Topic:"Dcrr" in M12451

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The Demand Side Management Cost Recovery Rider establishes a charge (in cents per kilowatt-hour) applicable to the current rate year's Tariff, to be applied in addition to the energy charge. This charge is specified within the DCR Rider framework.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The Demand Side Management Cost Recovery Rider (DCR) imposes an additional charge per kilowatt-hour on the Tariff, applied alongside the energy charge. This mechanism allows Nova Scotia Power Inc. (NSPI) to recover costs associated with demand-side management programs.

DEMAND SIDE MANAGEMENT (DSM) COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shal...

AI summary The Demand Side Management Cost Recovery Rider imposes an additional charge per kilowatt-hour on the Tariff for the current rate year, applied alongside the energy charge. This mechanism enables cost recovery for demand-side management initiatives.

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) The monthly amount computed under each of the rate schedules to which this DSM Cost Recovery Rider is applicable shall be increased or decreased by the DCRR at a class-specific rate per kil...

AI summary The Demand Side Management Cost Recovery Rider (DCRR) adjusts monthly rates based on a class-specific formula (DCRR = PCR + BA) applied to kilowatt-hour consumption under applicable rate schedules. This mechanism recovers DSM program costs through consumption-based rate adjustments.

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

AI summary The Balance Adjustment (BA) is updated annually and after each Approved DSM Term, with the NSEB-approved DCRR taking effect in bills after its effective date. This ensures alignment with DSM program costs and regulatory approvals.

DSM Cost Allocation Method - Step 1 Allocate the class and participation benefits by directly assigning 100% of the DSM investment identified for each participating customer class. - Step 2 For NS Power bundled service customers, divide th...

AI summary The DSM Cost Allocation Method outlines a five-step process for allocating Demand Side Management (DSM) costs. It involves assigning DSM investments to customer classes, calculating program cost recovery based on electricity sales, direct billing for Wholesale/Renewable to Retail (RtR) customers, and annual/term-end true-ups referenced in Balance Adjustment (BA) sections. The method applies to NS Power bundled service and market-specific recovery mechanisms.

For customers connected at distribution level, the following charge also applies, subject to the same provisions as the Demand Charge section above. per month Effective February 2, 2023 $1.632 Effective January 1, 2024 $1.632 Effective Jan...

AI summary A new charge applies to customers connected at the distribution level, with rates increasing from $1.632 in 2023 to $2.527 in 2027. Additionally, a 32-cent reduction in demand charge per kilovolt ampere is available for customers owning the transformer.

reduction per kilovolt ampere reduction in demand charge Effective February 2, 2023 $7.486 Effective January 1, 2024 $7.486 Effective January 1, 2026 $7.638 Effective January 1, 2027 $7.667 AVAILABILITY

AI summary The table shows the reduction per kilovolt-ampere reduction in demand charge at different effective dates, with values increasing slightly over time. The values are consistent from February 2023 to January 2024, then increase slightly in 2026 and 2027.

Page 19 of 21 D . C . kWh per per mo onth ($) 0.1 615 616 623 44 55 28 month 15 18 9 2026 9.98 10.20 9.55 2027 10.57 10.79 10.12 Other 615 616 623 624 44 55 28 50 month 15 18 9 17 2026 9.98 10.20 9.55 10.12 2027 10.57 10.79 10.12 10.72 Oth...

AI summary The text presents a table with data related to demand-side management (DSM) cost recovery riders (DCRR) and other related metrics, including values for different months and years, and other unspecified categories.

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

AI summary The Franchise Holder must seek NSUAREB approval for DSM activities and costs. NS Power must apply annually by October 1 for DCRR amounts and monthly fund DSM costs approved by NSUAREB under Section 79C of the Public Utilities Act.

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

AI summary The Balance Adjustment (BA) is annually updated to reflect BA1 and BA2, with the NSUAREB-approved DCRR implemented post-effective date. BA1 relates to annual updates, while BA2 applies at the end of Approved DSM Terms. The DCRR's activation is tied to NSUAREB approval.

2 The Approved DSM Term refers to the full DSM Plan period in effect (e.g. 2023-2026, 2027-2031). Applicable Tariff PCR (cents per kWh) BA (cents per kWh) DCRR (cents per kWh) Domestic Service, Domestic Service Time-of-Day, Domestic Servic...

AI summary The Approved DSM Term refers to the full DSM Plan period in effect, such as 2023-2026 or 2027-2031. A table outlines various applicable tariffs and associated PCR, BA, and DCRR values for different service categories.

PR-03 Proposed Regulations Attachment 1a (Redline)/2a (Clean) - Regulation 1.1 Interpretation and Definitions Attachment 1b (Redline)/2b (Clean) – Regulation 5.1 Meter Reading Attachment 1c (Redline)/2c (Clean) – Regulation 7.1 Schedule of...

AI summary The document outlines four attachments related to PR-03 Proposed Regulations, including amendments to definitions, meter reading protocols, charge schedules, and load research charges. These updates aim to clarify regulatory frameworks and operational procedures under the Demand Side Management Cost Recovery Rider (DCRR) program.

2026-2027 GRA Direct Evidence Appendix 1B Page 1 of 4 REDACTED (CONFIDENTIAL INFORMATION REMOVED)

AI summary The document is a redacted appendix from a Nova Scotia regulatory proceeding related to the 2026-2027 GRA, with confidential information removed. No substantive content or arguments are visible in the provided text.

REDACTED 2026-2027 GRA Direct Evidence Appendix SA Page 7 of 38 REDACTED (CONFIDENTIAL INFORMATION REMOVED)

AI summary The document is a redacted appendix from a 2026-2027 General Rate Application (GRA) proceeding in Nova Scotia, containing confidential information. Key acronyms related to energy regulation, cost recovery, and infrastructure are listed, though no substantive content is visible due to redaction.

2026-2027 GRA Direct Evidence Appendix 6B (Redline) Page 24 of 35 REDACTED (CONFIDENTIAL INFORMATION REMOVED)

AI summary This redacted page from the 2026-2027 GRA Direct Evidence Appendix 6B discusses confidential aspects of a regulatory proceeding, likely involving rate applications, cost recovery mechanisms, and energy management programs. Key focus areas include DSM, DER, and administrative cost allocations.

Cost of Service Study Redacted 1 TABLE OF CONTENTS 2 3 1.0 INTRODUCTION 5 4 2.0 SUMMARY OF STAKEHOLDER PROCESS 7 5 3.0 SUMMARY OF COSS 10 6 3.1 The COSS Framework 10 7 3.2 Developments in the Company's Power System Impacting COS 11 8 4.0 O...

AI summary The document outlines the structure and contents of a redacted Cost of Service Study (COSS) being presented in a regulatory proceeding. It includes sections on the stakeholder process, proposed changes to the COSS, and a line loss study. Key topics include classification of generation and transmission costs, treatment of battery systems, and proposed changes to the DSM rider.

Interruptible Base cost of fuel ¢/kWh 8.031 7.780 -0.251 -3.1% Non-fuel ¢/kWh 2.064 2.224 0.160 7.8% Subtotal 10.095 10.004 -0.091 -0.9% FAM AA ¢/kWh 0.000 0.000 0.000 0.0% FAM BA ¢/kWh 0.224 0.224 0.000 0.0% Subtotal 0.224 0.224 0.000 0.0...

AI summary The table presents cost breakdowns for interruptible services, showing a 3.1% decrease in base fuel costs (from 8.031¢/kWh to 7.780¢/kWh) and a 7.8% increase in non-fuel costs (from 2.064¢/kWh to 2.224¢/kWh). Fuel Adjustment Mechanism (FAM) and Demand Side Management (DSM) components remain unchanged, while total costs decreased by 0.8%.

Municipal Tariff Demand Charge (Ratcheted) $/kVA 11.330 12.270 0.940 8.3% Transformer Ownership Credit ¢/kVA -32.000 -32.000 0.000 0.0% Energy Charges Base cost of fuel ¢/kWh 8.943 9.044 0.101 1.1% Non-fuel ¢/kWh 2.614 2.831 0.217 8.3% Sub...

AI summary The document outlines municipal tariff rates for 2026 and 2027, including demand charges, energy costs, and adjustments like Fuel Adjustment Mechanism (FAM) and Demand Side Management (DSM). It details variances in rates, with percentages indicating changes from prior years, and references the 2026-2027 General Rate Application (GRA) attachment.

Outdoor Recreational Lighting Tariff Energy Charges Base cost of fuel ¢/kWh 8.120 7.915 -0.205 -2.5% Non-fuel ¢/kWh 3.271 3.748 0.477 14.6% Subtotal 11.391 11.663 0.272 2.4% FAM AA ¢/kWh 0.000 0.000 0.000 0.0% FAM BA ¢/kWh 0.156 0.156 0.00...

AI summary The Outdoor Recreational Lighting Tariff outlines energy charge components, including fuel and non-fuel costs, with percentage changes between periods. Key elements include Fuel Adjustment Mechanism (FAM), Demand Side Management (DSM) charges, and System Cost Recovery Rider (SCRR), showing variations in rates and their impacts.

Unmetered Service Rates: Miscellaneous Lighting & Small Loads Demand Charge $/kW 13.843 14.173 0.330 2.4% Energy Charges First 200 kWhs per kW of Max Demand Base cost of fuel ¢/kWh 8.120 7.915 -0.205 -2.5% Non-fuel ¢/kWh 9.652 10.281 0.629...

AI summary The document outlines unmetered service rates for Miscellaneous Lighting & Small Loads, detailing demand charges ($/kW) and energy charges (¢/kWh). It shows changes in base fuel and non-fuel costs, FAM adjustments, DSM PCR/BA, and SCRR, with percentage variations between periods. Fuel costs decreased (-2.5%), while non-fuel costs increased (6.5%).

The Fuel Adjustment Mechanism (FAM) and the Actual Adjustments (AA) or Balancing Adjustments (BA) is proposed to continue to operate in the normal course during 2026 and 2027, with new Base Cost of Fuel (BCF) amounts set for 2026 and 2027....

AI summary The Fuel Adjustment Mechanism (FAM) and related adjustments are proposed to continue during 2026 and 2027 with updated Base Cost of Fuel (BCF) amounts. The Demand Side Management Rider is also proposed to continue with changes to its calculation method.

1 4.5 Price Data 2 3 Price data is an input to the SAE forecasts for the residential, small general and general services 4 classes, and the price series is calculated from historical billed sales and billed revenues. Revenue 5 per kWh is f...

AI summary Price data is used in SAE forecasts for residential and commercial electricity classes, with the price series derived from historical billed sales and revenues. The nominal price of electricity is projected to increase by 3.8% in 2025 and 5% annually from 2026 to 2029, with higher increases thereafter. Price elasticity is factored into sales forecasts.

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

AI summary The Franchise Holder is responsible for seeking NSUAREB approval for all DSM activities, plans, and programs, as well as related costs. NS Power must apply for approval of DSM Cost Recovery Rider amounts by October 1 of the year before program implementation and pay the approved amount monthly to the Franchise Holder.

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) The monthly amount computed under each of the rate schedules to which this DSM Cost Recovery Rider is applicable shall be increased or decreased by the DCRR at a class-specific rate per kil...

AI summary The document outlines the formula for calculating the Demand Side Management Cost Recovery Rider (DCRR), which adjusts the monthly rate based on a class-specific rate per kilowatt hour of consumption.

BA = Balance Adjustment The BA is comprised of two components: - (1) BA1 = Annual Volume Variance Adjustment is calculated for each rate class separately on a previously completed calendar year basis and is used to reconcile the difference...

AI summary The Balance Adjustment (BA) is divided into two components: BA1, which reconciles revenue differences based on actual class load from the previous year, and BA2, which adjusts for discrepancies between approved DSM expenditures and actual costs, applying the adjustment over the remaining term of the DSM program.

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

AI summary The Balance Adjustment (BA) is updated annually and at the end of each Approved DSM Term. The NSUAREB-approved DCRR is implemented with bills rendered after the effective date of the change.

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

AI summary The document outlines three types of benefits from DSM: system, class, and participation. It argues that DSM costs should be allocated based on the level of benefit received by customer classes, with those receiving the most benefits bearing the greatest responsibility. However, it acknowledges the difficulty in precisely calculating and allocating these costs due to the nature of DSM programs.

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

AI summary The method outlines a multi-step process for allocating and recovering DSM program costs across customer classes. It involves allocating system benefits, class benefits, calculating total recovery amounts, and adjusting annually based on actual experience.

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

AI summary The DCRR applies to bundled service customers not in the Wholesale Market as a whole, while individual customers in the Wholesale Market are treated separately. The approach covers total Approved DSM costs.

(c) Please see the table below. Prior to 2023, NS Power did not include separate amounts for Level 1 & 2 and Level 3 & 4 storm restoration expense in revenue requirement. Total Storm OM&G in Level 1 & 2 Level 3 & 4 Revenue Year ($ million)...

AI summary Prior to 2023, NS Power did not include separate amounts for Level 1 & 2 and Level 3 & 4 storm restoration expenses in revenue requirement. The table shows the total storm OM&G in revenue requirement from 2020 to 2027, with changes starting in 2023. NS Power is not proposing changes to the DSM rider amounts for 2026 or 2027 but is proposing changes to how the Balance Adjustment (BA) is calculated.

Proposed DCRR Framework If approved, the proposed DCRR framework would be in effect during the 2027-2031 DSM Term. For example, the 2028 DCRR would include: (b) The proposed DCRR framework adds a BA 2 component to the BA to reconcile, by r...

AI summary The proposed DCRR framework would be effective during the 2027-2031 DSM Term. It introduces a BA2 component to balance differences between approved and actual DSM expenditures by rate class. This aims to reduce rate volatility by spreading variances over a four-year recovery period, starting in year two of the following Term.

sion 22570-D01-2018, 2018 Generic Cost of Capital, page 92, para. 438. Decision 2191-D01-2015, 2013 Generic Cost of Capital, para. 190 [emphasis added] [footnote omitted]. However, as discussed in Section 3, Concentric used these growth es...

AI summary The text discusses the use of multi-stage DCF growth estimates by Concentric, which assumes higher growth rates for 10 years before declining to long-term GDP growth rates. This approach implicitly assumes earnings and dividends will grow above expected nominal GDP growth indefinitely.

e realistic. See for example: "Monitoring changes in analysts' advice gives key insight: report," (Tim Shufelt, Globe and Mail, Report on Business, May 24, 2019, page B7. three witnesses in their single-stage DCF models are in excess of th...

AI summary The Commission states that long-term growth rates in single-stage DCF models must not exceed long-term GDP growth estimates, citing that utilities operate in mature markets as monopolies. It also notes that analyst growth estimates are upwardly biased and should not be used in DCF models.

of Northern States Power Company for Authority to Increase Rates for Electric Service in Minnesota. November 1, 2024. Exhibit___(CJB-1), Schedule 8 p.9 (PDF p.126). Provided as Attachment LFE-83-1. - Redacted Evidence of Caroline Palmer Th...

AI summary The discussion addresses the minimum system study and its implications, including the allocation of demand-related costs and the recommendation for a load carrying capacity adjustment. Industry literature is referenced to support the view that minimum-size distribution equipment can be a demand-related cost. The impact of using the basic customer distribution classification on the Cost of Service Study (COSS) is also raised.

load but rather a significant reduction, and (5) clarifying the eligibility requirement that customers "not [be] engaged in local commerce." Chait Prefiled Test., pp. 22–25; CIEC Brief, pp. 18–19, 22. First, UI agreed with CIEC's recommend...

AI summary The document discusses the approval of UI's amended special contract policy, including the inclusion of the EDR and adjustments to the price floor based on long-run marginal distribution costs. The Authority rejects a 15% or 20% discount but allows for larger discounts if necessary. Only the delivery component of the bill is eligible for a discount under this policy.

UTILITY RATE PROCEEDINGS IN WHICH TESTIMONY HAS BEEN PRESENTED BY JACOB POUS ALASKA Southern Union Gas Company 2738, 2958, 3002, 3018, 3019 Cons. Cost of Service, Rate Design, Depreciation Southern Union Gas Company 6968 Interim & Cons. Af...

AI summary Jacob Pous has provided testimony in multiple utility rate proceedings involving Southern Union Gas Company, covering topics such as cost of service, rate design, depreciation, affiliate transactions, and rate base. These proceedings include various consolidated and interim cases with different focus areas.

Definitions for Act and regulations - 2 (1) In the Act, "general rate increase" does not include increases arising from the fuel adjustment mechanism, demand side management cost recovery riders or the special annually adjusted rates. - (2...

AI summary The text defines 'general rate increase' in the Act, excluding increases from the fuel adjustment mechanism, demand side management cost recovery riders, and special annually adjusted rates. It also defines 'pay plan' as the Senior Officials Pay Plan under the Civil Service Act and Public Service Act.

10.1 Introduction Some components of the revenue requirement cannot be directly allocated, or allocated to customer rate classifications by using the functionalization, categorization and allocation process described earlier. Instead other...

AI summary The document discusses methods for allocating revenue requirements when direct allocation is not feasible, including pro rata allocation and detailed analyses. It lists various expenses and capital expenditures that fall into this category, such as administrative expenses, working capital allowance, and conservation costs.

General Approach The Technical Advisory Team believed that the general purpose of Conservation and Demand Management ("CDM") is to reduce energy consumption and peak demand. Based on this viewpoint, the suggestion arose during the consulta...

AI summary The Technical Advisory Team views Conservation and Demand Management (CDM) as a means to reduce energy consumption and peak demand. A 50/50 allocation of CDM costs based on energy consumed and demand used was suggested, but an alternative proposal was issued by Board Staff in 2006 to align cost allocation with budgeted spending, as agreed upon in a previous gas DSM hearing.

10.8.2 Direction – Allocation of Conservation and Demand Management Costs For cost allocation purposes, CDM costs must be allocated as follows: - 1. Direct CDM program operating expenses must be allocated to the participant customer classi...

AI summary The document outlines the allocation of Conservation and Demand Management (CDM) costs, specifying that direct program expenses are allocated to participant customer classifications, while indirect and capital costs are distributed proportionally based on composite operating and maintenance costs.

NON-CONFIDENTIAL 1 Undertaking U-15: 2 3 To provide an order of magnitude impact of the AA/BA FAM riders and DSM rider on each 4 individual customer class rate impact as a comparison to Figure 2-1. 5 6 Response U-15: 7 8 Please refer to th...

AI summary The response to Undertaking U-15 provides an overview of the impact of the AA/BA FAM riders and DSM rider on customer class rates in 2026, referencing specific figures and attachments. It also notes that the settlement agreement includes smoothing or mitigating the impacts of the AA/BA riders, which may lower increases for some classes in 2026 by deferring recovery to 2027.

28 1 3.9 Amendments Arising from GRA IR Process 3 4 2027 DCAs. … 5 6 Subject to the Board's approval, the Company proposes to make the appropriate 7 8 revision to the DCA in the Compliance Filing, consistent with the revised rate calculati...

AI summary The document outlines proposed amendments to the 2027 DCAs, subject to the Board's approval, and mentions revisions to the DCA in the Compliance Filing consistent with revised rate calculations following the Board's Decision on the GRA.

1 3.10.2 DSM Cost Recovery Rider (DCRR) - 2 On March 31, 2026, the Board issued its Order approving the 2026 DCRR (M12521) effective - 3 January 1, 2026. The DCRR Tariff has been updated to reflect the 2026 rates and the revised - 4 method...

AI summary The Nova Scotia Energy Board approved the 2026 DCRR effective January 1, 2026, with updates to the tariff reflecting revised cost-of-service study methods. NS Power plans to implement both DCRR and GRA rate changes simultaneously to avoid multiple rate increases. True-up adjustments will be addressed in a future DCRR Application.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the Tariff for the current rate year as specified in the Demand Side Management Cost Recovery Rider.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the Demand Side Management Cost Recovery Rider, specifying that a charge in cents per kilowatt-hour applies to the Tariff for the current rate year, in addition to the energy charge.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the Tariff for the current rate year as specified in the Demand Side Management Cost Recovery Rider.

11.2 Billing Unless NS Power directs otherwise, the RtR Customer shall be invoiced by the LRS and will pay the LRS for any charges or fees, inclusive of all applicable taxes, owing by the RtR Customer to NS Power under this Distribution Ta...

AI summary This section outlines the billing responsibilities of the RtR Customer under the Distribution Tariff, including charges for distribution system access, demand-side management, storm recovery, and other approved items. The RtR Customer agrees to pay the LRS for these charges and waives claims against NS Power related to billing by the LRS.

DEMAND SIDE MANAGEMENT (DSM) COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shal...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the Tariff for the current rate year as specified in the Demand Side Management Cost Recovery Rider.

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) The monthly amount computed under each of the rate schedules to which this DSM Cost Recovery Rider is applicable shall be increased or decreased by the DCRR at a class-specific rate per kil...

AI summary The document outlines the formula for the Demand Side Management Cost Recovery Rider (DCRR), which adjusts monthly rates based on a class-specific rate per kilowatt hour of consumption. The formula is defined as DCRR = PCR + BA, indicating how costs are recovered through this rider.

BA = Balance Adjustment The BA is comprised of two components: - (1) BA1 = Annual Volume Variance Adjustment calculated for each rate class separately on a previously completed calendar year basis and is used to reconcile the difference be...

AI summary The Balance Adjustment (BA) is divided into two parts: BA1, which reconciles revenue discrepancies from two years prior, and BA2, which adjusts for differences between approved DSM funding and actual expenditures, ensuring customers are charged or refunded based on real program costs.

DSM Cost Allocation Method - Step 1 Allocate the class and participation benefits by directly assigning 100% of the DSM investment identified for each participating customer class. - Step 2 For NS Power bundled service customers, divide th...

AI summary The DSM Cost Allocation Method outlines a five-step process for allocating and recovering Demand Side Management (DSM) investment costs across different customer classes, including bundled service customers and those in Wholesale or Renewable to Retail markets, with adjustments made annually and at the end of each Approved DSM Term.

Conditions - For bundled service customers, other than those who take service in the Wholesale Market (whether in whole or in part), this approach applies to classes as a whole (not to individual customers). - For customers who take servic...

AI summary The conditions outline how the approach applies to bundled service customers and those in the Wholesale Market, emphasizing that it applies to classes as a whole for the former and to individual customers for the latter, while also applying to total Approved DSM costs.

Special Terms and Provisions - (1) Green Power, as defined for the purposes of this rider includes energy produced from renewable resources that have minimal impact on the environment, and could be independently certified by third party en...

AI summary This section defines 'Green Power' as energy from renewable sources with minimal environmental impact, potentially certifiable by third parties. The Company may limit service based on the availability of green energy.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the Tariff for the current rate year as specified in the Demand Side Management Cost Recovery Rider.

DEMAND CHARGE per month per kilovolt ampere of maximum demand Effective February 2, 2023 $13.796 Effective January 1, 2024 $8.332 Effective upon the date of the Board's Order $10.710 Effective January 1, 2027 $11.269 32 cents per kilovolt...

AI summary The document outlines the demand charge rates effective from February 2, 2023, to January 1, 2027, with reductions available for customers who own the transformer. The rates are set by the Board and include a reduction of 32 cents per kilovolt ampere for transformer ownership.

For customers connected at distribution level, the following charge also applies, subject to the same provisions as the Demand Charge section above. per month Effective February 2, 2023 $1.632 Effective January 1, 2024 $1.632 Effective upo...

AI summary The text outlines a charge applicable to customers connected at the distribution level, with rates effective from February 2023 to January 2027. A reduction in demand charge is provided for customers who own the transformer, at a rate of 32 cents per kilovolt ampere.

11.2 Billing Unless NS Power directs otherwise, the RtR Customer shall be invoiced by the LRS and will pay the LRS for any charges or fees, inclusive of all applicable taxes, owing by the RtR Customer to NS Power under this Distribution Ta...

AI summary This section outlines the billing responsibilities of the RtR Customer under the Distribution Tariff, specifying that they will be invoiced by the LRS and must pay all applicable charges, including Demand Side Management Cost Recovery Charges and Storm Cost Recovery Charges, as well as any other items approved by the Board.

BA = Balance Adjustment The BA is comprised of two components: Effective: January 1, 2025January 1, 2026 - (1) BA 1 = Annual Volume Variance Adjustment is calculated for each rate class separately on a previously completed calendar year ba...

AI summary The Balance Adjustment (BA) consists of two components: BA1, which reconciles revenue differences based on actual class load from the previous year, and BA2, which adjusts for differences between approved DSM program costs and actual expenditures. Both are applied with a lag to ensure accurate billing.

Total BA = BA 1 + BA 2 The BA shall be updated annually to reflect BA1, and at the conclusion of each Approved DSM Term to reflect BA2. The NSEB-approved DCRR shall be placed into effect with bills rendered on and after the effective date...

AI summary The Balance Adjustment (BA) is composed of BA1 and BA2, with BA updated annually and BA2 applied at the end of each Approved DSM Term. The NSEB-approved DCRR will be implemented with bills starting from the effective date of the change.

5 178 (29) (30) TOTAL DIVISIONAL EXPENSES bfr Advocacy Expense 204 7,801 (31) (32) TOTAL DIVISIONAL EXPENSES 205 7,849 (33) (34) COGS - - (35) (36) DSM EXPENSES - - (37) (38) FCR DEFERRAL - - (39) (40) OTHER EXPENSES - - (41) (42) CAPITAL...

AI summary The text presents a financial summary with various expense categories, including divisional expenses, COGS, DSM expenses, FCR deferral, and others. It also includes depreciation and grants in lieu of taxes. Specific line items are listed with corresponding numbers.

(1) INTERR. RIDER DMD ADJ. (2) (3) Peak Dmd. in KWs (at Generator) 69,594 (4) Int Credit Amount 11,165 (5) (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (8) Demand Usage Annual Credit Amount Calculation Winter Month Winter Month Sum of 12 % Pr...

AI summary This document contains a table and calculation related to demand adjustment and interruption credits, including peak demand figures, credit amounts, and a breakdown of annual credit calculations based on power factor and priority levels.

OINCIDENT LINE COIN. PEAK COINCIDENT SALES LOSSES REQUIREMENT DMD. (KW) FACTOR DMD. (KW) LOSSES DMD. (KW) L/D FACTOR ( 1) DOMESTIC 431,585 8.60% 468,686 1,111,549 82.8% 920,296 11.77% 1,028,601 63.29% ( 2) SMALL GENERAL 28,882 8.54% 31,350...

AI summary The document presents a detailed breakdown of electricity sales, losses, and demand factors across various customer categories in Nova Scotia, including domestic, industrial, and municipal sectors, along with specific programs such as PHP and ELIADC.

18,477.9 (215) PURCHASED POWER - BIOMASS (Energy) 14,919.9 (216) PURCHASED POWER - BIOMASS (Demand) 5,382.6 (217) PURCHASED POWER - MARITIME LINK 198,664 86,453.2 85,044.2 (218) PURCHASED POWER - WIND (ERIS) 33,418.0 (219) PURCHASED POWER...

AI summary The text presents a detailed breakdown of purchased power costs and related expenses, including biomass, wind, and imports, along with depreciation and accretion figures for different energy sources. It includes categories such as DSM expenses, grants, and adjustments.

(1) INTERR. RIDER DMD ADJ. (2) (3) Dmd. in KWs 69,857 (4) Int Credit Amount 11,207 (5) (6) PHP DEMAND ADJUSTMENT CALCULATION (7) (8) Demand Usage Annual Credit Amount Calculation Winter Month Winter Month Sum of 12 % Premium For Priority P...

AI summary This text presents a demand adjustment calculation related to a PHP demand interruption credit. It includes figures for demand in kilowatts, credit amounts, and a detailed breakdown of the annual credit calculation based on demand usage and priority levels.

RATE CLASS DISAGGREGATION ANALYSIS BY FUNCTIONAL AREAS FOR THE YEAR ENDING DECEMBER 31, 2027 CLASS : DOMESTIC RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fixed Costs Unit Cost Demand ($/kW of Class monthly Energy Customer Fuel...

AI summary This document presents a rate class disaggregation analysis for the domestic rate class as of December 31, 2027, detailing the rate base, variable and fixed costs, and unit costs across energy and demand categories.

RATE CLASS DISAGGREGATION ANALYSIS FOR THE YEAR ENDING DECEMBER 31, 2027 CLASS : SMALL GENERAL RATE BASE COSTS (Source Exh 6) (Source Exh. 3) Variable Fixed Unit Cost Fuel Operating Capital Return Total Total Cost Units Sold Demand Energy...

AI summary This document provides a rate class disaggregation analysis for the Small General rate class as of December 31, 2027. It includes details on rate base, costs, and unit costs, with breakdowns of variable and fixed costs, as well as energy and demand-related metrics.

89,972.5 (232) BUTU CAPACITY CREDIT 393.0 (233) OTHER OVERHEAD EXPENSES 7,886.5 6,978.0 908.6 System Planniing and ECI (234) CURRENT YEAR INCENTIVE PLAN PAYOUT 0 (235) DSM EXPENSES - Demand-related ATL Classes 923,250.7 923,250.7 0.0 (236)...

AI summary This document excerpt presents a detailed breakdown of financial and operational expenses, including capacity credit, overhead expenses, DSM expenses categorized by ATL classes, and depreciation and accretion for various energy generation sources such as steam, hydro, wind, and solar. It includes figures related to the Fuel Cost Recovery (FCR) deferral and grants in lieu of taxes.

NON-CONFIDENTIAL It is important to bear in mind that relative to the costs that would be incurred and ultimately recovered from customers to change the Company's proration methodology, the likely effect of proration on customers is small....

AI summary The document discusses the impact of proration methodology on customer bills when rate changes occur mid-billing period, using an example of a 900 kWh customer. It notes the small effect of proration and acknowledges that fuel and DSM costs are trued up later, reducing future recovery. The Company is exploring alternatives to prorating bills as part of a new billing system.

[37] The terms of the settlement agreement are set out in a schedule to the agreement and provide as follows: GRA Element Settlement Terms Securitization a) NS Power will make best efforts to finalize and apply prior to January 1, 2026 for...

AI summary The settlement agreement outlines terms related to securitization, ML transmission assets, and the EIFEL exemption. NS Power is required to finalize securitization by 2026, and the inclusion of certain transmission assets in the rate base depends on meeting specific criteria. If the EIFEL exemption is not enacted, a tax expense deferral is agreed upon for the 2026-2027 period.

[488] A summary of the formula components used by Concentric and Dr. Cleary is set out in the table below: DC F Concentric Cleary Dividend Yield 3.49% 5.29% [Calculated from [Calculated from Bloomberg] Morningstar] Multi-Stage 6.62% (Mean)...

AI summary The text outlines the formula components used by Concentric and Dr. Cleary in their models, including dividend yield, growth rates, and financial metrics. Concentric's model uses a multi-stage DCF approach with near-term, transitional, and long-term growth phases, while Dr. Cleary's model uses the DDM approach with different growth assumptions.

Demand Side Management Rider Demand side management costs are currently allocated as 75% to the cost of programs undertaken for the rate class and 25% to the system benefit of the programs. NS Power is proposing to remove the allocation to...

AI summary NS Power proposes to reallocate 100% of demand side management (DSM) program costs to the benefiting rate class, eliminating the current 25% allocation to system benefits. This change aims to shift cost responsibility entirely to the classes directly benefiting from DSM initiatives.

fund period for endof-term variances, which is expected to reduce the volatility in rate impacts of DSM expenditure reallocations and better reflect the multi-year nature of DSM planning and spending. [688] The proposed DCRR framework adds...

AI summary The proposed DCRR framework introduces a BA2 component to allocate DSM expenditure variances over four years, reducing rate volatility and aligning with COSS. It ensures 100% DSM cost allocation by class, reflecting multi-year planning and spending. NS Power's stance in Matter M12521 supports this approach.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The Demand Side Management Cost Recovery Rider applies a charge in cents per kilowatt-hour to the Tariff for the current rate year, in addition to the energy charge.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The Demand Side Management Cost Recovery Rider applies a charge in cents per kilowatt-hour to the Tariff for the current rate year, in addition to the energy charge.

DEMAND CHARGE per month per kilowatt of maximum demand Effective upon the date of the Board's Order $9.809 Effective January 1, 2027 $10.697 32 cents per kilowatt reduction in demand charge where the transformer was owned by the customer p...

AI summary The document outlines the demand charge rates effective upon the Board's Order and on January 1, 2027. It also includes a reduction in demand charge for customers who own transformers predating February 1, 1974, or under Special Condition (2).

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The Demand Side Management Cost Recovery Rider applies a charge in cents per kilowatt-hour to the Tariff for the current rate year, in addition to the energy charge.

11.2 Billing Unless NS Power directs otherwise, the RtR Customer shall be invoiced by the LRS and will pay the LRS for any charges or fees, inclusive of all applicable taxes, owing by the RtR Customer to NS Power under this Distribution Ta...

AI summary The text outlines billing procedures for RtR Customers under the Distribution Tariff, specifying that they are invoiced by the LRS and must pay all applicable charges, including Demand Side Management Cost Recovery Charges and Storm Cost Recovery Charges, among others. The RtR Customer also agrees not to hold NS Power liable for billing actions taken by the LRS.

DEMAND SIDE MANAGEMENT (DSM) COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shal...

AI summary The Demand Side Management Cost Recovery Rider introduces a charge in cents per kilowatt-hour, applicable to the Tariff for the current rate year, in addition to the energy charge.

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) The monthly amount computed under each of the rate schedules to which this DSM Cost Recovery Rider is applicable shall be increased or decreased by the DCRR at a class-specific rate per kil...

AI summary The document outlines the formula for calculating the Demand Side Management Cost Recovery Rider (DCRR), which adjusts the monthly amount under applicable rate schedules based on a class-specific rate per kilowatt hour of consumption.

BA = Balance Adjustment The BA is comprised of two components: - (1) BA1 = Annual Volume Variance Adjustment calculated for each rate class separately on a previously completed calendar year basis and is used to reconcile the difference be...

AI summary The Balance Adjustment (BA) consists of two components: BA1, which reconciles annual volume variance on a two-year lag, and BA2, which adjusts for discrepancies between approved DSM amounts and actual expenditures, applied over the next DSM term.

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

AI summary The Balance Adjustment (BA) is updated annually to reflect BA1 and at the end of each Approved DSM Term to reflect BA2. The NSEB-approved DCRR is applied to bills starting from the effective date of the change.

DSM Cost Allocation Method - Step 1 Allocate the class and participation benefits by directly assigning 100% of the DSM investment identified for each participating customer class. - Step 2 For NS Power bundled service customers, divide th...

AI summary The document outlines a five-step method for allocating Demand Side Management (DSM) costs among different customer classes. The process involves direct assignment, calculation based on electricity sales, direct billing for wholesale customers, annual adjustments, and final adjustments at the end of the DSM term.

Conditions Effective: January 1, 2026 - For bundled service customers, other than those who take service in the Wholesale Market (whether in whole or in part), this approach applies to classes as a whole (not to individual customers). - Fo...

AI summary The conditions outlined apply to bundled service customers, distinguishing between those in the Wholesale Market and others. The approach applies to classes as a whole for non-Wholesale Market customers and to individual customers for those in the Wholesale Market. It also applies to total Approved DSM costs.

the entirety of this process, customer representatives have been aided by their expert consultants. Relevant components of the GRA to which all Parties noted above have agreed include the following: • An overall average rate increase acros...

AI summary The document outlines agreed-upon components of the GRA, including rate increases, updated studies, retention of financial parameters, continuation of a storm cost recovery rider, amendments to the DSM rider, and plans for securitization of thermal assets. These measures are expected to impact customer rates and savings over the 2026-2027 period.

Comment Other than the changes to the DSM Rider, the GRA does not propose any changes to the design of NS Power's rates, riders, or credits. Given the foregoing and the support for the GRA outcomes, NS Power submits the issue of rate desig...

AI summary NS Power states that the GRA does not propose changes to rate design, and therefore, the issue of rate design does not require further evidence in the hearing. The GRA only includes changes to the DSM Rider.

The Fuel Adjustment Mechanism (FAM) and the Actual Adjustments (AA) or Balancing Adjustments (BA) is proposed to continue to operate in the normal course during 2026 and 2027, with new Base Cost of Fuel (BCF) amounts set for 2026 and 2027....

AI summary The document proposes the continuation of the Fuel Adjustment Mechanism (FAM) and Actual Adjustments (AA) or Balancing Adjustments (BA) during 2026 and 2027, with updated Base Cost of Fuel (BCF) amounts. It also suggests changes to the calculation method for the Demand Side Management Rider.

Request IR-143: - Reference: Exhibit N-3 GRA Direct Evidence, Section 13.5 DSM Rider - On page 82, NS Power stated: - NS Power is not proposing changes to the DSM rider amounts for 2026 or 2027. However, NS Power is proposing changes to ho...

AI summary NS Power is not proposing changes to the DSM rider amounts for 2026 or 2027 but is seeking to alter the Balance Adjustment (BA) calculation method. The request includes questions about illustrative examples, justification for the BA change, confirmation of DSM expenses, and whether specific DSM initiatives were requested from EOne.

3.5.1.6 Payment of Interest on Deferral Accounts [362] The payment of interest to NS Power on its deferral accounts is subject to s. 64AB of the Public Utilities Act . In its 2023-2024 GRA Decision, the Board concluded that it was appropri...

AI summary The Nova Scotia Utility and Review Board (NSUARB) determines interest rates on NS Power's deferral accounts using its Weighted Average Cost of Capital (WACC) under s. 64AB of the Public Utilities Act. This follows the 2023-2024 GRA Decision and a 2024 DCR Rider decision (M11912), with the Board planning a generic proceeding to further address s. 64AB issues. London Economics International LLC is engaged to prepare a report.

[488] A summary of the formula components used by Concentric and Dr. Cleary is set out in the table below: DC F Concentric Cleary Dividend Yield 3.49% 5.29% [Calculated from [Calculated from Bloomberg] Morningstar] Multi-Stage 6.62% (Mean)...

AI summary The text outlines the formula components used by Concentric and Dr. Cleary, including dividend yield, growth rates, and financial metrics. Concentric's multi-stage DCF model incorporates three phases of growth: near-term, transitional, and long-term, with growth rates derived from analyst forecasts and GDP projections.

Demand Side Management Rider Demand side management costs are currently allocated as 75% to the cost of programs undertaken for the rate class and 25% to the system benefit of the programs. NS Power is proposing to remove the allocation to...

AI summary NS Power proposes to reallocate 100% of demand side management (DSM) program costs to the benefiting rate class, eliminating the current 25% allocation to system benefits. This change aims to shift cost distribution from system-wide benefits to specific rate classes.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the current rate year as part of the Tariff.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the current rate year as part of the Tariff.

DSM COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shall apply, in addition to t...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the current rate year as part of the Tariff.

DEMAND CHARGE per month per kilovolt ampere of maximum demand Effective upon the date of the Board's Order $10.710 Effective January 1, 2027 $11.269 32 cents per kilovolt ampere reduction in demand charge where the transformer is owned by...

AI summary The document outlines the demand charge rates effective upon the Board's Order and on January 1, 2027, as well as a rebate of 32 cents per kilovolt ampere reduction in demand charge for customer-owned transformers.

11.2 Billing Unless NS Power directs otherwise, the RtR Customer shall be invoiced by the LRS and will pay the LRS for any charges or fees, inclusive of all applicable taxes, owing by the RtR Customer to NS Power under this Distribution Ta...

AI summary This section outlines the billing responsibilities of the RtR Customer under the Distribution Tariff, including charges for distribution system access, demand-side management, storm costs, and other approved items. The RtR Customer agrees to pay the LRS for these charges and waives claims against NS Power related to billing by the LRS.

DEMAND SIDE MANAGEMENT (DSM) COST RECOVERY RIDER The Demand Side Management Cost Recovery Charge (in cents per kilowatt-hour) applicable to the Tariff for the current rate year, shown in the Demand Side Management Cost Recovery Rider, shal...

AI summary The document outlines the application of the Demand Side Management Cost Recovery Charge, which is added to the energy charge in the Tariff for the current rate year.

DEMAND SIDE MANAGEMENT COST RECOVERY RIDER (DCRR) The monthly amount computed under each of the rate schedules to which this DSM Cost Recovery Rider is applicable shall be increased or decreased by the DCRR at a class-specific rate per kil...

AI summary The Demand Side Management Cost Recovery Rider (DCRR) adjusts monthly rates based on a formula involving PCR and BA, applied per kilowatt hour of consumption for specific classes of customers.

BA = Balance Adjustment The BA is comprised of two components: - (1) BA1 = Annual Volume Variance Adjustment calculated for each rate class separately on a previously completed calendar year basis and is used to reconcile the difference be...

AI summary The Balance Adjustment (BA) consists of two components: BA1, which reconciles revenue differences based on actual class load from two years prior, and BA2, which adjusts for discrepancies between approved DSM funding and actual expenditures, ensuring customers are charged or refunded accordingly.

DSM Cost Allocation Method - Step 1 Allocate the class and participation benefits by directly assigning 100% of the DSM investment identified for each participating customer class. - Step 2 For NS Power bundled service customers, divide th...

AI summary The document outlines a five-step method for allocating DSM costs among customer classes, including direct allocation, recovery based on electricity sales, and annual true-up adjustments as defined in Balance Adjustments 1 and 2.

Conditions Effective: January 1, 2026 - For bundled service customers, other than those who take service in the Wholesale Market (whether in whole or in part), this approach applies to classes as a whole (not to individual customers). - Fo...

AI summary The conditions outlined apply to bundled service customers and those in the Wholesale Market, specifying that the approach applies to classes as a whole or individual customers, respectively, and that it covers total Approved DSM costs.

3.2.18 NSP Owned Variable Production Costs Third party production bonuses and penalties for NSP owned power production.

AI summary The section discusses third-party production bonuses and penalties related to NSP owned power production, highlighting the mechanisms in place for incentivizing or penalizing production based on performance.

2 proposing to do securitization based on either the DDA 3 approach or by generation. So that's something that the 4 company is considering right now. 5 Q. So that would come forward with 6 the securitization rider? 7 (Willett) That's corr...

AI summary The discussion involves Nova Scotia Power (NSP) considering securitization based on the DDA approach or by generation, and the allocation of the DSM rider, with 75% allocated to program costs and 25% to system benefits.