N-92026-2027 GRA Appendix 12 A-C - Cost of Service Study Process - Redacted
25 passages
- 4 to be consultative in nature, undertaken through a comprehensive stakeholder process facilitated - 5 by an expert COS consultant. NS Power retained Elenchus Research Associates Inc. (Elenchus) as - 6 its expert consultant at the end of...
AI summary NS Power conducted a consultative process in 2024 with stakeholders to address the Cost of Service (COS) treatment, facilitated by Elenchus and mediated by Bruce Outhouse. The process included technical conferences, resolution sessions, and extensive data exchange, resulting in multiple appendices with models, DR responses, and other supporting documents.
18 5.12 Decarbonization Deferral Account (DDA) 19 20 As a result of federal and provincial legislation regarding decarbonization, NS Power is required 21 to phase out coal generation, which will include addressing associated marine unloadi...
AI summary NS Power seeks to recover costs from retiring coal generation assets via the Decarbonization Deferral Account (DDA), approved by the Board on May 21, 2024. The DDA serves as a rate stabilization tool, with NS Power proposing it be classified and allocated similarly to other such tools. This addresses transition costs from decommissioning coal facilities by 2030 under federal and provincial decarbonization mandates.
Cost of Service Study Redacted - 1 service to which it was classified. The current Board-approved DDA COSS treatment is the - 2 appropriate scenario to consider as part of this COSS proceeding, and it would be premature to - 3 speculate on...
AI summary The document argues that the current Board-approved DDA COSS treatment is the appropriate scenario for the proceeding, with future scope changes requiring regulatory approval. NS Power's written response, dated November 1, 2024, and referenced in Appendix 12A(5), supports this position.
CONFIDENTIAL 1 COSS Model Run #6, Transmission Subfunctionalized to EHV and HV: 2 The current COSS includes subfunctionalization between EHV and HV but both subfunctions use 3 the same allocators. The allocators applicable to the HV subfun...
AI summary The document outlines various COSS model runs that adjust how costs are allocated across different subfunctions and classifications. These include changes to transmission subfunctionalization, distribution cost allocation, service allocation based on meter costs and customer count, and reclassification of generation based on capacity factors.
2026-2027 GRA Direct Evidence Appendix 12A(1) Page 32 of 46 REDACTED (CONFIDENTIAL INFORMATION REMOVED) CONCENTRIC EVIDENCE: GRA COSS ELEMENTS - the system. The minimum system cost represents the customer-related costs, whereas the total c...
AI summary The text discusses two methods for allocating distribution costs: the Zero Intercept Study and the Minimum Size Selection. The Zero Intercept Study uses regression analysis to estimate customer-related costs, but it is criticized for potential statistical unreliability. The Minimum Size Selection method involves selecting the smallest currently installed assets for cost allocation. These methods are outlined in the NARUC Manual.
NON-CONFIDENTIAL 1 Request DR-50: 2 3 Please explain who owns the conductors between the shared primary system and the 4 customer meter, and explain how NS Power proposes to determine the utility-owned service- 5 drop costs for primary cus...
AI summary NS Power owns the conductors between the shared primary system and the customer meter. They propose deferring the determination of utility-owned service-drop costs for primary customers until empirical data on service drop utilization is collected, allowing for the development of new allocators.
Nova Scotia Power Open Access Transmission Update February 2022 1 OATT Schedule 9 provides the System Average Loss Factor for Network Integration Service, 2 which is applied to the net demand of the eligible customer. This factor is update...
AI summary The document outlines Nova Scotia Power's Open Access Transmission Update for February 2022, including the System Average Loss Factor for Network Integration Service and the development of transmission revenue requirement, which includes depreciation, interest, return on equity, taxes, operating costs, and fixed cost deferral.
Description of the MSS - Distribution system costs are incurred to move electricity from generation and transmission facilities - to individual customers that are distributed geographically throughout the service territory of a - utility....
AI summary The document describes the Methodology for System Studies (MSS) used to allocate distribution system costs between demand-related and customer-related components. It explains that distribution costs are influenced by both the number of customers and peak demand, and that the NARUC Manual outlines two methods for this allocation: the Minimum Size Method and the Minimum-Intercept Method. Concentric used the Minimum Size Method in its analysis.
COSS IG DR-10 Attachment 1 Page 4 of 6 Peaker Deferral Method (PDM) - Simplified Pro Forma Model
AI summary The document introduces the Peaker Deferral Method (PDM) as a simplified pro forma model, likely used for regulatory proceedings related to cost deferral or financial modeling.
NON-CONFIDENTIAL 1 Request DR-4: 2 3 How are the costs of primary vs secondary distribution classified, to demand or energy? 4 5 Response DR-4: 6 7 Please refer to page 3 of Exh 5 of 2023 COSS1 for the distribution cost classification resu...
AI summary The response to DR-4 explains that NS Power classifies distribution costs exclusively to demand, customer, or both, but not by primary vs. secondary voltage levels. Classification factors are based on investment in poles and wires, and specific percentages are provided for OM&G costs.
MEMORANDUM TO: Nova Scotia Power, Inc. FROM: Bickey Rimal, Concentric Energy Advisors DATE: January 2022 RE: GRA Allocated Cost of Service and Miscellaneous Charges Matters The purpose of this memorandum is to provide the results of: - Con...
AI summary This memorandum from Concentric Energy Advisors to Nova Scotia Power Inc. reviews the company's allocated class cost of service (CCOS) model, concluding that it is reasonable, follows industry-accepted methodology, and produces accurate results. The model uses a three-step process: cost functionalization, classification, and allocation, which are described in detail.
its treatment of overhead costs, taking into account the input of stakeholde[rs](#page-22-1). 7 Based on Concentric's review, the approach taken by the Company is reasonable and appropriate. The Company's proposed functionalization factors...
AI summary The document reviews the treatment of overhead costs in the 2013 COSS Proceeding, noting that Nova Scotia Power Inc.'s approach is reasonable and appropriate based on Concentric's review. The company's functionalization factors are based on cost causation and feedback from senior managers, with consensus achieved by most parties.
ct customers) to the total cost of the system. The minimum system cost represents the customer-related costs; whereas the total costs less the minimum system costs represents the demand-related costs. The total count of primary poles was m...
AI summary The text discusses the allocation of system costs between customer-related and demand-related components by analyzing the ratio of minimum system costs to total costs for various infrastructure elements, such as primary and secondary poles, and overhead and underground conductors. The methodology aligns with guidance from the NARUC Electric Utility Cost Allocation Manual.
COSS SBA DR-6 Attachment 1 Page 4 of 24 171050 LT DIT ASSET LIABILITY FAM 172050 LT DERIV ASSET HFT 172350 LT DERIV ASSET HFT TREASURY 173050 DEFERRED PENSION RETIREE BENEFIT 180050 LT REG ASSET UNAMORT DEFEASANCE COSTS 180450 LT REG ASSET...
AI summary The document presents a list of long-term assets and liabilities, including deferred pension benefits, regulatory deferrals, and various financial instruments, as part of a regulatory proceeding related to cost of capital and other studies.
Reference Documents - As baseline, NARUC, Electric Utility Cost Allocation Manual, January 1992. What has changed in the last 30 years? Comments invited. - Cost Allocation Modernization references, such as: - Electric Cost Allocation for a...
AI summary The document references historical and modern cost allocation practices, including the NARUC Electric Utility Cost Allocation Manual and recent stakeholder suggestions. It also cites previous Nova Scotia Power evidence, NSUARB decisions, and discussions from past COSS projects, including the Maritime Link Project and deferred projects from 2014–2016.
Discussion - Material changes in operating environment require reviews of costing methodology to ensure proper alignment with cost causation and asset utilization. - It is also important to be mindful of established ratemaking principles,...
AI summary The discussion highlights the need to review costing methodologies in response to changes in the operating environment, emphasizing the importance of aligning with cost causation and asset utilization. It also addresses the balance between ratemaking principles and the simplicity of the SLF method, while noting the complexity of alternative methods like LOLP and Probability Dispatch.
• Bundled Service Rates - priced in either c/kWh or both in c/kWh and $/kVa or $/kW - Reflective of test year costs subject to - revenue to cost ratio adjustments - Cost deferrals, caps and multi-year rate smoothing which might be solely a...
AI summary Bundled service rates are priced in c/kWh or both c/kWh and \/kVa or \/kW, reflecting test year costs with adjustments such as revenue to cost ratio, cost deferrals, caps, and multi-year rate smoothing that may apply specifically to bundled service rates.
3. Transmission Classified 100% as Demand - ➢ Purpose: Classify all Transmission as 100% demand instead of using the SLF as peak demands are the primary cost driver of Transmission costs. - ➢ Model Notes: The classification factors that sh...
AI summary This section discusses reclassifying all Transmission costs as 100% demand, removing classification factors that shift costs to energy. This change shifts cost responsibility from classes with high load factors to those with low load factors, with adjustments made to avoid cell definition errors in the model.
Municipal Tariff Rates - Revenue requirement reflects costs of three services areas of generation, transmission and retail - As above-the-line (ATL) & FAM rates they are subject to cost deferrals, rate capping and smoothing, their cost req...
AI summary The document discusses municipal tariff rates, which include revenue requirements covering generation, transmission, and retail services. These rates are subject to cost deferrals, rate capping, smoothing, and adjustments related to the R/C ratio and fuel costs. A two-part tariff structure, consisting of energy and demand charges, is applied for ratcheted non-coincident demands.
November 1, 2024 Memo to Participants in COSS Stakeholder Process Pros Cons Would be consistent with fuel conversion Does not align with the view that the DDA and emission reduction classification. is a rate stabilization tool and was esta...
AI summary The memo outlines a debate on the classification of the Decarbonization Deferral Account (DDA) and its alignment with rate stabilization tools. It also details the inclusion of regulatory amortization in corporate taxes and the apportionment of regulatory assets and expenses to rate classes based on their responsibilities for the rate base.
6.2.2.1 NSP CURRENT APPROACH - The minimum system methodology is used in the cost of service study for the - classification of poles & fixtures and overhead & underground lines between customer- - related and demand-related. The need to cl...
AI summary NSP uses the minimum system methodology in its cost of service study to classify distribution costs as either demand-related or customer-related, following guidelines from the NARUC Electric Utility Cost Allocation Manual.
6.2.2.3 ELENCHUS OPINION - The minimum system method is appropriate for classifying poles & fixtures and overhead - & underground lines between demand and customer. These costs have two clear cost - drivers: the sprawl of the distribution...
AI summary The minimum system method is deemed appropriate for classifying distribution costs related to poles, fixtures, and overhead and underground lines. It accounts for two cost drivers: the sprawl of the distribution system and peak demand. This method is used by multiple utilities and is considered the most common approach in Canada for classifying distribution costs.
2026-2027 GRA Direct Evidence Appendix 12B Page 41 of 55 REDACTED (CONFIDENTIAL INFORMATION REMOVED) -41- NSP COSS Consultation Report Draft April 25, 2025 - 1 load can create counterintuitive and controversial results that are detached fr...
AI summary The document discusses the limitations of the basic customer method for cost allocation, highlighting inconsistencies with cost causality. It compares this method to the minimum system and zero-intercept methods, noting that the latter two are used by some Canadian utilities but not universally. The zero-intercept method, while used by some, can produce counterintuitive results.
4 7.1.3 ELENCHUS OPINION - 5 Meter reading, call centre, and billing services costs are allocated by a weighted allocation - 6 factor that consider the costs of these sub-functions are largely driven by the number of - 7 customers but ther...
AI summary The text discusses the allocation of meter reading, call centre, and billing services costs using a weighted factor that considers both the number of customers and class revenues, with an 85%/15% weighting based on resource analysis.
2026-2027 GRA Direct Evidence Appendix 12B Page 46 of 55 REDACTED (CONFIDENTIAL INFORMATION REMOVED) -46- NSP COSS Consultation Report Draft April 25, 2025 - judgement. 1 [11](#page-103-2) Allocating these costs typically relies on judgeme...
AI summary The text discusses the allocation of costs related to customer experience, solutions, and meter data services, emphasizing the use of direct allocations and adjustments for seasonal customers. Elenchus supports these methods as reasonable.
N-142026-2027 GRA OP 01-15 - Redacted
15 passages
The Company has the following categories on the Condensed Consolidated Balance Sheets related to derivatives receiving regulatory deferral: As at June 30 December 31 millions of dollars 2025 2024 Derivative instrument assets (current and o...
AI summary The Company reports regulatory deferral-related derivative instruments and regulatory assets and liabilities on its Condensed Consolidated Balance Sheets, with figures for June 30, 2025, and December 31, 2024. The net asset from these items is reported as $1 million and $2 million respectively.
The Company recognized the following net (losses) gains in income related to derivatives receiving regulatory deferral: Three months ended Six months ended For the June 30 June 30 millions of dollars 2025 2024 2025 2024 Fuel for generation...
AI summary The Company reported net losses and gains in income related to derivatives receiving regulatory deferral, particularly in the 'Fuel for generation and purchased power' category, with figures for the three and six months ended June 30, 2025 and 2024.
As at June 30 December 31 millions of dollars 2025 2024 Regulatory assets Deferred income tax regulatory asset $ 974 $ 922 FAM (refer to table below) 35 - Deferrals related to derivative instruments 31 40 Hurricane Fiona 31 32 Cost of remo...
AI summary The table presents regulatory assets and liabilities for the periods ending June 30, 2025, and December 31, 2024, highlighting changes in deferred income tax, FAM, derivative instruments, and storm-related deferrals. Regulatory assets increased from $1,041 million to $1,107 million, while regulatory liabilities decreased from $100 million to $20 million.
Notional Volumes As at June 30, 2025, the Company had the following notional volumes of commodity swaps and forward and physical natural gas purchase contracts designated for regulatory deferral that are expected to settle as outlined belo...
AI summary The document outlines the notional volumes of commodity swaps and natural gas purchase contracts designated for regulatory deferral as of June 30, 2025, with details on their expected settlement.
millions 2025 2026-2027 Commodity swaps and forwards purchases: Natural gas (MMBtu) 6 11 Power (MWh) 2 5 As at June 30, 2025, the Company had the following notional volumes of foreign exchange forward contracts designated for regulatory de...
AI summary The document outlines the notional volumes of commodity swaps and forwards purchases for natural gas and power, as well as foreign exchange forward contracts designated for regulatory deferral, with expected settlement periods in 2025 and 2026-2027. It also mentions credit risk as a relevant consideration.
The Company has recorded the following changes with respect to derivatives receiving regulatory deferral: Commodity swaps and FX Commodity swaps and FX millions of dollars forwards forwards forwards forwards For the three months ended June...
AI summary The document outlines changes in derivative instruments related to regulatory deferral, including unrealized and realized gains and losses in regulatory assets and liabilities for the periods ending June 30, 2025 and 2024, both for three and six months.
As at June 30, 2025, the Company had the following notional volumes designated for regulatory deferral that are expected to settle as outlined below: millions 2025 2026-2027 Commodity swaps and forwards purchases: Natural gas (MMBtu) 6 11...
AI summary As of June 30, 2025, the Company has designated notional volumes for regulatory deferral, including natural gas and power swaps, as well as FX forwards. These volumes are expected to settle over the next few years, with a weighted average rate and percentage of USD requirements provided.
Detailed rate base forecasts to follow the 2024 annual capital refresh 1 Average rate base; 2 USD/CAD exchange rate for 2022 updated to reflect forecasted rate; 3 Capital structures that support the rate base include deferred tax liabiliti...
AI summary The text discusses detailed rate base forecasts following the 2024 annual capital refresh, including capital structures, deferred tax liabilities, and equity investments. It highlights the exclusion of fuel and storm cost deferrals and mentions updated exchange rates and capital asset values.
4 Includes net investment in capital leases; 2 Excludes fuel and storm cost deferrals included in rate base; 3 Reflects the capital asset values of the regulated pipeline investments;
AI summary The text includes notes on net investment in capital leases, excludes fuel and storm cost deferrals from rate base, and reflects the capital asset values of regulated pipeline investments.
7% Increase in 2024 Operating Cash Flow 2 2024 Fuel & Storm Cost Deferrals (Net over-recovery) Note: Millions of Canadian dollars (except per share amounts), 1 Adjusted EPS is a non-GAAP ratio 2 Operating cash flow before changes in workin...
AI summary The text discusses a 7% increase in 2024 operating cash flow, excluding fuel and storm cost deferrals, and includes figures related to net over-recoveries and under-recoveries at Tampa Electric and Nova Scotia Power. Notes provide additional context on financial metrics and adjustments.
1 Capital structures that support the rate base include deferred tax liabilities (DTL), a zero cost-of-capital component of the capital structure in Florida; 2023 capital structures included DTLs of approx. US$1,300 million at Tampa Electr...
AI summary The text discusses capital structures supporting the rate base, including deferred tax liabilities (DTL) at Tampa Electric and Peoples Gas, and excludes fuel and storm cost deferrals. It also mentions the inclusion of net investment in capital leases and the updated USD/CAD exchange rate for 2024.
1 Capital structures that support the rate base include deferred tax liabilities (DTL), a zero cost-of-capital component of the capital structure in Florida; 2023 capital structures included DTLs of approx. US$1,300 million at Tampa Electr...
AI summary The text discusses capital structures supporting the rate base, including deferred tax liabilities (DTL) at Tampa Electric and Peoples Gas, and notes exclusions such as fuel and storm cost deferrals. It also references exchange rates and investment values in regulated pipeline assets.
FAM Securitization Sold $117M of deferred costs to the Provincial Government in Q2 2024 and used the proceeds to reduce consolidated debt Securitized a further $500M of deferred fuel costs via a second federal loan guarantee and used the p...
AI summary The document outlines the securitization of deferred costs, including the sale of $117M in Q2 2024 and an additional $500M of deferred fuel costs through a federal loan guarantee, both used to reduce consolidated debt.
1 Capital structures that support the rate base include zero cost-of-capital components in Florida. 2024 capital structures included DTLs and other items of approx. US$1,600 million at Tampa Electric and approx. US$300 million at Peoples G...
AI summary The text discusses capital structures supporting the rate base in Florida, including details on deferred costs and exchange rates for 2024. It mentions specific figures for Tampa Electric and Peoples Gas, as well as net investment in capital leases and exchange rate updates.
2. Excludes fuel and storm cost deferrals included in rate base; 3. Reflects the capital asset values of the regulated pipeline investments; 4. Includes net investment in capital leases; 5. USD/CAD exchange rate for 2024 updated to reflect...
AI summary The text provides notes on exclusions and inclusions in rate base calculations, including fuel and storm cost deferrals, capital asset values of regulated pipeline investments, net investment in capital leases, and an updated USD/CAD exchange rate for 2024.
N-27NSPI (NSEB) RIR 1-152 - Redacted (settlement agreement attached at IR-1)
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Appendix "A" GRA Element Settlement Terms brought forward for approval by the Board later this year to be effective January 1, 2026. For clarity, any payment approved by the Board for Active Demand Control services will be collected from a...
AI summary The document outlines settlement terms related to the approval of Active Demand Control services and tariff processes by the Board, effective January 1, 2026. NS Power and PHP are required to reflect these terms in a written tariff, and NS Power may seek approval for a deferral account to address potential revenue variances in 2026 or 2027.
Regulatory Assets and Regulatory Liabilities Regulatory assets represent prudently incurred costs that have been deferred because it is probable that they will be recovered through future rates collected from customers. Management believes...
AI summary The text discusses regulatory assets and liabilities, explaining that regulatory assets are deferred costs expected to be recovered through future rates, while regulatory liabilities are obligations to refund customers or reduce future revenues. Management's judgment on the probability of recovery or settlement determines their recognition in income.
Hurricane Fiona: On June 27, 2024, the UARB approved the deferred recognition of $25 million in incremental operating costs incurred during the Hurricane Fiona storm restoration efforts in September 2022. Following the UARB approval, the $...
AI summary The UARB approved the deferred recognition of $25 million in incremental operating costs from Hurricane Fiona's restoration efforts and directed the reclassification of $10 million in undepreciated costs to 'Regulatory assets'. Both amounts will be amortized over 10 years starting July 1, 2024.
Notional Volumes As at December 31, 2024, the Company had the following notional volumes of commodity swaps and forward and physical natural gas purchase contracts designated for regulatory deferral that are expected to settle as outlined...
AI summary The document outlines notional volumes of commodity swaps and natural gas purchase contracts designated for regulatory deferral as of December 31, 2024, expected to settle according to specified timelines.
2025 2026-2027 millions Purchases Purchases Commodity swaps and forwards: Natural gas (MMBtu) 12 12 Power (MWh) 1 - Coal (Metric Tonnes) 1 - Physical natural gas purchases: Natural gas (MMBtu) 6 - As at December 31, 2024, the Company had t...
AI summary The document outlines the Company's commodity purchases and foreign exchange contracts for 2025 and 2026-2027. It includes natural gas, power, and coal purchases, as well as foreign exchange forward contracts designated for regulatory deferral. NSPI plans to adjust these hedges periodically based on forecast requirements.
Hurricane Fiona: On June 27, 2024, the UARB approved the deferred recognition of $25 million in incremental operating costs incurred during the Hurricane Fiona storm restoration efforts in September 2022. Following the UARB approval, the $...
AI summary The UARB approved the deferred recognition of $25 million in incremental operating costs from Hurricane Fiona's storm restoration efforts, reclassifying it to 'Regulatory assets'. Additionally, $10 million of undepreciated costs from retired assets were also reclassified and will be amortized over 10 years starting July 1, 2024.
The Company has the following categories on the Consolidated Balance Sheets related to derivatives receiving regulatory deferral: As at December 31 December 31 millions of dollars 2024 2023 Derivative instrument assets (current and other a...
AI summary The Company's Consolidated Balance Sheets show changes in derivative instrument and regulatory assets and liabilities as of December 31, 2024, and December 31, 2023. The net asset (liability) is reported as $2 million and -$0 million, respectively. The regulatory impact recognized in net income is also highlighted.
The Company recognized the following net (losses) gains in income related to derivatives receiving regulatory deferral: For the Year ended millions of dollars December 31 2024 2023 Fuel for generation and purchased power (1) $ (36) $ 70 (1...
AI summary The Company reported net losses and gains related to derivatives with regulatory deferral, specifically in the 'Fuel for generation and purchased power' category, with a loss of $36 million in 2024 compared to a gain of $70 million in 2023. These gains and losses are tied to settled hedging relationships.
2 All GRA and Cost of Service Study costs are external and incremental costs. NS Power 3 does not track internal GRA costs. Please note that $0.8M of GRA expense was incurred 4 in 2021 but was expensed in 2022 as NS Power had initially pro...
AI summary The text discusses the external and incremental costs associated with GRA and Cost of Service Study, noting that NS Power expensed some GRA costs in 2022 after initially proposing to defer and amortize them. It also mentions that costs for the 2026-2027 GRA are not included in current OM&G expense figures.
12 Response IR-55: 13 14 (a) NS Power is not of the opinion that the approved deferred recovery of Post Tropical Storm 15 Fiona costs makes it inappropriate to include these costs when illustrating a complete 16 picture of storm costs for...
AI summary NS Power argues that including Post Tropical Storm Fiona costs in the illustration of storm costs for 2020-2024 is appropriate, as the figure was intended to show the calculation of proposed storm Level 3 and 4 OM&G expenses using prior period OM&G expenses as a starting point, and Fiona costs were not included in those prior expenses.
REDACTED 2 3 Reference: Exhibit N-6(ii), Corporate Office of Secretary and General Counsel 4 With respect to the reasons given for the following significant projected increases for 2026 5 over 2024 actuals: 6 7 (a) Consulting and Ext Legal...
AI summary The document requests explanations for significant projected increases in consulting, legal, and insurance costs for 2026 compared to 2024, including details on the CRA litigation appeal, its delays, costs incurred, and potential future expenses.
NON-CONFIDENTIAL 1 Request IR-62: 1 Request IR-63: 2 3 Reference: Exhibit N-6(ii), Regulatory Affairs 4 5 The consulting expense forecast for 2026 is 57% higher than 2024 compliance and slightly 6 below 2024 actuals. Board staff assumes th...
AI summary The consulting expense forecast for 2026 is 57% higher than 2024 compliance and slightly below 2024 actuals. The majority of incremental cost associated with the 2026-2027 GRA is expected to be incurred in 2025, not reflected in the Regulatory Affairs operating expense as it is being deferred and amortized over the test period.
Request IR-79: Reference: Exhibit N-3 GRA Direct Evidence, 8.6 Regulatory Amortizations - Please provide a breakdown of the unreduced accrued and forecast GRA and COSS Deferral - costs included in Figure 8-3 of the application. Response IR...
AI summary The response to Request IR-79 provides a breakdown of unreduced accrued and forecast GRA and COSS Deferral costs included in Figure 8-3 of the application, as referenced in Exhibit N-3 GRA Direct Evidence, 8.6 Regulatory Amortizations.
1 Request IR-80: 2 3 Reference: Exhibit N-12, FO-13. 4 - 5 Please provide a breakdown of the "Deferred Charges – Other General" in FO-13 in the - 6 same format as in FO-13, but including 2024 compliance and actual amounts, as shown in - 7...
AI summary A request is made for a breakdown of 'Deferred Charges – Other General' in FO-13, including 2024 compliance and actual amounts in the same format as FO-13 and RB-2-16. A response is provided in the form of a table.
2026-2027 GRA NSEB IR-85 Confidential Attachment 1 has been removed due to confidentiality. 1 Request IR-86: 8 securitization will be in place for these assets by January 1, 2026, and requests that its 9 recovery of depreciation and its re...
AI summary Nova Scotia Power is requesting the Board to defer the recovery of depreciation and return on assets if securitization is delayed beyond January 1, 2026. The request includes inquiries about the timing of securitization, outstanding issues, estimated deferral costs, and the rationale for splitting the securitization into two debt issuances.
9 Rate Base ($ million) 2023 Part VI.1 Tax Adjustment (M12248) 2023 Corrected Net Utility Fixed Assets 4,719.9 4,719.9 Deferred Charges & Credits 404.9 404.9 Long term receivable 82.2 82.2 Allowance for materials and supplies 345.2 345.2 A...
AI summary The text presents a table showing the rate base and related adjustments for 2023 and 2024, including corrections and changes in various line items such as Net Utility Fixed Assets, Deferred Charges & Credits, and Allowance for Working Capital. The Part VI.1 Adjustment (M12248) is referenced as a matter number.
NON-CONFIDENTIAL Category ($ Million) 2023 2024 2025 2026 2027 17 (d) See NS Power's response to NSEB IR-47(b). 18 19 (e) See NS Power's response to NSEB IR-47(b). 20 21 (f) NS Power's forecast was based on a point in time. The IESO-NS com...
AI summary The document outlines NS Power's responses to the NSEB regarding various financial and operational forecasts, including deferrals, cost reductions, and potential tax expenses. It references the IESO-NS, GRA, and other regulatory processes, highlighting uncertainties and future considerations.
1 2027 COSS Change on Total Allocated Costs in $ Million Revenue to Expense Ratio 2 development of the PHP ATL Tariff to be filed with the Board by the end of 2025. 3 4 The Company has proposed a deferral mechanism "PHP Deferral" for, amon...
AI summary The document discusses the development of the PHP ATL Tariff to be filed with the Board by the end of 2025 and the proposed 'PHP Deferral' mechanism for revenue variances between the assumed and approved tariffs. The request asks for clarification on the assumptions and how revenue variances would be isolated.
N-44STATE OF CONNECTICUT
PUBLIC UTILITIES REGULATORY AUTHORITY
34 passages
Proposed ($) Adjustments ($) Approved ($) Prior Approved (2022) 2,273,831,000 2,273,831,000 Adjustments Test Year Beginning Balance Correction - (265,839) (265,839) Net Metering 2,226,469 (2,226,469) - Municipal Dashboard 900,222 (900,222)...
AI summary The table outlines proposed, adjustment, and approved figures for Test Year Plant-in-Service Adjustments, including items like Net Metering, Municipal Dashboard, and All Other Proposed Plant Additions, with specific dollar amounts and adjustments made.
Late Filed Ex. 1, Att. 2 Supp., Sch. B-4.0 WP (modified for PURA adjustments). [28](#page-32-2) It is a customary regulatory practice to include a CWC allowance – an adjustment to rate base in recognition of the timing difference between w...
AI summary The document discusses issues with the utility's (UI) proposed cash working capital (CWC) allowance, highlighting inconsistencies with prior approvals, the inclusion of non-cash items, and the use of an unsupported payment lag, which have inflated the CWC request.
Expense Category PURA Expense Adjustment ($) CWC Adjustment Factor CWC Adjustment ($) Compensation (301,500) 0.1113 (33,557) Employee Benefits (227,626) 0.1468 (33,415) Income Tax (4,917,242) 0.0640 (314,703) Other O&M (14,971,618) 0.0261...
AI summary Table 10 presents the impact of expense adjustments on the Cost of Service Working Capital (CWC) for various expense categories, including compensation, employee benefits, income tax, and others. The table shows both the PURA expense adjustment and the corresponding CWC adjustment in dollars.
1. Summary The Company proposes regulatory liabilities with a total rate year average of $92,304,872 (($103,985,756 + $80,623,985) / 2) to reduce the Company's rate base. Late Filed Ex. 1, Att. 2 Supp.; Sch. B-1.0; Sch. B-8.0; Sch. WP C-3....
AI summary The Company proposes regulatory liabilities of $92,304,872 to reduce its rate base, but the Authority approves a lower amount of $29,918,723, treating certain costs as O&M expenses and amortizing them outside the rate base, including storm reserve, OPEB deferral, pension liabilities, and fee-free program deferral. The Authority also considers the $14,700,000 bad debt reserve as an offset to the rate base.
1. Summary The Company proposed a total rate base balance of $36,575,480 related to deferred expenses and credits. The Authority will exclude $36,575,480 of the Company's deferred expenses from rate base, as summarized in [Table 18, below....
AI summary The Company proposed a rate base balance of $36,575,480 for deferred expenses and credits. However, the Authority will exclude this amount from the rate base and instead allow recovery of $28,942,312 as amortized O&M expenses.
Table 18: Summary of Approved Deferred Expenses (Credits) Proposed Balance Approved Balance as of Nov. 1, 2025 Adjustment as of Nov. 1, 2025 Deferred Expense (Credit) ($) ($) ($) Pension deferral 6,767,774 (6,767,774) - OPEB deferral (284,...
AI summary Table 18 outlines the summary of approved deferred expenses (credits) as of November 1, 2025, showing various deferrals and adjustments, including pension, OPEB, storm, and regulatory proceeding costs, among others, with a total adjustment of $36,575,480.
ppears to have derived its $1,892,932 by applying the distribution allocator to the $2,814,514 projected Rate Year expenses reflected in an earlier filing in the proceeding. Interrog. Resp. RRU-377. benefits could be realized through succe...
AI summary The Authority has determined that the deferral mechanism for the Fee Free Program is no longer necessary, as the program has been in place for over a year and a half, providing enough historical data to set a known and measurable adjustment for the program in the Rate Year.
As explained in the preceding sections and summarized in the table below, the Authority approves $6,188,125 of storm expenses. Proposed Rate Year ($) Adjustment ($) Approved ($) Schedule C-3.07 Discrepancy 43,591 (43,591) - Minor Storm 2,9...
AI summary The Authority has approved $6,188,125 of storm expenses, as detailed in a table summarizing proposed amounts, adjustments, and approved figures for various storm-related categories.
l, installation of an engineered control, and site restoration, in addition to support activities that include permitting, contractor oversight, and preparation of a final report. Ex. UI-ERP-1, p. 11. The Authority previously permitted the...
AI summary The Company is seeking recovery of $3,744,144 for East Shore Project expenses not deferred, citing expected remedial work and a competitive RFP process. The Authority previously allowed deferred accounting for these expenses, subject to prudency review.
Table 56: Approved Annual Amortization Expense (Deferral and Interim Period) Approved Balance, Nov. 1, 2025 ($) Allowed Carrying Costs ($) Total Deferred Amounts Amortized ($) Proposed Annual Amortization ($) Adjustment ($) Allowed Annual...
AI summary Table 56 presents the approved annual amortization expense for various items, including pension, OPEB, storm-related costs, and others, with details on balance, carrying costs, amortized amounts, and adjustments. It outlines the financial implications of deferral and interim periods.
b. Pension The Authority permits the Company to recover a total of $9,502,832 in pension deferral expenses over a three-year period for a Rate Year amortization expense of $3,167,611. The Company reported a pension deferral balance of $13,...
AI summary The Authority permits the Company to recover $9,502,832 in pension deferral expenses over three years, including $3,167,611 in amortization for the Rate Year. The Company's pension deferral balance increased to $13,053,936 as of August 2023, but the Authority did not approve carrying charges on the new $1,827,178 incremental pension costs. However, carrying charges will be permitted on this amount going forward as a regulatory asset.
c. OPEB The Authority approves an OPEB credit of ($1,175,847), which is to be amortized over a three-year period, resulting in a Rate Year credit of ($391,949). The Company reported a $1,576,130 deferred OPEB liability accrued as of August...
AI summary The Authority approves an OPEB credit of $1,175,847 to be amortized over three years, resulting in a Rate Year credit of $391,949. This follows the Company's reported deferred OPEB liability of $1,263,859 as of October 31, 2025, and adjustments made to remove $200,322 in net carrying credits.
d. Storm Deferral (Continuing Amortization Approved in 22-08-08 Decision) The Authority concludes that the Company correctly calculated the balance and associated carrying charges associated with the amortized storm expenses approved in th...
AI summary The Authority confirms the correct calculation of the remaining storm balance and associated carrying charges from the Company's last rate case. It combines this balance with a new storm deferral and amortizes the total over three years for efficiency.
f. New Storm Deferral In its Application, the Company is requesting two new storm deferrals. Late Filed Ex. 1, Att. 2, WP C-3.21, p. 1, lns. 14 and 21. The first storm deferral is a refund of $2,073,000 to be amortized over 12 months. Late...
AI summary The Company is requesting two new storm deferrals: a $2,073,000 refund amortized over 12 months covering multiple storms, and a $5,511,000 balance amortized over 36 months related to a 'Thunderstorms' event. The deferrals are based on the major storm threshold, determined using the Handy-Whitman Index, and are intended to mitigate financial impacts from unpredictable storm costs.
i. Summary of Allowed New Storm Deferrals The new storm deferral allowed for recovery as a deferred expense is the sum of the Storm Deferral Refund and the Thunderstorm Deferral. [Table 57](#page-173-0) shows the allowable balance for reco...
AI summary The new storm deferral allowed for recovery as a deferred expense includes the Storm Deferral Refund and the Thunderstorm Deferral, with a total allowable balance for recovery of $48,843 as shown in Table 57.
Table 57: Total New Storm Deferral Balance, October 31, 2025 Requested ($) Adjustment ($) Allowed ($) Tropical Storm Elsa Expense (7,896) - (7,896) Hurricane Henri Expense 97,782 (10,592) 87,190 Storm Izzy Expense 76,010 (38,427) 37,583 Bl...
AI summary The table outlines the Total New Storm Deferral Balance as of October 31, 2025, listing expenses related to various storm events, including Tropical Storm Elsa, Hurricane Henri, and Hurricane Lee, along with adjustments and amounts allowed. It also includes deferred expenses and carrying charges, resulting in a total storm deferral refund of $48,843.
(a) Tropical Storm Elsa Deferred Expenses The Company reports a refund of $7,896 for Tropical Storm Elsa as an accounting accrual for contractors and materials. Interrog. Resp. EOE-249 Supp. 2, Att. 2, p. 3. The Authority approves the refu...
AI summary The Company reports a $7,896 refund for Tropical Storm Elsa as an accounting accrual for contractors and materials. The Authority approves this refund.
(c) Storm Izzy Deferred Expenses As for Storm Izzy, which occurred on January 17, 2022, the Company submitted expenses related to overtime, materials, and accounting accruals totaling $76,010. Interrog. Resp. EOE-249 Supp. 2, Att. 2, p. 3...
AI summary The Company submitted expenses related to Storm Izzy, including overtime, materials, and shared service costs. The Authority disallowed a portion of these expenses, citing lack of documentation, overlap with previously approved costs, and the need for incremental justification. A small portion of shared service costs was allowed based on an invoice from Securitas.
Proposed ($) Adjustment ($) Approved ($) Overtime 4,739 (4,739) - Fleet Fuel (30,356) - (30,356) Contractors and Affiliates 12,451 (9,135) 3,316 Materials 89,176 (24,553) 64,623 Total 76,010 (38,427) 37,583 Table 58: Storm Izzy Deferred Ex...
AI summary Table 58 outlines deferred expenses and adjustments related to Storm Izzy, including overtime, fleet fuel, contractors and affiliates, and materials, with proposed, adjustment, and approved figures for each category.
119. The Company instituted the Contractor Daily Time and Work Report requirements in 2022 and confirmed that it requires contractors to provide the UI Contractor Daily Time & Work Report prior to the processing of invoices. Interrog. Resp...
AI summary The Company requires contractors to submit daily time and work reports before processing invoices. However, a vendor, Tempest Energy, LLC, did not provide the required report, leading to the disallowance of $10,512 in expenses. Another vendor, ASPLUNDH Tree Expert LLC, was found to have incorrectly billed overtime hours, resulting in a disallowance of $4,274 and an adjusted total of $73,710.
(e) Blizzard Event Deferred Expenses The Company is also requesting $14,656 in storm expenses relating to a Blizzard Storm on January 29, 2022. Interrog. Resp. EOE-249 Supp. 2, Att. 2, p. 3. The expenses for this storm were for overtime an...
AI summary The Company is requesting $14,656 in storm expenses related to a Blizzard Storm on January 29, 2022, for overtime and external vendors. The Authority authorizes this amount.
(f) Hurricane Lee Lean-In Event Deferred Expenses The Company requests $1,082,185 in storm expenses for the Hurricane Lee – Lean-In event. Interrog. Resp. EOE-249 Supp. 2, Att. 2, p. 3 ("Incremental Costs" column"). The Company reports exp...
AI summary The Company requested $1,082,185 in storm expenses related to Hurricane Lee – Lean-In, but the Authority disallowed $11,531 in overtime costs and 25% of fleet fuel costs due to errors and unreasonable expenses. The revised allowed amount is $1,070,162.
Table 60: Hurricane Lee Lean-In Event Deferred Expenses Proposed ($) Adjustments ($) Approved ($) Overtime 125,482 (9,531) 115,951 Fleet Fuel 9,968 (2,492) 7,476 Contractors 928,275 - 928,275 Meals, Travel, and Lodging 18,460 - 18,460 Tota...
AI summary Table 60 outlines deferred expenses related to the Hurricane Lee Lean-In Event, including overtime, fleet fuel, contractors, and travel expenses, with adjustments made to the proposed amounts. The total approved amount is $1,070,162 after adjustments.
Table 61: Storm Deferral Refund Expenses Proposed ($) Adjustment ($) Approved ($) Tropical Storm Elsa (7,896) - (7,896) Hurricane Henri 97,782 (10,592) 87,190 Storm Izzy 76,010 (38,427) 37,583 Blizzard 14,656 - 14,656 Flooding Event 1,292,...
AI summary Table 61 outlines the proposed, adjustment, and approved amounts for various storm deferral refund expenses, including Tropical Storm Elsa, Hurricane Henri, Storm Izzy, Blizzard, Flooding Event, and Hurricane Lee, with a total adjustment of $135,172. The section also mentions a carrying charge adjustment related to storm deferral refunds.
In calculating the Storm Deferral Refund balance, the Company included carrying charges on the monthly net balance of storm deferral expenses, storm accrual, and mutual aid reimbursements. Interrog. Resp. EOE-249 Supp. 2, Att. 2, p. 2. The...
AI summary The Company calculated the Storm Deferral Refund balance by including carrying charges on monthly net balances of storm deferral expenses, storm accruals, and mutual aid reimbursements. The Authority found this approach improper, as carrying costs on deferred expenses require explicit prior approval.
torm reserve accrual. See Ex. UI-RRP-22C, p. 2. The Authority previously determined that carrying costs on deferred expenses are not permissible without explicit prior Authority approval, and allowing carrying charges to accrue on deferred...
AI summary The Authority disallows a credit of $80,343 of carrying charges calculated by the Company, as it was based on deferred expenses and the reserve accrual. The Authority recalculates the Storm Deferral Refund balance to include carrying charges on the storm reserve but excludes them on deferred expenses and mutual aid reimbursements. The resulting carrying charge balance is a credit of $374,911.
ately from the storm cost balance. The resulting carrying charge balance as calculated on a monthly basis on the reserve accrual balance from August 2022 through October 2025 is a credit of $374,911. When calculating the storm accrual bala...
AI summary The document discusses the calculation of a storm accrual balance, including carrying charges, which resulted in a credit of $4,708,244 as of October 31, 2025. This balance includes monthly storm accruals recorded through October 2025, with the Company ceasing such recordings from December 2024.
When calculating the deferred storm expense balance, the Authority removes the application of carrying charges improperly recorded by UI and also includes the reduction to the deferred expenses of $735,003 outlined in the previous section....
AI summary The Authority adjusts the deferred storm expense balance by removing improperly recorded carrying charges and applying a reduction of $735,003, resulting in a credit balance of $538,457 as of October 31, 2025.
(i) Storm Deferral Refund Final Balance The total approved Storm Refund Deferral balance as of October 31, 2025, is the sum of the storm accrual balance credit minus the deferred expenses balance, which equals a credit of $4,169,787 ($4,70...
AI summary The total approved Storm Refund Deferral balance as of October 31, 2025, is calculated as the storm accrual balance credit minus the deferred expenses balance, resulting in a credit of $4,169,787.
iii. Thunderstorms Deferral For the Thunderstorms Deferral, the Company reports a balance of $5,510,724 to be amortized over 36 months. Late Filed Ex. 1, Att. 2, WP C-3.21, p. 1. The Company is reporting one storm (Thunderstorm) totaling $...
AI summary The Thunderstorms Deferral involves $5,510,724 in storm-related expenses to be amortized over 36 months, including $5,158,351 in storm costs and $114,000 in carrying costs. The Authority disallows carrying costs prior to October 31, 2025, citing ratemaking principles. Expenses include overtime, materials, and vendor costs, with some vendors found to have incurred imprudent costs.
g. Environmental Deferral The Company proposes to amortize $481,664 in environmental remediation expenses related to its East Shore site over a 12-month period. Late Filed Ex. 1, Att. 2 Supp., Sch. WP C-3.21, p. 1. The Authority permits th...
AI summary The Company seeks to amortize $481,664 in environmental remediation expenses over 12 months, but the Authority allows recovery of $430,235 over three years, excluding $51,429 in carrying charges. This follows a prior decision that deferred remediation expenses cannot include carrying charges.
h. Fee Free Program The Company proposes to amortize a ($1,852,863) credit related to the difference between its actual credit card transaction fee costs and the amount embedded in distribution rates for such costs as ordered in the 22-08-...
AI summary The Company seeks to amortize a $1,852,863 credit related to credit card transaction fees, as ordered in the 22-08-08 Decision. The Authority adjusted this credit by $308,376 and added a carrying credit of $228,227, resulting in a $2,389,466 deferred credit to be amortized over three years, representing a $796,489 Rate Year credit.
Table 75: Calculation of Interest Synchronization Adjustment Proposed Average Rate Base (A) 1,384,647,638 Adjustment to the Proposed Weighted Cost of LTD (B) 0.0500% Increased to the Allowed Interest Expense (C) 692,324 Adjustment to the P...
AI summary The Authority applies a $3,297 interest synchronization adjustment to align the allowed rate base and weighted cost of long-term debt in the calculation of allowed state and federal income taxes.
4. Pleasure Beach Island The Company serves two customers located on Pleasure Beach Island (PBI) the WICC radio station and a pavilion owned by the City of Bridgeport. Ex. UI-RRP-1, p. 134. In its application, the Company states that it in...
AI summary The Company serves two customers on Pleasure Beach Island with a solar-plus-Battery Energy Storage System (BESS) microgrid project, but clarified it will not be used before the end of the Rate Year. The Authority previously approved the project as a cost-effective solution and authorized deferred accounting to track its costs, which will be reviewed for prudence and reasonableness in the next rate case proceeding.
N-67Response to Undertaking U-4 - Combined Redacted Only
7 passages
(16) Charges/Credits: (17) CASH - FUEL (18) CASH - OTHER (19) MAT. & SUPPLIES - FUEL (20) MAT. & SUPPLIES - OTHER (21) DEF. CHG Financing (22) DEF. CHG Tax (23) DEF. CHG Pension (24) DEF. CHG Steam Assets (25) DEF. CHG Fuel Deferral (26) D...
AI summary The text presents a table of charges and credits, including categories such as fuel, materials and supplies, and deferred charges and credits related to financing, tax, pension, and asset retirement obligations. The table includes numerical data across multiple rows and columns, reflecting financial transactions and balances.
EXHIBIT 3 PAGE 2 OF 5 (1) TOTAL (2) (3) SMALL (4) (5) GENERAL (6) SMALL (7) MEDIUM (8) LARGE (9) (10) (11) (12) ALLOCATION (46) MAT. & SUPPLIES - FUEL 0 0 0 0 0 0 0 0 0 0 0 P-9 (47) MAT. & SUPPLIES - OTHER 15,503 10,603 584 3,063 184 340 3...
AI summary The table presents financial data related to materials and supplies, deferred charges, and asset retirement obligations, with allocations across different categories and sizes. It includes figures for fuel, other materials, and various deferred charges, along with associated allocations and references to different matters.
EXHIBIT 3 PAGE 3 OF 5 (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) INDUSTRIAL LARGE (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATION FACTOR (25) DEF. CHG...
AI summary The table presents various deferred charges and credits across different customer categories, including domestic, small general, general, large, industrial, and municipal, with allocation factors provided for each. The data includes entries such as Fuel Deferral, Other Deferral, and Asset Retirement Obligation (ARO) credits for different energy sources.
EXHIBIT 3 PAGE 5 OF 5 (1) TOTAL COMPANY (2) DOMESTIC (3) SMALL GENERAL (4) GENERAL (5) GENERAL LARGE (6) SMALL INDUSTRIAL (7) MEDIUM INDUSTRIAL (8) INDUSTRIAL LARGE (9) PHP (10) MUNICIPAL (11) UNMETERED (12) ALLOCATION FACTOR (32) MAT. & S...
AI summary The text presents a table with various cost categories and their distribution across different customer classes and allocation factors. The table includes items such as 'MAT. & SUPPLIES - OTHER' and 'DEF. CHG Financing,' with associated values and allocation factors.
FOR THE YEAR ENDING DECEMBER 31, 2026 (1) TOTAL (2) PROD. (3) TRANS. (4) DIST. (5) RETAIL (6) DIRECT (7) (24) CORP. SECRETARY (25) LEGAL SERVICES 0 1,882 11,405 3,161 11,405.2 5,043.0 - 0.373 8,005 3,744 1,753 368 1,062 853 585 78 11,405.2...
AI summary The document presents a detailed breakdown of various departments and their associated costs for the year ending December 31, 2026. It includes figures related to corporate secretary, legal services, external relations, regulatory affairs, finance, procurement, IT, human resources, and generation services.
(IN THOUSANDS OF DOLLARS) (1) (2) (3) (4) (5) (6) (7) (8) (9) (21) CASH - FUEL 0 0 0 0 0 0 0 0 0 (22) CASH - OTHER 0 0 0 0 0 0 0 0 0 (23) MAT. & SUPPLIES - FUEL 0 0 0 0 0 0 0 0 0 (24) MAT. & SUPPLIES - OTHER (25) DEF. CHG Financing 15,513...
AI summary The document presents a table of financial figures in thousands of dollars, including line items related to cash, materials and supplies, deferred charges, and other costs. It outlines various categories such as pension, tax, and financing under deferred charges, as well as distribution and retail functions. The data includes subtotals and totals for different periods.
DETAILED LISTING OF C.O.S.S. INPUT INFORMATION FOR THE YEAR ENDING DECEMBER 31, 2027 (227) POWER PRODUCTION - FUEL (228) POWER PRODUCTION - OPERATING & MAINT. 366,094.3 (313) RETAINED EARNINGS 212,356 0.000 Net 154,075 Settlement Adj. 0 (3...
AI summary The document presents a detailed listing of C.O.S.S. input information for the year ending December 31, 2027, covering various financial and operational categories such as power production, retained earnings, interruption costs, and customer solutions allocators. It outlines percentages and figures related to different cost allocations and adjustments.
N-92Compliance Filing - Standardized Filings - Redacted
16 passages
tal & Deferred Charges/Credits (50) (51) CASH - FUEL 0 0 0 0 0 0 (52) CASH - OTHER 162,574 0 0 0 162,574 0 (53) MAT. & SUP. - FUEL 222,761 222,761 0 0 0 0 (54) MAT. & SUP. - OTHER 75,610 34,225 13,868 26,859 658 0 (55) DEF. CHG. - Financin...
AI summary The text presents a table of cash and deferred charges/credits, including entries for fuel, other expenses, and various deferrals related to financing, tax, pensions, and fuel deferral. The data shows amounts across different categories and years.
-6,244 0 0 0 0 0 -6,244 0 0 (33) DEF. CR. - Other -29,365 0 0 16,077 -16,077 0 -13,288 -16,077 0 (34) DEF. CR. - COST OF REMOVAL LIABILITY (COR) 10,587 0 0 -5,796 5,796 0 4,791 5,796 0 (35) CONTRACT RECEIVABLE 0 93,310 0 0 0 0 0 93,310 0 (...
AI summary The text presents a series of financial line items and balances, including deferred credits, cost of removal liability, contract receivables, and subtotals related to generation and transmission functions. The data appears to be part of a financial statement or regulatory filing.
-749 -4,687 -737 -538 -916 -1,414 -1,625 -252 -163 E-1A (30) DEF. CR. - ARO Wind -9,036 -4,512 -306 -1,913 -301 -220 -374 -577 -663 -103 -67 E-1A (31) DEF. CR. - ARO LM6000 -763 -381 -26 -162 -25 -19 -32 -49 -56 -9 -6 E-1A (31) DEF. CR. -...
AI summary The document presents a table with financial figures related to various categories such as asset retirement obligations (ARO), cost of removal liability (COR), and contract receivables. The data includes numerical values across different years and categories, indicating financial transactions and liabilities.
ACK OFFICE - (16) (17) TOTAL FINANCE 7,350 5,000 640 1,416 106 189 (18) (19) ENTERPRISE SERVICES (20) PROCUREMENT & FACILITIES 12,284 2,996 2,996 2,996 2,996 298 F - 5 (21) INFORMATION TECHNOLOGY 46,049 19,238 5,324 12,901 7,473 1,114 F -...
AI summary The document presents a financial summary with various expense categories, including procurement, information technology, human resources, and other expenses, along with totals for different divisions and periods. It includes figures for advocacy expenses and deferrals related to FCR.
1,189 1,438 - (16) DSM (17) FCR DEFERRAL 0 0 0 - (18) REG. AFFAIRS - ADVOCACY EXPENSE 1,367.0 619 748 - (18) GRANTS IN LIEU OF TAXES 22,260 10,073 12,187 - (19) Depreciation: (20) STEAM 46,715 21,139 25,575 - (21) HYDRO 16,145 7,306 8,839...
AI summary The text presents a financial summary with line items including depreciation, grants, interest, and taxes. It includes categories such as DSM, FCR deferral, and various depreciation line items for different energy sources. The data shows figures for different years and includes net interest and corporate taxes.
143,585 170,285 (87) DEFERRED CHARGES - Steam Assets Temp Adj for COR andARO unbalanced averageARO (88) DEFERRED CHARGES - FAM Deferral -5,403 -290 -10,516 (89) DEFERRED CHARGES - Other 28,723 34,227 23,219 (90) DEFERRED CHARGES - Other (D...
AI summary The text provides a detailed breakdown of deferred charges and credits related to various assets and programs, including Steam Assets, FAM Deferral, and other categories such as DSM and Storm Rider. Adjustments and average ARO values are also included.
5) PREFERRED DIVIDENDS 0 Corporate Adjustment 23,800.0 0 Regulatory Amort. 7,420 (677.610) (276) CORPORATE TAXES -10,608 Allowance for Funds (26,086) Costs of Goods Sold 0 (277) RETAINED EARNINGS 200,714 (583.862) Net 141,773 Settlement Ad...
AI summary This chunk outlines various financial and operational adjustments, including corporate taxes, retained earnings, interruption costs, and customer solutions allocators. It includes percentages and figures related to different categories and allocations.
52) CASH - OTHER 126,109 0 0 0 126,109 0 (53) MAT. & SUP. - FUEL 219,858 219,858 0 0 0 0 (54) MAT. & SUP. - OTHER 74,624 31,810 15,547 26,751 517 0 (55) DEF. CHG. - Financing 20,546 8,758 4,280 7,365 142 0 (56) DEF. CHG. - Tax 24,823 10,58...
AI summary The document presents a financial table with various line items, including cash, materials and supplies, deferred charges, and deferred credits, along with their respective amounts across different periods.
8,758 8,758 0 0 (21) DEF. CHG. - Tax 10,581 10,581 0 0 (22) DEF. CHG. - Pension 89,796 44,266 45,530 0 (23) DEF. CHG. - Steam Assets 0 0 0 0 (24) DEF. CHG. - Fuel Deferral -6,017 0 -6,017 0 (25) DEF. CHG. - Other 8,992 8,992 0 0 (26) DEF....
AI summary The text presents a financial table with various line items, including deferred charges and credits related to taxes, pensions, fuel deferral, and asset retirement obligations, as well as contract receivables and a subtotal for the generation function.
e Base Factors 48.191% 51.809% (16) Working Capital & Deferred (17) Charges/Credits: (18) CASH - FUEL 0 0 0 0 0 0 0 0 0 (19) CASH - OTHER 0 0 0 0 0 0 0 0 0 (20) MAT. & SUPPLIES - FUEL 0 219,858 0 0 0 0 0 219,858 0 (21) MAT. & SUPPLIES - OT...
AI summary The text presents a table detailing various working capital and deferred charges/credits, including entries for fuel, materials, financing, tax, pension, and other categories. The table shows values across multiple periods, with some entries showing credits and debits.
174 902 103 94 109 185 153 71 24 P-7 (23) DEF. CHG. - Pension 44,266 28,500 1,509 7,830 897 820 946 1,608 1,331 614 212 O-1 (24) DEF. CHG. - Steam Assets 0 0 0 0 0 0 0 0 0 0 0 D-3A (25) DEF. CHG. - Fuel Deferral 0 0 0 0 0 0 0 0 0 0 0 D-3A...
AI summary The text presents a table with various deferred charges and credits related to pension, steam assets, fuel deferral, and other categories, along with associated figures and codes. It outlines financial adjustments and liabilities for different asset types.
0 0 0 D-3A (16) OPER. & MAINT. - RADIAL TO GENERATION TRANS. 1,291 831 44 228 26 24 28 47 39 18 6 D-3A (17) DSM 0 See DSM Allocation (18) FCR DEFERRAL 0 0 0 0 0 0 0 0 0 0 0 P-14 (19) REG. AFFAIRS - ADVOCACY EXPENSE 648 315 51 253 0 29 0 0...
AI summary The document presents a financial breakdown of various operational and maintenance costs, including depreciation, interest, and regulatory affairs expenses. It includes figures for different line items such as demand-side management (DSM), fuel cost deferral, and grants in lieu. These details are likely part of a regulatory proceeding related to utility costs and financial reporting.
(1) Transmission - EHV and HV combined (2) OPERATING & MAINT. (Before Storm Expense) 34,364 22,124 1,171 6,078 696 637 734 1,248 1,034 476 165 D-3A (3) OPERATING & MAINT. (Storm Expense) 236 152 8 42 5 4 5 9 7 3 1 D-3A (4) REG. AFFAIRS - A...
AI summary The document presents a detailed breakdown of various financial categories, including operating and maintenance costs, regulatory affairs, depreciation, interest, and corporate taxes, with specific line items and associated references. It includes both pre-storm and storm-related expenses, as well as grants and deferrals.
170,285 197,785 (73) DEFERRED CHARGES - Steam Assets Temp Adj for COR andARO average ARO unbalanced (74) DEFERRED CHARGES - FAM Deferral -6,017 -10,516 -1,518 (75) DEFERRED CHARGES - Other 20,049 23,219 16,879 (76) DEFERRED CHARGES - Other...
AI summary The text presents a series of deferred charges and credits related to asset retirement obligations (ARO) and other categories, including Steam Assets, FAM Deferral, and FCR. Adjustments and averages for ARO are noted, as well as specific line items like DSM and LED.
-42,561 0 -42,561 -41,468 -43,655 (81) DEFERRED Credits - ARO Wind -17,384 0 -17,384 -16,933 -17,835 (82) DEFERRED Credits - ARO LM6000 -1,468 0 -1,468 -1,430 -1,506 (83) DEFERRED Credits - ARO CT -6,573 0 -6,573 -6,404 -6,742 (84) DEFERRE...
AI summary The text presents a financial summary with deferred credits related to asset retirement obligations (ARO) and other liabilities, including ARO Wind, ARO LM6000, and ARO Transformers, along with a contract receivable. The figures show variations across different categories and periods.
10,114 Allowance for Funds (17,343) Costs of Goods Sold 0 (294) RETAINED EARNINGS 212,348 (8.277) Net 154,226 Settlement Adj. 0 (295) Normal Interruption Cost 160.44 10,114 (296) Interr. Rider Coincident Demand & CD Losses 69,857 (297) PHP...
AI summary The text presents a financial summary with various line items related to costs, credits, and allocations. Key elements include fuel cost recovery deferrals, customer solutions allocators, and percentages for different customer segments.
101354Board Decision
12 passages
- The EIFEL deferral, allowing NS Power to defer incremental tax expense of about $7 million if an exemption is not enacted by the Government of Canada as it has announced; - The inclusion of four Maritime Link transmission capital project...
AI summary The document outlines NS Power's proposed adjustments, including EIFEL deferral, Maritime Link rate base inclusion, Storm Cost Recovery Rider revisions, DSM Rider changes, OATT rate updates, and fee modifications. The Board accepts some elements but reduces revenue requirements by cutting OM&G expenses, aligning executive pay with regulations, denying GRA deferral, and lowering fuel costs.
[37] The terms of the settlement agreement are set out in a schedule to the agreement and provide as follows: GRA Element Settlement Terms brought forward for approval by the Board later this year to be effective January 1, 2026. For clari...
AI summary The settlement agreement outlines terms related to the approval of a tariff for Active Demand Control services by the Board, effective January 1, 2026. NS Power and PHP will reflect these terms in a written tariff, and NS Power may seek approval for a deferral account to address revenue variances from 2026 or 2027 scenarios.
check with NSPML what their projection is for at least the federal loan guarantee part and we could take that difference. But that's $2 million right there off of both years on the base cost of fuel. So I'm just do you have any comment or...
AI summary The discussion revolves around the base cost of fuel and adjustments related to the federal loan guarantee. The speaker notes discrepancies between projections and actual figures, emphasizing the need for adjustments through the AA/BA process. There is also a mention of underrecoveries due to current rates being set below cost.
the partial decommissioning would be a lower cost to customers. So there would be a benefit to customers, but not in the sense of it's providing a service to customers, but the benefit would be there. And I think when I say, you know, a br...
AI summary The text discusses the implications of partial versus full decommissioning of hydro systems by Nova Scotia Power Inc. (NSP), noting that partial decommissioning may lower short-term costs but defer expenses to future customers. The NSUARB expresses concern that adjusting net salvage rates in the settlement agreement creates intergenerational inequity by shifting costs to future generations.
3.5.1.3 EIFEL Deferral [330] NS Power has requested the ability to create a regulatory deferral to allow it to recover an incremental tax expense if an exemption is not enacted by the Document: 328719 Government of Canada with respect to a...
AI summary NS Power requested a regulatory deferral to recover an incremental tax expense related to the EIFEL provision, which limits excessive interest and financing expenses. The exemption for regulated utilities was proposed but not yet enacted. A deferral of about $7.5 million over 2026-2027 was agreed upon if the exemption is not granted. Doane Grant Thornton supported the deferral as reasonable.
an interruptible credit (equal to the Large Industrial Interruptible Rider (LIIR) credit) and the value of priority interruption service provided, if any (modeled as a 10% premium to the LIIR credit). [339] NS Power's GRA requested a PHP D...
AI summary NS Power requested a PHP Deferral to account for revenue differences between the GRA cost-of-service study assumptions and the eventual ELID tariff. The deferral applies under specific scenarios, including if the Board's decision on the PHP tariff differs from GRA assumptions. The Industrial Group raised concerns about delays in the Goose Harbour Wind Project not being accounted for in the estimates. Uncertainty about the deferral scope was noted during the hearing.
3.5.1.4.1 Findings [349] NS Power requests a PHP Deferral account to track any variances in revenue between that which would occur based on the assumptions in the GRA cost-ofservice study treating PHP as an ATL customer versus that which r...
AI summary NS Power requests the creation of a PHP Deferral Account to track revenue variances between assumptions in the GRA cost-of-service study and the eventual ELID tariff. The Board finds it appropriate to approve the deferral account, which will account for revenue variances arising from differences in the PHP tariff, its unavailability, or unsatisfactory outcomes of the PHP ADC and tariff processes.
3.5.1.5 GRA Deferral [354] In its general rate application, NS Power asks for a deferral of its GRArelated costs of the present matter and to collect those costs in rates on a straight-line basis over the two-year test period. Such costs i...
AI summary NS Power is requesting to defer GRA-related costs, including those for the company, consumer advocates, the Board, and expert consultants, and recover them over a two-year test period. The amount was reduced from $4.0 million to $2.0 million via a settlement agreement. The deferral aligns with the Board's prior approval in the 2023-2024 GRA Decision and the recovery of costs from the Cost-of-Service Study and Line Loss Study.
he deferral of operating costs, which were canvassed by the Nova Scotia Regulatory and Appeals Board in Halifax Regional Water Commission 2026-2027 General Rate Application , 2025 NSRAB 142 (M12257):
AI summary The document references the deferral of operating costs discussed in the Nova Scotia Regulatory and Appeals Board's decision on the Halifax Regional Water Commission's 2026-2027 General Rate Application (M12257), highlighting regulatory considerations around cost deferral mechanisms.
was recently mentioned in Deirdre Sheehan et al, The Push for Electrification and a Net-Zero Grid: Developments, Reactions, and Implications, 2024 62-2 Alberta Law Review 424, 2024 CanLII Docs 3091: Consideration of the retirement of coal-...
AI summary NS Power is retiring coal-fired assets by 2030 due to legal decarbonization obligations, which may result in undepreciated costs of up to $757 million. To manage rate impacts, NS Power proposed transferring these costs to a Decarbonization Deferral Account (DDA), which was approved by the Nova Scotia Utility and Review Board (NSURB) with modifications to ensure rate stability and affordability.
[673] To reduce monthly charges for opt-out customers, NS Power proposes to conduct semi-annual meter readings for customers whose meters are currently read bimonthly (i.e., Domestic and Small General classes), and to continue monthly read...
AI summary NS Power proposes to reduce the frequency of manual meter readings for certain customer classes to lower costs, estimating savings of $1.2 million over two years. It dismissed the option of customer-submitted readings, citing challenges with accuracy and potential for intentional misreporting.
rts of the settlement agreement. It has made several adjustments in this decision to reduce NS Power's proposed revenue requirement or adjust the allocation of costs among customer classes, including: - A further reduction of $8 million in...
AI summary The Board has made several adjustments to NS Power's revenue requirement and cost allocations, including reducing operating expenses, executive compensation, and denying certain cost deferrals. Adjustments also include changes to peak load carrying capability and the denial of an AMI opt-out fee.
20260107-1Hearing Transcript — 01/07/2026 (Willett, Williams, Flemming, MacIntosh, Blair)
16 passages
NSP COST OF SERVICE PANEL 45 Questions, (Deveau) 1 evidence but did not go to an oral hearing, 2 But you were a consultant, but Q. 3 not you didn't testify as an expert. 4 (Blair) To clarify, there were A. 5 two times I've testified 6 Okay...
AI summary The text discusses a witness's involvement in regulatory proceedings, including testimony before the Ontario Energy Board and involvement in matters related to cost allocation, load forecasts, and regulatory accounts in New Brunswick. The witness was not qualified as an expert in these matters.
1, 2027. 1 A. (Williams) I think what was 2 intended with that passage was it's certainly no later 3 than January 1, 2027. 4 And it's possible that PHP may Q. 5 not be satisfied by the outcome of that proceeding at all 6 and not be served...
AI summary The text discusses a proceeding related to the allocation of costs to PHP, with the possibility that PHP may not be satisfied by the outcome of the proceeding and may not be served at an above-the-line tariff. The difference in costs between above-the-line and below-the-line customers is proposed to be collected and recovered from other above-the-line customers in a deferral account.
the-line Cost-of-Service Study that would form the basis of a true-up calculation in the deferral? A. (Williams) The basis for that true-up would be the ELIADC, the tariff that PHP is currently taking service on. MS. RUDDERHAM: Mr. Goodine...
AI summary The discussion revolves around the basis for a true-up calculation in the deferral, referencing the ELIADC tariff and NSPI's responses to NSEB IRs, specifically IR-130 subsection (e), which provides estimates of deferred amounts by month if PHP does not take service under the above-the-line tariff in the test years.
BY MS. RUDDERHAM: 1 Q. I'll just read it into the record 2 starting at line 9. It says: 3 4 5 6 7 8 9 10 11 12 13 14 In order to provide a credible monthly forecast of the PHP Deferral, [NSPI] would need to know the corresponding alternati...
AI summary The discussion revolves around the need for a credible monthly forecast of the PHP Deferral, which depends on knowing the alternative rate under which PHP would take service. The true-up would be based on the ELIADC tariff, and there is uncertainty around calculating the forecasted deferral amount if PHP remains on the current rate through 2026 or 2027.
NSP COST OF SERVICE PANEL 107 Cr-ex, (Mahody) 1 material to the Application. I believe every aspect that 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 The minimum system study is a cost analysis that estimates what the cost of the distribut...
AI summary The document discusses the Minimum System method used by Nova Scotia Power for cost analysis, where the cost of a hypothetical system with minimal equipment is considered customer-related. The remaining cost of the actual distribution system is deemed demand-related. The discussion includes a recommendation to discontinue the Minimum System method and adopt the Basic Customer method.
1 Q. And in Item B, there are three 2 factors that are referenced, the PHP's firm load at 8 3 megawatts at the three coincident peaks, and then a couple 4 of other factors. Can you confirm that all of those 5 factors are the represented fo...
AI summary The text discusses Nova Scotia Power's (NSP) application for a deferral account related to potential revenue variances arising from the Pooled Hydro Program (PHP). The company is seeking approval for the deferral account in its tariff application, but not for the specific assumptions used in the PHP treatment. The discussion also references the Settlement Agreement and its inclusion in the application.
felt, and obviously others that have signed this as well, felt was a prudent measure to ensure that the full costs and the appropriate costs are being captured. And when I say costs, I mean the cost of providing service, not just to PHP, b...
AI summary The text discusses the deferral of costs related to PHP and the need to capture the full cost of service for all customers, not just PHP. It references Bates White's evidence and mentions the approval of the deferral to address potential implications of PHP being above the line in the Application.
NSP COST OF SERVICE PANEL 141 Cr-ex, (Mahody) 1 in relation to the timing to Goose Harbour, that would 2 not be approved, necessarily, as part of the filing. It 3 would be borne out as that project progresses and comes 4 online. And so whe...
AI summary The discussion revolves around the timing of the Goose Harbour project and its impact on cost recovery from the PHP (Pooled Hydro Program). The panel acknowledges that the project's timing affects cost recovery and that assumptions in the cost of service application may differ, leading to the consideration of a deferral to mitigate risk and address potential deviations.
NSP COST OF SERVICE PANEL 167 Questions, (Chair) shift in costs under the new method of $26 million to domestic customers? A. (Willett) That is correct. That's the impact of the old cost-of-service methodology compared to the new cost-of-s...
AI summary The discussion revolves around the impact of changing the cost-of-service methodology on different customer classes, particularly the shift of costs to domestic customers under the new method, and the potential offset of these changes by adopting the Basic Customer method.
NSP DEPRECIATION PANEL 205 In-ch, (Clarke) 1 been conducting depreciation studies for utility companies 6 7 8 9 10 11 12 13 14 15 16 As described in Section 9.2, if securitization of the unrecovered net book value of generation assets with...
AI summary Nova Scotia Power is requesting an interim deferral of depreciation expense and financing costs for generation assets under the DDA if securitization cannot be completed by January 1, 2026. The Consensus Agreement does not address this request, leaving parties free to take positions on the application.
NSP DEPRECIATION PANEL 215 Cr-ex, (MacAdam) 1 costs and that those costs would be included in a deferral 2 as of that date and carried forward. 3 [2:19:54] Q. So how would NSPI account for any 4 of the financing and depreciation costs that...
AI summary The discussion revolves around Nova Scotia Power's (NSPI) accounting for financing and depreciation costs related to securitization, with concerns about potential double charging to ratepayers. NSPI is seeking to defer these costs, acknowledging the debate over whether they are already included in current rates.
NSP DEPRECIATION PANEL 221 Cr-ex, (MacAdam) 1 service and we look at the total revenue that Nova Scotia 2 Power forecasts for 2026, it's clear that the company 3 doesn't have or doesn't expect to have their revenue to 4 cover its cost of s...
AI summary The discussion revolves around Nova Scotia Power's projected revenue shortfall in 2026 and the proposed deferral of costs. The questioner seeks a percentage-based estimate of under-collection, but the response indicates that while assumptions can be made, the company primarily considers the total cost-of-service basis for decision-making.
NSP DEPRECIATION PANEL 225 Cr-ex, (MacAdam) 1 A. (Williams) Yeah, and I think what 2 we would suggest is that it is the $18 million. So the 3 depreciation and financing costs associated with those 4 that securitized tranche of rate base. A...
AI summary The discussion centers on the $18 million depreciation and financing costs associated with a securitized tranche of rate base. The speaker questions whether reducing this amount would be appropriate, emphasizing the need to align with the expectations set in the Rate Application and avoid assumptions. The discussion also touches on the potential for double collection if deferral costs are tied to new rates.
1 treating your return on equity with respect to that amount 2 differently as well because you're getting the benefit of 3 allowing those costs to be put into a deferred account for 4 later recovery. Otherwise, you'd just be absorbing them...
AI summary The discussion revolves around deferring financing costs related to securitization due to delays, with the aim of keeping rates lower for customers. These costs will be recovered over time through securitization bonds rather than being included in the current rate application.
NSP DEPRECIATION PANEL 235 Cr-ex, (MacAdam) 1 THE CHAIR: Right. You're asking the 2 Board to once it approves the deferral, to 3 retroactively include costs that you've already incurred. 4 MR. FLEMMING: Asking the Board, yes, 5 to let us d...
AI summary The discussion revolves around the deferral of financing costs for Nova Scotia Power, with concerns about retroactively including these costs after they have already been incurred. There is a focus on the timing of rate approvals and securitization, and how these factors impact the recovery of costs over time.
NSP DEPRECIATION PANEL 273 Cr-ex, (Mahody) 1 Mr. Wiedmayer here as well, Mr. Mahody. INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORTERS 1 questions. 2 THE CHAIR: All right. Why don't we 3 take a brief break and come back at quarter to...
AI summary The document is a transcript from a depreciation panel hearing involving Nova Scotia Power and the Nova Scotia Energy Board. It includes questions from Member Murphy regarding the General Rate Application (GRA) and cost-of-service deferral from the 2022 GRA, specifically referencing a deferral amount of $2.5 million.
20260108-1Hearing Transcript — 01/08/2026 (Pecurica, Willett, Williams, Flemming, Coyne)
12 passages
NSP COST OF CAPITAL PANEL 409 Cr-ex, (Mahody) 1 Trenton Unit 5 two boiler feed and, ultimately, down at 2 the bottom of paragraph 7, the Board indicates: 3 4 5 6 7 8 These extra costs were calculated at $1,141,261.58. The Board finds that...
AI summary The Board found Nova Scotia Power imprudent in incurring extra costs of approximately $1.1 million, which will be disallowed and credited to customers in the FAM. This amount is a small fraction of the $1.7 billion in FAM costs incurred by Nova Scotia Power over the 2022 and 2023 audit period.
Q. So lots of potential factors at play there. INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORTERS A. (Williams) So yes, and I think all of the uncertainty that you and I are discussing here really just underlines the need for, and the...
AI summary The discussion focuses on the importance of deferral mechanisms in managing cost-of-service impacts, particularly in relation to PHP's potential subscription to the ELID Tariff. The witness emphasizes the need for caution when considering changes to PHP's treatment within the electricity system.
d on. The deferral was intended to capture anything that's different at a high level, anything that's different than that. To the extent that 2027, a tariff for PHP in 2027 differs from that, the cost 1 of service that's imbedded in electr...
AI summary The discussion revolves around the deferral of costs related to PHP (Power Hosting Provider) in the context of a Cost-of-Service Study. The deferral is intended to capture deviations from current assumptions, and there is no final study that assumes PHP is below the line.
line. 1 Q. And I guess just the reason I'm 2 asking is I'm trying to get some certainty some sense 3 of certainty about what the potential outcome could be 4 whether it's phrased through the vehicle of a deferral 5 account or whether it's...
AI summary The discussion focuses on the potential outcomes of a deferral account and different cost-of-service models, particularly their impact on the residential class. The witness refers to a tab in OR-1, Attachment 1, which outlines PHP's revenues as both below-the-line and above-the-line customers.
1 the deferral account will account for any differences that 2 would arise as a result of the different treatment between 3 PHP being above the line versus below the line. 4 A. (Williams) The short answer to 5 that would be yes, Mr. Murphy...
AI summary The discussion revolves around the deferral account and its treatment of PHP (Power Hosting Provider) above or below the line, as well as the proposed dispatchable rider in the Application ELID. The impact of Goose Harbour Lake and load changes is noted, and the dispatchable rider is compared to ADC (Active Dispatchable Capacity).
1 CROSS-EXAMINATION BY MS. RUDDERHAM 3 Q. Sorry. And what I referred to is 4 that 3CP debate that we kind of talked about yesterday. 5 A. (Williams) That would be included 6 in that, yes. 7 Q. Yes. Okay. 8 Looking at bullet 2, then no, 9 s...
AI summary This text is a transcript of a cross-examination discussing the inclusion of items in a deferral account and the need for the Board and stakeholders to understand what would be captured in such an account. The conversation touches on tariff-related charges and baseline comparisons.
INTERNATIONAL REPORTING INC. CERTIFIED COURT REPORTERS 1 scenarios. 2 Q. So it's fair to say that what's 3 listed here are they're intended to set the parameters for 4 this PHP deferral account that NSPI is seeking approval 5 of. 6 A. (Wil...
AI summary The discussion centers on the parameters of a PHP deferral account that NSPI is seeking approval for, acknowledging the uncertainty and cautious approach to avoid harming customers. The exhibit referenced is from matter M12661, page 14.
rvice over the test 17 period, and it would be a fairly significant assumption 18 that was built into the GRA in terms of when that wind 19 farm would be coming online and when PHP's load would INTERNATIONAL REPORTING INC. CERTIFIED COURT...
AI summary The discussion revolves around the impact of timing changes in the implementation of a wind farm on revenue collected through electricity rates and potential effects on cost deferral. The GRA assumptions regarding the wind farm's online date and PHP load shifts are being considered in relation to the Board's decision on the PHP tariff.
1 think, "material aspects" and "material assumptions," and 2 I just want to get some clarity, I guess, to explain how 3 NSP is going to distinguish between the tariff-related 4 variances that are deferrable and volume-related variances 5...
AI summary The discussion focuses on distinguishing between deferrable tariff-related and volume-related variances, with NSP highlighting that only material or significant impacts to PHP's operations are considered, excluding normal course deviations.
- of the year. Do you recall that? 1 A. (Williams) I recall a discussion. 2 I wasn't intending to clarify or change it. It was the 3 first half of 2026. 4 The first half. Q. 5 A. (Williams) Middle of the year. 6 No, that's fine. Q. 7 So if...
AI summary The discussion revolves around the securitization of deferred depreciation and financing costs by Nova Scotia Power during the 2026-2027 period. The timing of securitization, potentially starting in July 2026, is being considered, with implications for customer benefits and rate structures.
acknowledge that if we had submitted it earlier that rates could have been in place, but that's really the reason for the delay. BY MR. MacDOUGALL: Q. Okay, but just to get clarity there. You agree that if these assets were in rate base yo...
AI summary The discussion revolves around the treatment of assets in rate base and the deferral of depreciation and financing costs. The witness confirms that if assets are in rate base, no further recovery can occur until new rates are set. The questioner highlights the difference in approach for these assets compared to others in rate base.
're now asking that even 17 before the new rates are put in place that you can 18 collect, for a deferral account, depreciation and 19 financing costs, and you would not, until new rates are in INTERNATIONAL REPORTING INC. CERTIFIED COURT...
AI summary The discussion revolves around the treatment of identical generation assets under different accounting practices, specifically regarding the collection of depreciation and financing costs prior to the implementation of new rates, with concerns about unequal treatment and the absence of securitization.