including details about PHP load, the ELID Tariff, and the PHB Generation Facility's designation as a Network Resource. The responses highlight planning assumptions, load classifications, and interconnection designations.

FUNCTIONALIZATION OF AVERAGE RATE BASE COMPANY GENERATION TRANSMISSION DISTRIBUTION RETAIL CAPITAL PRODUCTION PLANT (1) (2) (3) STEAM $847,049 $847,048.6 $0 $0 $0 $0 (4) HYDRO 699,665 $699,665.5 0 0 0 0 (5) WIND 163,771 $163,770.9 0 0 0 0...

AI summary The document presents a detailed breakdown of capital assets across various categories such as generation, transmission, and distribution plants, including specific values for steam, hydro, wind, solar, and other energy sources. It also includes data on land, easements, substations, poles, lines, and other infrastructure components.

NOVA SCOTIA POWER INC. FUNCTIONALIZATION OF OPERATING EXPENSES FOR THE YEAR ENDING DECEMBER 31, 2026 (IN THOUSANDS OF DOLLARS) (1) REGULATORY AFFAIRS (2) Advocacy Expense 1 49 (3) Other Expenses 4 191 (4) Subtotal 5 240 (5) (6) FINANCE GRO...

AI summary The document outlines the functionalization of operating expenses for Nova Scotia Power Inc. for the year ending December 31, 2026, including various expense categories such as regulatory affairs, finance group, enterprise services, human resources, and depreciation across different energy generation and distribution assets.

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 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 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 data for the year ending December 31, 2027, focusing on energy metrics such as MWH, energy line losses, system demand, and contribution percentages. The table highlights voltage service-based analysis for EHV transmission service under the LIR category.

$3,627,090 $2,521,417 $2,850,490 $2,534,080 $2,191,956 $1,916,096 $2,250,818 $2,157,931 $3,711,916 $3,788,118 $33,418,031 Purchased Power Wind $ 13,164,243.69 $ 14,283,765.76 $ 16,273,457.62 $ 13,857,420.27 $ 12,582,203.02 $ 10,596,475.95...

AI summary The text presents a series of numerical figures related to power purchases, wind generation, and operational and maintenance costs, including data from the Electricity Resource Information System (ERIS) and the Non-Renewable Resource Information System (NRIS). These figures are likely part of a financial or operational report related to energy generation and procurement.

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.

1 Request IR-1: 4 Proceedings, 1. 2022-2023 FAM Audit Report Recommendation XV-1, on page 7: 5 6 (a) Please provide an example of the overlapping, incomparable dispatch results ("e.g., 7 unit starts and shutdowns which are in conflicting p...

AI summary Request IR-1 asks for details on conflicting dispatch results from different models, the scope of these conflicts, the precision of the PortOps model, load increments/decrements for cause codes, and whether PortOps can model hourly system output and handle emergency situations.

Request IR-3: 2 Reference: N-20, Bates White Evidence, p. 15, lines 5-8: NSPI applied a projected output for Goose Harbour that assumes a facility installed capacity of 130.5 MW, while the reported planned facility capacity is 168 MW … thu...

AI summary NSPI's projected output for the Goose Harbour facility assumes a 130.5 MW capacity, which is 29% lower than the reported planned capacity of 168 MW, as noted in the COSS.

Response IR-4: - (a) We do not believe the use of a P90 value has great significance in part because the assumed capacity factor of 44% is already fairly high, and consistent with historical performance of relatively new and large wind far...

AI summary The response discusses the insignificance of P90 capacity factor estimates for the Goose Harbour wind farm due to high assumed capacity factors, and explains how using P50 estimates would lower PHP net load, increasing ELID Energy Charge rates and shifting system fixed costs to FAM customers.

- 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.