P-2NSPI (UARB) IR-1 to IR-33; NSPI (Irving Oil) IR-1 to IR-7; NSPI (CBRM) IR-1 to IR-17 - Responses
107 passages
Nova Scotia Utility and Review Board IN THE MATTER OF The Public Utilities Act, R.S.N.S., 1989, c. 380, as amended - and - IN THE MATTER OF an Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The Nova Scotia Utility and Review Board is considering an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act, R.S.N.S., 1989, c. 380, as amended.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-1: The existing GRLF Rate appears to be promoting self-generation while the proposed Load Retention Rate is designed to discourage self generation and as such the two rates...
AI summary NSPI responds to a question about the potential conflict between the GRLF Rate and the proposed Load Retention Rate, stating that there is no conflict and that both rates serve the interest of all customers by supporting self-generation where appropriate.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The Nova Scotia Utility and Review Board is considering an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act. The proceeding involves regulatory approval for a rate related to load retention.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary Nova Scotia Power Incorporated has applied for approval of a Load Retention Rate under the Public Utilities Act. This proceeding involves regulatory approval for a rate that may impact how the utility retains load, potentially affecting rates and services.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-5: In Availability Clause 1 of NSPI's submission to this Hearing, it is stated that the load retention rate must not be less than necessary to make the customer in question...
AI summary NSPI responds to an information request regarding Availability Clause 1, which sets a minimum load retention rate to prevent customers from switching to alternative energy providers. The clause is discussed in the context of potential conflicts with the Canadian Competition Act Section 50(1), which prohibits discriminatory pricing practices. The response references the Public Utilities Act and the Load Retention Rate approval application.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-5: ( c) engages in a policy of selling products at prices unreasonably low, having the effect or tendency of substantially lessening competition or eliminating a competitor,...
AI summary NSPI responds to an information request from NSUARB regarding the load retention rate, asserting that it is consistent with the Competition Act's goal of maintaining competition and ensuring fair pricing. The response references the Public Utilities Act and an application for approval of the load retention rate.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Response IR-5: The differentiating factor is whether a customer has the facilities to receive alternate energy supply, which is not discriminatory from a pricing perspective. The custom...
AI summary NSPI responds to an information request regarding a load retention rate, stating that the rate does not discriminate based on geography and is not predatory. The rate is customer-specific and subject to approval by the UARB. NSPI argues that the rate is regulated conduct and does not affect competition.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Response IR-5: One important factor in assessing predatory pricing is a comparison between the price and the cost of the product sold. The proposed rate is not below costs; it will cove...
AI summary NSPI responds to an information request by NSUARB regarding predatory pricing, stating that the proposed rate covers marginal and fixed costs and does not intend to undercut competitors. The pricing mechanism aims to retain customer load beneficially for other NSPI customers and will be submitted to DARB for approval.
Question IR-13: Page 2, lines 16-17 - a) Please provide copies of all of the reports, studies and analyses related to the various strategies considered by NSPI to face the potential competition to be posed by the availability of gas in the...
AI summary The text requests NSPI to provide reports, studies, and analyses related to strategies for addressing potential competition from natural gas in its service territory, along with written comments made by NSPI and whether it considered offering discounts for long-term contracts.
Response IR-13: a) The strategy referred to in Lines 16-17 is NSPI' s strategy with respect to customers potentially opting to choose an alternate supply of electric energy. NSPI believes that a load retention rate offered on the fundament...
AI summary NSPI outlines its strategy for retaining customers who may opt for alternate energy suppliers, proposing a load retention rate as the best approach to address the issue.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary This document pertains to an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act. The proceeding involves regulatory approval related to utility rates and operations.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Response IR-13: NSPI' s broader strategy to address competition from natural gas is to manage costs, maintain rate stability, improve our customer service, and develop new products and...
AI summary NSPI outlines its strategy to address competition from natural gas by managing costs, maintaining rate stability, and improving customer service through new products and services. Since privatization in 1992, rates have increased only 4%, compared to 10% CPI. NSPI has introduced time-of-use rates, thermal storage units, and heat pumps, and established customer service teams to better meet customer needs.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-14: Page 2, lines 17-18 - a) Please provide the amounts of the exit fee(s) considered, if any. - b) Please provide the approach, data, calculations and work papers used in t...
AI summary NSPI responded to an information request from NSUARB regarding exit fees and ancillary services for self-generating customers. No exit fee was calculated, and ancillary services such as backup power may be required. NSPI would not provide these services for free.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary Nova Scotia Power Incorporated has applied for approval of a Load Retention Rate under the Public Utilities Act. The application is before the Nova Scotia Utility and Review Board.
AVAILABILITY Available for the sale of electricity to customers, including small power producers and cogenerators which are qualifying facilities as defined in the Public Utility Regulatory Policies Act of 1978. To qualify for this schedul...
AI summary The availability schedule outlines conditions for selling electricity to customers, including small power producers and cogenerators, in the Company's Maryland service territory. Customers must use alternative generation facilities not owned by the Company and meet specific operational and metering requirements.
TYPES OF SUPPLY Types of power supply available are Supplementary, Maintenance (Firm or Interruptible), and Standby (Firm or Interruptible). For the purposes of this schedule, "normal alternative generation" for the current billing period...
AI summary The document outlines the types of power supply available, including Supplementary, Maintenance (Firm or Interruptible), and Standby (Firm or Interruptible). It provides a method for determining 'normal alternative generation' based on billing periods and demand intervals.
ALTERNATIVE GENERATION SCHEDULE SCHEDULE "AGS" (Continued) TYPES OF SUPPLY (continued) SUPPLEMENTARY POWER is power that is used by the customer in addition to that normally produced by the alternative generation facilities. Supplementary...
AI summary The document outlines the definition and availability of Supplementary Power, Firm or Interruptible Maintenance Power, including constraints on availability, notification requirements, and procedures for customers. It was issued by Michael P. Morrell, Vice President, and accepted for filing by the Public Service Commission in 1998.
TYPES OF SUPPLY (continued) - (6) The Company shall not supply Maintenance Power in excess of the normal alternative generation for the billing period. - (7) During any period that Firm Maintenance Power is made available, the Maintenance...
AI summary The text outlines the rules for supplying Firm and Interruptible Standby Power by the Company, specifying conditions for availability, agreement capacities, and billing practices. It also defines when standby power is considered used and outlines the transition to Supplementary Power after usage limits are reached.
Obligations Interruptible Maintenance or interruptible Standby Power shall be interrupted when, in the sole judgment of the Company, any production, transmission, or distribution limitations exist. During an interruption period, the custom...
AI summary The document outlines the conditions under which interruptible maintenance or standby power may be interrupted by the Company during production, transmission, or distribution limitations. It specifies that the customer's load must be reduced to a defined capacity during such interruptions and defines the effective dates and filing details of the policy.
Demand Charge Firm standby Power First 100 Kilowatts of Standby Power Billing Demand or Less ............................................ $6.103 net per kilowatt Additional Kilowatts of Standby Power Billing Demand ...........................
AI summary The document outlines the demand charge rates for standby power in Nova Scotia, distinguishing between firm and interruptible standby power. Rates are specified per kilowatt and kilovar, with different rates for the first 100 kilowatts and additional kilowatts, and for reactive kilovoltampere demand exceeding 25% of the current kilowatt standby power billing demand.
ALTERNATIVE GENERATION SCHEDULE SCHEDULE "AGS" (Continued) MONTHLY RATE (Continued) Demand Charge (Continued) Firm or Interruptible Maintenance Power All Kilowatts of Maintenance Power Billing Demand ......$5.332 net per kilowatt All Kilov...
AI summary This document outlines the Alternative Generation Schedule (AGS) for electricity billing, including demand charges, energy charges, and fuel rates. It specifies billing procedures for maintenance and standby power and references regulatory orders and effective dates.
Power Demands (Continued) The demand for each period shall be the highest of: - (a) The maximum kilowatt demand created during the intervals in the period when no Maintenance Power or Standby Power is used, of if no such intervals exist in...
AI summary This document outlines the methodology for calculating power demand for billing periods, including the use of Maintenance Power, Standby Power, and Supplementary Power Demand. The rules are issued by Michael P. Morrell and became effective on November 18, 1998.
Power Billing Demands - (1) Supplementary Power Billing Demand shall be the higher of: - (a) The Supplementary Power Demand (if multiple Supplementary Power Demands are required due to the applicable standard rate schedule, they shall be c...
AI summary The document outlines the definitions and calculation methods for three types of power billing demands: Supplementary, Maintenance, and Standby. Each is determined based on specific criteria, such as minimum demand provisions or a percentage of agreement capacity.
DETERMINATION OF ENERGY USE - (1) Supplementary Energy Use shall be the lesser of: - (a) The average kilowatt demand during those portions of the billing period when no Maintenance Power or Standby Power is used, or the kilowatt portion of...
AI summary This document defines 'Supplementary Energy Use' as the lesser of two calculated values based on average kilowatt demand during periods without maintenance or standby power use. The determination was issued by Michael P. Morrell, Vice President, and became effective on November 18, 1998.
Authorized: October 15 1990 By: Effective: October 21 1990 Director of Rates No Supersedes Rate Designation ·G Docket No. E001/M-90-582 (Proposal submitted August 2, 1990)
AI summary This document is a regulatory proceeding related to rate designations and proposals submitted by Nova Scotia Power Incorporated on August 2, 1990, with an effective date of October 21, 1990, and authorization dated October 15, 1990.
ORIGINAL VOLUME NO. 8 ORIGINAL SHEET NO. 22.1 _R_A_T_E_D_E_S-IG_N_A_T-IO_N_:-·4,5(~. ·(~.)f CLASS OF SERVICE: COMPETITIVE RATE - LARGE POWER AND LIGHTING SERVICE AREA: ALL MINNESOTA SERVICE AREA - (5) T_he maximum rate reduction offered un...
AI summary This section outlines a competitive rate schedule for large power and lighting services, specifying that the maximum rate reduction cannot exceed the difference between the company's rate and the customer's cost for the lowest cost competitive energy supply.
Rules and Regulations: Service hereunder is subject to the provisions of the Company's Electric Service Standards. Authorized: October 15 1990 By: Director of Rates Effective: October 21 1990 No Supersedes Rate Designation Docket No. E001/...
AI summary This document outlines the rules and regulations governing electric service standards, with an effective date of October 21, 1990, and was authorized by the Director of Rates on October 15, 1990. It references a docket number and a proposal submission date.
3. Rate - a. For customers with generation facilities rated at more than 20 kW. - 1) Customer Charge Facilities rated between 20 kW and 200 kW: $9.75 per month. Facilities rated at 200 kW or greater: $19.50 per month.
AI summary This section outlines customer charges for customers with generation facilities rated above 20 kW. Facilities between 20 kW and 200 kW are charged $9.75 per month, while those rated 200 kW or greater are charged $19.50 per month.
The company shall pay for all quantities of electricity received from the customer's facilities during each billing period at the following rates: Per kWh Per kWh Voltage Level On-Peak Off-Peak Transmission $0.0362 $0.0158 Distribution $0....
AI summary The company is required to pay customers for electricity received at specified on-peak and off-peak rates based on voltage level. Customers dissatisfied with these rates may negotiate facility-specific rates, subject to review by the Public Service Commission of Wisconsin.
- c. The company will supply standby, maintenance, or supplemental energy to the customer under the retail rates and rules for which the customer qualifies. In the case of maintenance energy, the demand charges will be prorated for the act...
AI summary The document outlines the company's obligation to provide standby, maintenance, or supplemental energy to customers under applicable retail rates and rules. It also mentions the proration of demand charges for maintenance energy when coordinated with the company's outages.
11. Service Option Customers with generation facilities connected in parallel with Company facilities have the option to not be served under Paragraph 3c. of this schedule. In such case, meters used to measure energy and/or demand usage fr...
AI summary Customers with parallel generation facilities may opt out of service under Paragraph 3c, with meters ratcheted to prevent reverse flow measurement. A dated letter and reference to a document are included.
PRICING OPTIONS: Pricing will be determined on a customer by customer basis. The final arrangements between the Company and Customer will be determined through negotiations and shall be included in the Contract.
AI summary Pricing arrangements between the Company and Customer will be determined on a customer-by-customer basis through negotiations, with final agreements included in the Contract.
CHANGE IN RA TES AND CHARGES: Unless specifically stated within the Contract, energy sales under this Service Classification shall be subject to the same riders as the Customer's controlling rate schedule. These riders include, Rider l (Fu...
AI summary The document outlines that energy sales under the Service Classification are subject to specific rate riders, including Fuel Rate, Purchased Capacity Surcharge, Conservation Surcharge, Emergency Generation, and Curtailable Service. Future PSC-approved non-base rate surcharges will also apply.
The Company shall notify the Maryland Public Service Commission at least 30 days prior to the effective date of the Contract. The notification will include a confidential informational document. ELECTRIC RATE SCHEDULE CENTRAL MAINE POWER C...
AI summary The Company is required to notify the Maryland Public Service Commission at least 30 days before the Contract's effective date, including a confidential informational document. The text also references an electric rate schedule and a docket number.
RATES Customers receiving electrical service under this tariff will be charged the following components: RATES (continued) Access Charge Energy Charges - Winter and Non-Winter Reactive Demand Charges The Winter period includes the billing...
AI summary The document outlines the rate structure for electrical service, including access charges, energy charges divided into winter and non-winter periods, and reactive demand charges. Access charges vary based on the customer’s expected maximum load and voltage level, with annual reviews by CMP.
RATES (continued) pricing flexibility criteria as described in Attachment F of the Alternative Rate Plan (ARP). The energy rates will be adjusted annually, with new rates effective October 1, based on an index of the appropriate alternativ...
AI summary The document outlines the pricing flexibility criteria for energy rates under the Alternative Rate Plan (ARP), including annual adjustments based on an alternative fuel price index, bandwidth limitations on rate changes, and reactive demand charges for different customer classes.
RATE DIESEL DE=F-'E=RRA~ L~RA~T=E~ · DIESEL GENERATION DEFERRAL ENERGY SERVICE :rgie~tive Date:l?or meters read-on and after March 20, :Cu s A. M~ldner Docket No. 97-605 \i ice President
AI summary The document discusses a rate diesel deferral energy service proceeding, referencing a docket number and a date related to meter readings. It appears to be part of a regulatory process involving energy services and rates.
AVAILABILITY Service under this rate is available for the purpose of operating smvmill and associated manufacturing equipment, using all-electric saws. For the purposes of this rate, sa\vmills are considered to be businesses in which logs...
AI summary This rate is available for specific industrial uses, including sawmills, asphalt and concrete production, and iron foundries. Service may be separately metered, and customers must enter into a Customer Service Agreement.
Access Charge: Customers receiving electric energy under this rate schedule will pay a fixed monthly charge, which is detem1ined by multiplying the an10unts below by the customer's expected maximum load \vhich will be specified in the Cust...
AI summary The access charge for electric customers is determined based on their expected maximum load, with different rates for customers under and over 20 kW, and different voltage levels. Seasonal customers have a weighted average charge, and CMP reviews these charges annually.
RATE DIESEL DEFERRAL RATE DIESEL GENERATION DEFERRAL ENERGY SERVICE Effective Date: For meters read on and after October 1, 1999 Docket No. 99-608 Raymond W. Hepper General Counsel
AI summary This document outlines the Rate Diesel Deferral and Rate Diesel Generation Deferral Energy Service, effective from October 1, 1999, under Docket No. 99-608. It is managed by Raymond W. Hepper, General Counsel.
Energy Charge: The energy charge per kilowatt-hour for all kilowatt-hours applicable under this rate schedule are $0.062 during the billing periods ending in the months of December, January, February, and March and $0.052 during the billin...
AI summary The energy charge per kilowatt-hour is set at $0.062 during certain months and $0.052 during others. Rates are adjusted annually based on diesel fuel prices from The Wall Street Journal, with adjustments limited by a bandwidth to prevent excessive changes, especially in the early years.
Minimum Charge: The minimum monthly charge for all customers taking service Central Maine Power Company: Elect... Schedule - Rate DDR- Page 135.10 http://www.cmpco.com/services/rates/schedules/ddrl35.10.htm' under this rate schedule, inclu...
AI summary The minimum monthly charge for all customers under this rate schedule, including seasonal customers, is defined as the access charge. The Central Maine Power Company's rate schedule is referenced.
CONTRACT A Customer Service Agreement shall be required for all customers. The Agreement shall offer service consistent with this tariff and shall specify the expected maximum load level( s) to be used to establish the initial access charg...
AI summary A Customer Service Agreement is required for all customers, specifying service terms, expected maximum load levels, and initial access charges. The agreement cannot extend past 2/29/2000 without mutual consent.
Other Facilities: Any other facilities required for service under this rate schedule in excess of those needed for service under the applicable general service rate schedule shall either be furnished, owned and maintained by the customer o...
AI summary The text outlines the responsibility for providing, owning, and maintaining additional facilities required for service under a specific rate schedule. Customers may either provide these facilities themselves or CMP will provide them, with an additional monthly charge applied as per Section 13 of the Terms and Conditions.
ELIGIBILITY. A customer seeking a contract hereunder shall make written application to the Company which shall include an affidavit stating the customer's intent to bypass the Company's electric service system absent service hereunder. The...
AI summary The eligibility criteria for a customer seeking a contract under this rate require a written application with an affidavit stating intent to bypass the Company's electric service system, along with evidence of competitive bids, investment requirements, and ability to bypass. The Company retains sole discretion in determining eligibility and may withhold service.
ELIGIBLE LOAD. For a customer entering into an initial Rate CS contract. service hereunder shall be available only to existing load, which, for purposes of this rate, is defined as the customer's highest Maximum Demand for the calendar yea...
AI summary Eligible load under Rate CS is defined as the customer's highest Maximum Demand in the prior calendar year. For recontracting customers, service is limited to the volume of eligible load under the prior contract. New or expanded load is not eligible for service under this rate.
ORDER APPROVING SPECIAL CONTRACT On December 4, 1995, Consumers Power Company (Consumers) filed an application for approval of a special contract for the supply of retail electric service to The Upjohn Company (Upjohn). Consumers says that...
AI summary Consumers Power Company applied for approval of a special contract to supply electric service to The Upjohn Company, citing Upjohn's large energy demand and competitive pressures. Consumers claims that reducing subsidies and implementing customer-specific pricing initiatives are necessary to remain competitive, and notes that similar contracts have been approved for other major manufacturers.
APPLICABILITY: This rate is applicable to all commercial and industrial customers of El Paso Electric Company ("Company") that have taken service from the Company for a period of at least twelve (12) consecutive months, and have a minimum...
AI summary This rate applies to commercial and industrial customers of El Paso Electric Company who have been served for at least 12 consecutive months and have a minimum monthly demand of 1,500 KW.
MONTHLY RATE: The Company may enter into negotiations to establish a lower rate not less than the Company's incremental cost of power and energy as estimated over the term of the contract. Sufficient documentation of the cost estimates use...
AI summary The document outlines the conditions under which the Company may negotiate a lower monthly rate, subject to the New Mexico Public Utility Commission's approval. The rate must not be less than the Company's incremental cost of providing service and must be reviewed annually. The agreement is governed by a contract with a maximum initial term of three years.
EL PASO ELECTRIC COMPANY Continuation of Original Rate No. 30 Load Retention Rate Page 2 of 2 contracted rate, the Company will adjust thi:: charge to be above or equal to the incremental cost. ·
AI summary The document discusses the adjustment of charges by El Paso Electric Company to ensure they are above or equal to the incremental cost under the continuation of Original Rate No. 30 Load Retention Rate.
TERMS AND CONDITlONS: nd Regulations apply to service under this rate. Advice Notice No. 17S Signature/Title L · /}/.;; 5 ~ IJ'U:J-P? Assistant Vice President b) a second amount is calculated as follows:
AI summary This section outlines the terms and conditions of a service agreement, referencing a regulation and an advice notice number. It includes a signature line with a title and a calculation method for a second amount.
Application 163 The Load Retention Rate applies to a contract belonging to an industrial customer which, in accordance with the Rates Bylaw in effect, is subject to Rate Las of the date when said customer obtains the Load Retention Rate or...
AI summary Application 163 discusses the Load Retention Rate for an industrial customer's contract, which is subject to Rate L as per the Rates Bylaw. The rate applies either when the customer obtains the Load Retention Rate or if they were subject to Rate L in the three years before the Bylaw's effective date.
Definitions 164 In this Division, the following terms are defined as follows: "collaborator": Any physical or moral person other than a supplier, including financial institutions, supplying items defined as being among the variable costs o...
AI summary This section defines key terms used in the regulatory proceeding, including 'collaborator,' 'reference period,' 'supplier,' and 'variable costs.' It clarifies that electricity costs are excluded from variable costs when applying the Load Retention Rate.
Eligibility 166 A customer, to be eligible for the Load Retention Rate, must meet the conditions stipulated in Section 165 as well as the following: - a) the customer must demonstrate that it is experiencing financial difficulties entailin...
AI summary To be eligible for the Load Retention Rate, customers must demonstrate financial difficulties, non-reimbursable reductions from other suppliers, and plans to improve profitability. Hydro-Québec reserves the right to audit information and may approve the rate at the start of the consumption period or one of the next three.
b) Second and last application The Load Retention Rate may once again be applied to the same contract for another 12 consumption periods, consecutive or not to the first 12, but beginning no later than 12 months after the end of the first...
AI summary The Load Retention Rate can be reapplied to the same contract for another 12 consumption periods, provided the customer submits a new written application to Hydro-Québec and remains eligible under Sections 165 and 166. The Rate will apply again as outlined in Sections 170 and 171.
Determination of the billing coefficient 169 for first application The billing coefficient is determined as follows for the first application: - a) the relative importance of each category of variable costs for the reference period accordi...
AI summary The billing coefficient 169 for the first application is calculated through a multi-step process involving the determination of variable cost percentages, their reduction by suppliers, and weighting based on duration and units. The final coefficient is obtained by subtracting the calculated result from the number (l).
Determination of the billing 170 coefficient for second and last application The billing coefficient is determined as follows for the second and last application: - a) the relative importance of each category of variable costs for the refe...
AI summary The document outlines the detailed process for determining the billing coefficient for the second and last application, involving multiple steps that calculate percentages based on variable costs, reductions, and time periods, ensuring the total does not exceed the first application's total.
Object 173 Hydro-Quebec shall reimburse the municipality the difference between the customer's normal Rate L bill and the bill resulting from the application of the load Retention Rate set forth in Subdivision 1, for eligible contracts.
AI summary Hydro-Quebec is required to reimburse the municipality for the difference between the customer's normal rate bill and the bill calculated using the load retention rate for eligible contracts.
Terms and conditions of application 174 The reimbursement mentioned in Section 173 shall be subject to the following conditions: - a) the customer of the municipality shall advise the latter in writing as stipulated in Section 165 and prov...
AI summary The reimbursement under Section 174 is conditional on the customer informing the municipality in writing, the municipality submitting the application to Hydro-Quebec, and Hydro-Quebec determining eligibility and reimbursing the municipality for the difference between the normal rate and the Load Retention Rate bill.
CONTRACT Service under this Riqer re,qt1fre!?.a contract betwe~n th~ Customer and the Company. The Company will negotiate with the Customer the specific terms of the Contract which shall provide for service by the Company of all the altern...
AI summary This document outlines a contract between a Customer and the Company for the provision of alternative electric power services over a period of up to five years, with specific terms to be negotiated.
DESCRIPTION The Load Retention and Expansion Price (LREP) provides a mechanism that allows Hydro to respond with a negotiated price in situations where Hydro faces competition from lower-cost energy suppliers and where such negotiations co...
AI summary The Load Retention and Expansion Price (LREP) is a mechanism that allows Hydro to negotiate prices in response to competition from lower-cost energy suppliers, influencing customer decisions on energy use.
LOAD RETENTION AND EXPANSION - Allows for electricity price negotiations where load would be at risk with new or existing direct industrial customers of Ontario Hydro or large customers of Hydrosupplied MEUs. - Process: - Customer prepares...
AI summary The Load Retention and Expansion (LREP) process allows for electricity price negotiations with industrial customers at risk of losing load due to factors like relocation, fuel switching, or expansion. The process involves preparing a business case, third-party review, and price negotiation.
PRICING Any negotiated LREP will apply only to that portion of the load demonstrated to be at risk. After all information provided by the customer has been considered, prices will be negotiated on an individual basis and be subject to the...
AI summary The document outlines guidelines for negotiated LREP pricing, which applies only to load at risk. Discounts must meet minimum price limits and cannot reduce bills below minimum billing provisions. Capital contributions are based on net revenue from customers taking power under this option.
(D) Indicates Decrease GS-3 LP-4 LP-5 Intangible Transition Charge $0.357/KW $0.386/KW $0.415/KW (Effective 8-10-99 through 12-31-99) 0.177<1:/KWH 0.192C/KWH 0.206<1:/KWH Intangible Transition Charge $0.373/KW $0.415/KW $0.448/KW (Effectiv...
AI summary The document outlines changes to the Intangible Transition Charge over various periods and introduces billing adjustments for new customers, including a reduction of 1 cent per kilowatt-hour for usage exceeding 400 hours per month for Qualifying Service locations.
Issued: August 5, 1999 Effective: August 10, 1999 GS-3 LP-4 LP-5 Intangible Transition Charge (Effective 8-10-99 through 12-31-99) 0.177C/KWH 0.192(1:/KWH 0.206():/KWH Intangible Transition Charge (Effective 1-1-00 through 12-31-00) 0.187C...
AI summary The document outlines the Intangible Transition Charge rates for different service classes (GS-3, LP-4, LP-5) from August 1999 through December 2009. The rates decrease over time, reaching zero for all classes by December 2009.
PURPOSE This rider provides competitive rates to existing and new commercial and industrial customers served under Rate Schedules LP-5, LP-6, and IS-T who can demonstrate that they have a viable competitive alternative to purchasing electr...
AI summary This rate rider offers competitive rates to commercial and industrial customers who have viable alternatives to purchasing electric service from the Company and intend to select those alternatives, potentially to the detriment of the Company and its ratepayers.
GENERAL CONDITIONS - 1. The customer must demonstrate that it has a viable competitive alternative to service under Rate Schedule LP-5, LP-6, or IS-T to be eligible for this rider. The customer must provide written information, satisfactor...
AI summary The general conditions outline the process for customers seeking competitive rates under Rate Schedule LP-5, LP-6, or IS-T. Customers must prove they have a viable alternative, provide documentation, and demonstrate financial capability. The company retains sole discretion in determining appropriateness and setting rates.
APPLICABILITY Applicable to existing customers with demands of at least 200 kW and not more than 4,000 kW with a Standard Industrial Classification Code of 200 through 3999 (Manufacturing), or 781 (Motion Picture Production and Allied Serv...
AI summary This document outlines the applicability of a specific service schedule to customers in California with certain demand levels and industry classifications. It specifies eligibility criteria, excludes certain customers, and sets a limit on total eligible load. The schedule may be closed if not extended by a specified date or when the load limit is reached.
RATES Unless provided herein, or in the Retention Economic Development Rate Agreement, all charges and provisions of the customer's Otherwise Applicable Tariff shall apply, except that the customer's energy and demand charges shall be subj...
AI summary The text outlines the application of customer tariffs with specific discounts on energy and demand charges, except where provided in the Retention Economic Development Rate Agreement. It also mentions a senior vice president, indicating potential involvement in rate-related decisions.
Revised Cal. PUC Sheet No. 23812-E Cancelling Original Cal. PUC Sheet No. 20645-E RATES (Continued) RETENTION ECONOMIC Schedule REDR RETENTION ECONOMIC DEVELOPMENT RATE (Continued) Year 1 Year 2 Year 3 Year 4 Year 5 Year 6 Year 7 25% 20% 1...
AI summary This document outlines a revised rate schedule that includes a retention economic development rate with decreasing discounts over seven years. The discount excludes specific surcharges and fees, as outlined in the Preliminary Statement and Part O, Section 5.
SPECIAL CONDITIONS - Otherwise Applicable Tariff. The customer's regularly filed rate schedule under which service is rendered. - 2. Agreement: The customer must sign the Retention Economic Development Rate Agreement in order to take servi...
AI summary This document outlines special conditions for a customer's service under a specific rate schedule, including the requirement to sign a Retention Economic Development Rate Agreement, an affidavit, and a commitment to maintain a minimum load for seven years.
SECTION A. Economic Development/Incentive Rates Economic development/incentive utility rates are intended to stimulate economic activity (job creation and capital investment). By reducing a participating customer's overall utility costs, t...
AI summary Economic development/incentive utility rates aim to boost economic activity by reducing customer utility costs, improving system efficiency, and spreading fixed costs over a broader customer base. Illinois allows such rates for both new and existing load, with discounts for existing customers only applying to load additions.
No Response 1 No Yes 39 11 For what utilities are such rates offered? (Illinois - 2. ·· Electric Only 15 Gas Only 5 Both 14 3. What rate mechanisms are available to do so? (Illinois - Tariffs Only 6 Special Contracts Only 3 4. fixed or fle...
AI summary The text discusses questions related to economic development/incentive rates, including for which utilities such rates are offered, available rate mechanisms, whether they are fixed or flexible, applicable load, and responsibilities for revenue shortfalls during rate cases. It includes responses from stakeholders and references to the Illinois Commission.
8. Are Impacts of such rates tracked? (Illinois - Yes) Yes 21 No 13 No Response 17 9. Identify Commission considerations utilized to justify such rates. (Illinois - Promote Jobs, Increase utilization of existing resources, Encourage expans...
AI summary The document presents responses to questions about rate impacts and justifications, with Illinois indicating that impacts are tracked and that considerations such as job creation and increasing utility plant utilization were used to justify rates.
Expansion of Existing Industry 21 No Response 12 Table 1 States Offering E∞nomic Development Rates State E∞nomic Development Rate offered Applicable Industries Rate Mechanism Rate Type If Tariffs Allowed Applicable Load Rates Exceed MC Rat...
AI summary The document presents a table summarizing states offering economic development rates, including details on applicable industries, rate mechanisms, types of rates, load applicability, and impacts assessed. Illinois is highlighted with specific data on rate mechanisms and impacts. Other states like Alabama, Arizona, and Arkansas are also listed with similar information.
tomers. Illinois is 1 of 29 states (57 percent) in which load retention rates are offered in the gas industry and 1 of 25 states ( 49 percent) in which such rates are offered in the electric industry. The following summarizes responses mad...
AI summary The text discusses load retention rates in Illinois, comparing them to other states. Illinois allows both gas and electric utilities to offer these rates through special contracts and tariffs, with fixed or flexible options. The Commission requires that revenues from load discounts meet or exceed marginal costs and determines responsibility for revenue shortfalls during rate cases. However, impacts of these rates are not tracked.
Although not tracked as extensively as economic development/incentive rates, selected information on load retention rates is monitored for use in evaluating such proposals. Table 3 States Offering Load Retention Rates State Load Retention...
AI summary The text discusses load retention rates offered by various states, focusing on their mechanisms, applicable industries, and impacts assessed. It highlights states like Illinois, Alabama, Arizona, Arkansas, and California, with details on rate types, treatment, and justification.
to year-round firm service or service during peak periods. Off-peak rates help reduce customers' energy costs in proportion to the amount of load consumed during off-peak times. In Illinois, off-peak periods for electric utilities are defi...
AI summary The text discusses economic development related rates, including off-peak and real-time rates, and how they are implemented in Illinois. It outlines that Illinois permits utilities to offer such rates, and provides statistics on the types of utilities that offer them and the rate types available.
Enhance the competitiveness of a specific industry 11 Increase the efficiency of utility plant utilization 32 Other 13 No Response 14 The same of the same of the same of the same of the same of the same of the same of the same of the same...
AI summary The text contains a heading and a table with fragmented and repetitive entries, including mentions of rate mechanisms and impacts assessed. The content appears to be related to regulatory proceedings and utility rate structures, though it is incomplete and lacks clear context.
SECTION D. Other Economic Development Related Policies There are several utility commission policies that have economic development implications. Two of the more popular economic development related topics in the electric industry are comp...
AI summary The section discusses economic development policies related to competitive bidding and retail wheeling in the electric industry. Competitive bidding involves utilities soliciting bids from power suppliers, while retail wheeling allows power transmission over facilities not owned by the generator. Illinois is addressing competitive bidding through a rulemaking process, and a Commission Task Force is exploring retail wheeling implications.
SECTION E. Comparison With Midwestern States In the contest among states to retain existing business and attract new businesses, accessibility to low cost energy can be a significant factor in determining the relative competitiveness of on...
AI summary This section discusses how utility rate-related factors, such as pricing flexibility, depreciation acceleration, and obligations to serve, influence a state's competitiveness in attracting businesses. It also highlights the importance of considering other state actions, such as market entry mechanisms and utility costs, when comparing states, particularly in the midwestern region.
Availability of Economic Development Rates For Competing States Table 7 State Rate Offered Industry Rate Treatment Illinois YES ELECTRIC, GAS RATE PAYERS Indiana YES ELECTRIC SHAREHOLDERS Michigan YES ELECTRIC,GAS RATE PAYERS Ohio YES ELEC...
AI summary The document presents tables comparing the availability of economic development and load retention rates across several U.S. states, highlighting differences in rate treatment for electric and gas industries. The tables include states such as Illinois, Indiana, Michigan, Ohio, and Wisconsin, with varying approaches to rate offerings and industry coverage.
Other ECONOMIC DEVELOPMENT QUESTIONNAIRE Section A: Economic Development/Incentive Rates - discounted utility rates offered for, a) significant load additions by existing customers, and/or b) load additions created by customers new to the...
AI summary The questionnaire asks whether utilities are allowed to offer economic development/incentive rates, including the types of utilities, rate mechanisms, load applicability, cost considerations, and how impacts are tracked. It also explores how such rates are treated during rate cases and the considerations used to justify them.
ECONOMIC DEVELOPMENT QUESTIONNAIRE Are utilities allowed to offer other economic development related rates? Yes If yes, what types? Please mark th e appropriate response (No te: more than one item p er question can be marked if necessar Re...
AI summary The document discusses whether utilities are allowed to offer economic development-related rates, including real-time rates and special contracts, and explores the mechanisms, cost considerations, and regulatory monitoring associated with such rates.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-23: Please explain the reasons for excluding the following provisions from the Proposed Load Retention Rate filed on December 6, 1999 which were included in the proposed Loa...
AI summary NSPI explains the exclusion of certain provisions from the Proposed Load Retention Rate filed on December 6, 1999, compared to a prior submission. The excluded provisions relate to customer options, procedures for special conditions, cost determination, benefit evaluation, and UARB approval requirements.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Response IR-23 e) Item ( 12) was removed from Attachment A, which is the procedure to be followed to determine the proposed load retention rate, and has been reflected in Item (3) of th...
AI summary NSPI responded to an information request from the NSUARB regarding the removal of Item (12) from Attachment A and its inclusion in Item (3) of the Special Conditions of the December 61 submission, noting that the UARB has final approval of all proposed rates.
Full Range of Evaluation Criteria PROSCREEN II provides a full range of evaluation criteria so that every aspect of a plan can be assessed: RATES Average Cass Prices - Base and Fuel Class Rate Increases - Base and Fuel ECONOMICS Present Wo...
AI summary PROSCREEN II offers a comprehensive set of evaluation criteria for assessing energy plans, covering rates, economics, reliability, financial integrity, customer impact, and societal and shareholder considerations. Key aspects include revenue requirements, cost assessments, reliability metrics, financial ratios, and stakeholder impacts.
Introduction The Financial Reporting and Analysis (FIR) Module is designed to combine results from the Load Forecast Adjustment (LF A) Module, the Generation and Fuel (GAF) Module, and the Capital Expenditure and Recovery (CER) Module, wit...
AI summary The Financial Reporting and Analysis (FIR) Module integrates data from multiple modules to generate financial reports and analyze the impact of various factors on company financial operations, including construction programs, capital market conditions, tax law changes, and rate adjustments.
Regulatory Lag Once the desired financial condition and rate of return is reached, the FIR Module considers the impact of regulatory lag on the utility's revenues. Regulatory lag occurs when the test period used to determine utility rates...
AI summary Regulatory lag refers to the delay between the test period used to determine utility rates and the period when those rates are actually implemented. This delay can affect the utility's revenues by reducing the rate increase awarded, depending on inputs such as minimum rate increases, inflation caps, and required increases. The impact of regulatory lag is factored into financial statements and automatic financing calculations.
Marginal Cost Rate Determination Traditional rate determination determines total revenue requirements using accounting information and then functionalizes, classifies and allocates historical embedded costs. The marginal cost methodology a...
AI summary The document compares traditional rate determination with the marginal cost methodology. Both methods use accounting information to determine total revenue requirements, but they differ in how revenues are allocated across rate classes. The marginal cost approach calculates revenues based on energy, demand, or customer-specific marginal costs, while the traditional method allocates historical embedded costs.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary This document pertains to an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. It outlines the regulatory proceeding initiated by the utility company.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-26: Please provide a copy of the latest short run and long run marginal cost studies conducted by or on behalf of NSPI. Response IR-26: The most recent marginal costs were d...
AI summary NSPI responded to an information request by providing marginal cost studies conducted in 1994/95, which were included in the IRP Report IR-R2. Tables 1 and 2 from the report summarize the marginal energy costs, along with explanations of their development.
($/MWH) WINTER F PERIOD NON-WINTER PERIOD YEAR AVERAGE ALL HOURS ON-PEAK OFF-PEAK ON-PEAK OFF-PEAK 1996 $26.85 $31.98 $26.20 $27.39 $24.65 1997 27.57 33.17 27.08 28.05 25.18 1998 28.71 34.96 28.23 29.18 26.09 1999 30.57 37.25 29.29 32.03 2...
AI summary This table presents historical average electricity rates in Nova Scotia from 1996 to 2018, distinguishing between winter and non-winter periods, and on-peak and off-peak hours. The data shows a general upward trend in rates over time, with significant fluctuations in certain years.
RESPONSE TO INFORMATION REQUEST TO: NSUARB FROM: NSPI Question IR-29: Page 4 of the Report mentions about deregulation and separation of generation and retail supply. - a) Please describe how the proposed Load Retention rate is in conforma...
AI summary The response to IR-29 explains that the Load Retention rate is discussed in the context of potential deregulation and unbundling of services, though this has not yet occurred in Nova Scotia. The document references the Public Utilities Act and mentions that existing rates may need revision if deregulation proceeds.
"REVISED" Question ffi-30: Page 14 of the Report mentions about NSPI's direct sales to Quebec, Maine and Maryland. - a) Please provide the amounts of power sales in 1998 - b) Please provide all the cost/benefit analysis of making sales to...
AI summary The document addresses a question regarding NSPI's power sales in 1998 and requests a cost/benefit analysis of selling power to self-generation at Load Retention rates versus selling in the wholesale market. The response refers to Table UARB-IR-30-A for the amounts of power sales in 1998.
NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The document pertains to an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. This proceeding is part of a regulatory process involving utility rate approvals.
"REVISED" Response IR-30: b) NSPI interprets this question to mean "How does the benefit of selling power at load retention rates compare to the benefit of selling power in the export market?" NSPI does not believe that the current export...
AI summary NSPI argues that the export market cannot replace the loss of large customer loads, as energy sales in the export market are limited and represent less than 2% of NSPI's total energy production in 1998. The discussion pertains to the comparison of revenue from load retention rates versus export market sales.
Table UARB-IR-31-D Year Off System Sales (MWh) Off System Revenue $ 2000 300,000 7,800,000 2001 300,000 7,800,000 2002 300,000 7,800,000 2003 300,000 7,800,000 2004 300,000 7,800,000 2005 300,000 7,800,000 NOTE: For competitive reasons in...
AI summary The table shows Off System Sales (MWh) and Off System Revenue ($) from 2000 to 2005, with consistent values across all years. A note explains that NSPI has excluded net revenue for competitive reasons when dealing with marketers.
NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATIER OF: The Public Utilities Act, RS.N.S., 1989, c.380 as amended IN THE MATIER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary This document pertains to an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. The proceeding involves regulatory oversight of utility rates and compliance with relevant legislation.
RESPONSE TO INFORMATION REQUEST TO: IRVING OIL LIMITED FROM: NSPI Question 4: Reference: Proposed load retention rate availability condition ( 4). Please explain the rationale for not making this rate available to new load. Response 4: The...
AI summary NSPI explains that the Load Retention Rate is intended for existing customers and not new load, as other rates are available to encourage new load, including the Industrial Expansion Interruptible Rate, Time-of Day Expansion Rate, and Surplus Power Interruptible Rate.
RESPONSE TO INFORMATION REQUEST TO: IRVING OIL LIMITED FROM: NSPI Response S: - b) It is theoretically possible that two customers ofNSPI with identical energy requirements could receive energy under different prices, terms and conditions....
AI summary NSPI explains that different customers with identical energy needs may face different pricing and terms due to varying technical and economic conditions, which is considered reasonable and not discriminatory. The load retention rate is based on the cost of alternate supply, including standby power options.
"REVISED" Question 7: Reference 3) 1998 Nova Scotia Power Annual Report, page 16: "Nova Scotia is building its electric utility business to become more competitive. In July, the National Energy Board approved the company's export license....
AI summary The document asks Nova Scotia Power Inc. (NSPI) about its exploration of replacing lost customer loads through export sales, details on 1999 electricity exports, financial statements, and whether NSPI has considered shutting down uneconomic generating facilities to benefit other customers.
"RE VISED" Response 7: b) Table Irving-7B provides the export sales destination, energy and revenue on a month basis for calendar year 1999.
AI summary Table Irving-7B details monthly export sales destinations, energy, and revenue for the year 1999.
millions of da/fars 1999 199S Assets Property, plant and equipment S2.2832 $2,266.1 Construction work in Qrogress 49.9 30.5 2,333.l 2,296.6 Deferred charges 330.6 363.1 Investment in Maritimes & Northeast Pipeline 50.3 Current assets 169.6...
AI summary The text presents a table with financial figures for 1999 and 199S, including assets, liabilities, and equity details. It also includes a reference to 'NS Power Holdings' Inc., likely a key entity in the proceeding.
millions of dollars 1999 1998 Operating activities: Net earnings adjusted for non-cash items S183.4 $172.2 Change in OQerating working caQital (66.8) (33.1) Net cash provided by operating activities 116.6 139.1 Net cash provided by financi...
AI summary The text presents a table showing financial data for two years, including net earnings adjusted for non-cash items, changes in operating working capital, and cash flow from operating, financing, and investing activities. It also includes dividends and changes in the cash position.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The Nova Scotia Utility and Review Board is considering an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act. This proceeding involves regulatory approval for a rate that may impact how the utility manages load retention.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The document pertains to an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act, R.S.N.S., 1989, c.380 as amended.
P-3NSPI (Sempra) IR-1 to IR-14
30 passages
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary This document pertains to an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. It outlines the regulatory proceeding initiated by the utility company.
RESPONSE TO INFORMATION REQUEST TO: SEMPRA ATLANTIC GAS INC. FROM: NSPI Question IR-1: Application by Nova Scotia Power Inc. ("NSPI") for a Load Retention Rate. NSPI proposes a Load Retention Rate to retain existing customers it fears may...
AI summary NSPI is proposing a Load Retention Rate to retain customers who might switch to natural gas. The response indicates that NSPI is not currently planning any future expansion of its power generation capability and does not foresee a need to expand to meet future demand.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary This document pertains to an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. The application is part of a regulatory proceeding before the Nova Scotia Utility and Review Board.
IN THE MATTER·OF THE'PUBLIC UTILITIES ACT R.S.N.S., 1989, c. 380, as amended - and - IN THE MATTER OF an Application of Nova Scotia .Power Incorporated for approval of certain revisions to its Rates, Charges, and Regulations Prepared Testi...
AI summary This document is a prepared testimony from John H. Chamberlin on behalf of the Nova Scotia Utility and Review Board, submitted in a proceeding under the Public Utilities Act regarding Nova Scotia Power Incorporated's application for approval of revisions to its rates, charges, and regulations.
I. INTRODUCTION 1 2 3 In 1993 I was retained by the Nova Scotia Utility and Review Board (the Board) to 4 provide testimony on cost of service and pricing issues related to Nova Scotia Power, 5 Inc. (NSPI). In that testimony, which was fil...
AI summary In 1993, the author was retained by the Nova Scotia Utility and Review Board to provide testimony on cost of service and pricing issues related to NSPI, including recommendations on time-of-use rates and rate design.
9 10 Since that time, NSPI has filed additional rate design materials and a study of NSPI' s 11 rate proposals was completed by consultant Douglas Bowman at the request of the 12 Board. On August 17, 1995, NSPI filed an application for an...
AI summary The document discusses NSPI's application for a 3% rate increase and changes to rate design, following the submission of additional materials and a study by consultant Douglas Bowman. The Board requested a review of previous recommendations and information on rate design and industry restructuring impacts.
3 4 As I stated in my previous testi1nony, the prin1ar; purpose of TOU rates is to 5 improve the extent to which rates reflect the cost of producing electricity. Most 6 utilities have costs that vary by time of day or time of year in a rel...
AI summary The text discusses the purpose of Time-of-Use (TOU) rates, emphasizing their role in aligning electricity prices with production costs and encouraging efficient consumer decisions. It notes that while all parties support TOU rates in principle, NSPI and Mr. Bowman differ on the extent of their implementation.
III. SEASONAL RATES AND DECLINING BLOCK RATES FOR DOMESTIC CUSTOMERS 21 22 In my previous testimony I recommended that NSPI pursue seasonal rates (non-time 23 differentiated) for all customer classes. With regard to NSPI's proposal to offe...
AI summary The testifier previously recommended seasonal rates for all customer classes and did not find sufficient justification for NSPI's proposal to offer declining block rates to domestic customers for both summer and winter. This position remains unchanged based on the current case review.
VI. COMPETITION AND FLEXIBLE RATES 20 21 Mr. McDonald describes structural changes taking place in the U.S. electric utility 22 industry and NSPI' s need for pricing flexibility to respond to growing competition. I 23 concur with his comme...
AI summary The text discusses the need for Nova Scotia Power Inc. (NSPI) to adopt flexible pricing strategies to remain competitive in a changing electricity market. It highlights the trend in the U.S. toward retail wheeling and unbundling, and suggests that regulatory protocols for flexible pricing could help NSPI respond to industrial customers' demands for competitive arrangements.
DIRECT EXAMINATION BY MR. OUTHOUSE Q. Thank you, Dr. Chamberlin. Dr. Chamberlin, the only question that I would have before cross-examination; you said in your remarks that avoided cost is not synonymous with long-run marginal cost. Can th...
AI summary Dr. Chamberlin is being questioned about the distinction between avoided cost and long-run marginal cost, clarifying that they are not synonymous. This distinction is important in regulatory proceedings involving cost recovery and rate design.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. KEHOE 2760 answer that right, I think you'd have to first believe that the allocation methods were appropriate to begin with in each jurisdiction. And I wouldn't agree that that's true. My concern is not...
AI summary The discussion centers on the importance of accurate price signals reflecting marginal costs in energy systems to ensure efficiency and maximize system value. The speaker questions whether reliability and outage costs should be uniformly applied to all customers, suggesting that those with lower outage cost values should contribute less. The conversation references embedded cost of service and reliability considerations.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. KEHOE 2764 possible these so-called at-risk customers are just really taking advantage of the utilities and regulators? In other words, they have an expectation of what the product should cost as opposed...
AI summary Dr. Chamberlin is questioned about whether at-risk customers are exploiting utilities and regulators by expecting lower costs. He suggests that some customers are taking advantage of competitive wholesale and spot markets, but argues that retaining them is beneficial as long as they pay over marginal costs.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. KEHOE 2768 would that tell you about the current level of our electricity rates for industrial load? - A. I don't know that it would tell me anything without knowing a lot more than I do about what load g...
AI summary The cross-examination discusses the impact of electricity rates on industrial load, the need for NSPI to demonstrate effects of price changes on production decisions, and the importance of pricing incremental energy at marginal cost to promote efficiency.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. MACDONNELL 2774 shortfall who would pay for it? - A. If there's a revenue shortfall that results from an incorrect price to start with, I guess stockholders pay for it until the next rate case. And then i...
AI summary The discussion centers on revenue shortfalls due to incorrect pricing and the allocation of costs based on marginal costs. The expert explains that shareholders typically bear the burden of shortfalls until the next rate case and suggests that while marginal cost-based studies may be beneficial, they are not strictly necessary.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. MACDONNELL 2776 - a necessary goal? - 2 A. Undue discrimination? - Yes. 11 12 13 14 15 16 17 - discrimination is the A. Well. undue amount discrimination that you exercised that you didn't 5 need to. I su...
AI summary The testimony discusses concerns about potential undue discrimination in utility pricing, particularly in scenarios where identical services are priced differently for competing industrial customers in Nova Scotia. The witness expresses concern but acknowledges there may be situations where such discrimination is necessary or beneficial.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. MACDOUGALL 2786 - A. Well, it certainly is in the United States and every place else that I've spent any time looking. - Q. So, if we have competition in the electrical industry, is it your opinion that w...
AI summary Dr. Chamberlin discusses the potential for customers in the electrical industry to purchase energy on the spot market, driven by concerns about short-term energy costs and perceptions of over-built capacity. He notes that customers are seeking better pricing and believe that utilities have not adequately responded to their needs.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. CAMPBELL 2800 that's important. - 2 Q. All right. - Α. From a theoretical point of view, there are two 3 things that you want to that you need to know, 4 in order to get the revenue reconciliation process...
AI summary Dr. Chamberlin explains the importance of understanding marginal costs and elasticity in different types of usage for accurate revenue reconciliation. He emphasizes that pricing adjustments should be tailored based on customer responsiveness to ensure proper resource allocation.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. HARRIS 2815 - present environment, long-run marginal costs can be considered as well. - 3 Α. I would consider them both. Yeah. I actually disagree with the notion that in competitive 4 5 markets, rates ar...
AI summary Dr. Chamberlin discusses the difference between short-run and long-run marginal costs in electricity markets, noting that the gap is larger in this sector compared to other markets. He contrasts his view with Dr. Parmesano’s approach of setting lower short-run prices and higher long-run prices to reflect capacity needs.
DR. CHAMBERLIN, CROSS-EXAM. BY MR. HARRIS 2817 You have opportunities to hedge the differences between short run and long run, by selling and buying in futures markets. So that difference gets small. And so in the competitive market, I'd s...
AI summary Dr. Chamberlin discusses the importance of considering both short-run and long-run costs in pricing, particularly in competitive markets, and the role of futures markets in reflecting long-run considerations. He also touches on the diminishing role of Integrated Resource Planning (IRP) in competitive markets and the need for regulatory involvement in planning.
proposed by economists, the inverse elasticity rule, uses information on both marginal costs and price elasticities to minimize the resource distortions caused by price deviations from marginal cost. Trank Ramsey first proposed this second...
AI summary The inverse elasticity rule, proposed by Frank Ramsey, suggests that prices should deviate from marginal costs in proportion to the inverse of price elasticity of demand to minimize resource distortions. This rule has been applied in public utility pricing and is illustrated with an equilibrium condition involving price, marginal cost, and elasticity.
Retail Competition Much of the growing concern over competition in the retail electric utility industry centers around when and if retail wheeling will become a reality. Even without retail wheeling, utilities face numerous threats to thei...
AI summary The text discusses the growing competition in the retail electric utility industry, highlighting existing forms of competition and the potential for retail wheeling. While uncertainty remains about the form and timing of retail wheeling, some states have already taken steps to consider it. Utilities may benefit from retail wheeling by expanding loads and increasing revenue.
ojects on their own. The funds they would expend to develop new technologies and marketing infrastructures would benefit all customers and energy providers, putting them at a competitive disadvantage. - Broad-based rebate programs that rai...
AI summary The document discusses changes to utility planning, including the removal of broad-based rebate programs that raise rates from DSM portfolios and the elimination of cross-subsidization of DSM costs. Instead, DSM costs will be covered under a cost-causer pays arrangement.
RESPONSE TO INFORMATION REQUEST TO: SEMPRA ATLANTIC GAS INC. FROM: NSPI Question IR-5: Evidence of M. E. Whalen, Application of Nova Scotia Power Inc., Page 8. In purporting to illustrate the "benefit to NSPl's customers of a load retentio...
AI summary The document is a response to an information request regarding Nova Scotia Power Inc.'s (NSPI) assumption that 20% of large industrial and commercial customers would switch to an alternate energy source. The request seeks clarification on the basis for this assumption, including pricing scenarios and the rationale for a 10% price reduction in the evidence provided.
RESPONSE TO INFORMATION REQUEST TO: SEMPRA ATLANTIC GAS INC. FROM: NSPI Question IR-6: - (e) If the answer to ( d) is "yes", why should residential and other customers subsidize the reduction ofrates to NSPl's large industrial and commerci...
AI summary NSPI responds to a question regarding subsidizing rate reductions for large industrial and commercial customers, stating that the Load Retention Rate aims to prevent losses and maintain stable prices for all customers. The response also references an application for approval under the Public Utilities Act.
3. Real Time Pricing. Does your company currently have any RTP tariffs in effect or are you planning to implement such pricing in the near future? If any of the information requested above is available on your web site please provide the w...
AI summary Nova Scotia Power Inc. is being asked whether it currently has Real Time Pricing (RTP) tariffs in effect or plans to implement them soon. The request is part of a regulatory proceeding under the Public Utilities Act, involving a Load Retention Rate application.
Table Sempra IR-7 A Patrick Corcoran Director, Regulatory Affairs Montana Power Company 40 E. Broadway St. Butte, MT 59701-0001 Joanne Curley Director, Strategic Planning Orange and Rockland Utilities, Inc. One Blue Hill Plaza Pearl River,...
AI summary The document lists individuals from various utility companies involved in regulatory affairs and includes a reference to an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act, R.S.N.S., 1989, c.380 as amended.
Table Sempra IR-7A Barry M. Utsumi Manager, Rate & Regulatory Affairs Hawaiian Electric Company, Inc. P.O. Box 2750 Honolulu, HI 96840-0001 Judy Charnley Rates, Regulatory Affairs & Prod. Dev. BC Hydro 333 Dunsmuir St., 13th Floor Vancouve...
AI summary The text presents a list of individuals and their affiliations from various utility companies involved in rate and regulatory affairs, with a reference to a 1999 NSPI-P-871 document. It includes contact information for professionals from organizations such as Hawaiian Electric Company, BC Hydro, and others.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The document outlines an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. This proceeding involves regulatory approval of a rate structure aimed at managing load retention.
NOVA SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE ivIATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary The Nova Scotia Utility and Review Board is considering an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act, R.S.N.S., 1989, c.380 as amended.
NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF: The Public Utilities Act, R.S.N.S., 1989, c.380 as amended IN THE MATTER OF: An Application by Nova Scotia Power Incorporated for approval of a Load Retention Rate
AI summary This document pertains to an application by Nova Scotia Power Incorporated under the Public Utilities Act for approval of a Load Retention Rate. It outlines the regulatory proceeding related to this application.
P-14Direct Evidence of Jatinder Kumar [Board Consultant]
26 passages
BEFORE THE NOV A SCOTIA UTILITY AND REVIEW BOARD IN THE MATTER OF THE PUBLIC UTILITIES ACT. R.S.N.S., 1989, C.380 AS AMENDED AND IN THE MATTER OF AN APPLICATION BY NOV A SCOTIA POWER IN CORPORA TED FOR APPROVAL OF A LOAD RETENTION RA TE
AI summary This document pertains to a proceeding before the Nova Scotia Utility and Review Board, concerning an application by Nova Scotia Power for approval of a load retention rate under the Public Utilities Act, R.S.N.S., 1989, C.380 as amended.
PURPOSE ( - Q. WHAT IS THE PURPOSE OF YOUR DIRECT EVIDENCE? - A. The purpose of my Direct Evidence is to present my review and analysis of a "load retention" ("LR") rate proposed by the Nova Scotia Power Incorporated ("NSPI"). I will also...
AI summary The purpose of the direct evidence is to review and analyze a proposed 'load retention' rate by Nova Scotia Power Incorporated and provide recommendations. The testimony is structured into three sections: background, analysis of the proposal, and conclusions and recommendations.
BACKGROUND - Q. PLEASE PROVIDE A BRIEF BACKGROUND OF THIS PROCEEDING. - A. In a letter dated September 30, 1999, NSPI proposed to UARB a generic tariff involving the LR rate. On December 6, 1999, NSPI filed its application ("Application")...
AI summary NSPI proposed a LR rate to UARB in 1999 to prevent large customers from installing their own generation, which could lead to losing their loads and shifting fixed costs to other rate payers.
ANALYSIS OF NSPI'S PROPOSAL - Q. TO WHOM WILL NSPI BE OFFERING THE LR RATE? - A. NSPI is proposing to offer the LR rate to customers with a minimum load of 2,000 KVA or 1,800 KW. - Q. ARE YOU OPPOSED TO THE IMPLEMENTATION OF THE PROPOSED L...
AI summary The document discusses concerns raised about NSPI's proposed LR rate, which is intended for customers with a minimum load of 2,000 KVA or 1,800 KW. The respondent is not opposed to the implementation but has concerns and comments regarding the proposal, based on evidence provided by NSPI's witnesses.
- A. The issues and concerns discussed in my Direct Evidence are: 1. Loss of revenue due to load loss 2. NSPI's analysis of LR rates offered by other utilities 3. Lack of discussion of a competitive market 4. NSPI's basis for proposing the...
AI summary The testimony discusses concerns about revenue loss due to load loss, with a critique of the method used to calculate the loss. The claim is that using average energy cost rather than marginal energy cost may have overstated the revenue loss.
Rates, Cents/KWH Class 1995 1998 1999 Large Industrial - Firm 4.710 4.642 4.693 Large Industrial - Interruptible 4.766 4.577 4.605 Total Large Industrial 4.746 4.596 4.626 Large Commercial 6.547 6.475 6.458 Total 1.8 MW 4.980 4.797 4.803 T...
AI summary The table shows average electricity rates for different customer classes in Nova Scotia from 1995 to 1999, indicating a decline in rates over this period. In 1999, the average rate for all large customer classes was 4.803 cents/KWH, and for the Large Industrial class, it was 4.626 cents/KWH.
SUPPORT OF YOUR ASSERTION THAT THE RECOVERY OF REVENUE LOSS IS NOT GUARANTEED? -., - A. Yes. In a case involving Consumers Pennsylvania Water Company, Pennsylvania Public Utility Commission stated: Negotiated rates must not become merely a...
AI summary The text discusses the potential for revenue loss when utilities negotiate discounted rates with large customers, emphasizing the need for mechanisms to recover lost revenue and the importance of risk sharing between ratepayers and shareholders. It references decisions by the Pennsylvania Public Utility Commission and the New Hampshire Public Utilities Commission on this matter.
Analvsis of LR Rates Offered By Other Utiliti~ - Q. HA VE YOU REVIEWED MR. WHALEN'S DIRECT EVIDENCE RELATED TO LR RA TES OFFERED IN OTHER JURISDICTIONS? - A. Yes, I have. In his Direct Evidence and Table A attached thereto, Mr. Whalen list...
AI summary The witness confirms reviewing Mr. Whalen's evidence on LR rates in other jurisdictions, noting that while Table A lists 15 utilities, it lacks full detail. Additional information in Attachment 4 reveals that some utilities no longer offer load retention rates, and most will discontinue them with retail choice implementation.
Q. WHAT ARE YOUR CONCLUSIONS OF THE ABOVE ANALYSIS? A. A detailed analysis of the rates offered by utilities listed in Table A of Mr. Whalen's Direct Evidence indicates that the load retention rates similar to the one proposed by NSPI are...
AI summary The analysis concludes that load retention rates similar to those proposed by NSPI are not common and will be phased out with retail choice. Only a few utilities, such as NIPSCO and Commonwealth Edison, offer similar rates to prevent self-generation, while others limit such rates to specific industries.
Q. DOES NSPI'S SURVEY SUPPORT ITS PROPOSED LR RATE? A. If NSPI is relying on the widespread use of such a rate in other jurisdictions, then as I pointed out above the survey does not support the adoption of the LR rate. However, in my opin...
AI summary The response indicates that while NSPI's survey does not support the adoption of the LR rate based on its widespread use in other jurisdictions, this is not considered an important factor. The focus should be on the merits of the LR rate or any other rate proposal.
Lack of Discussion of a Competitive Electric Market Q. HAS NSPI ADDRESSED THE COMPETITIVE ELECTRIC MARKET? A. No, it has not done so in its Application, however, on page 4 of its 1998 Annual Report, NSPI acknowledges the increasing competi...
AI summary NSPI has not addressed the competitive electric market in its Application, but its 1998 Annual Report acknowledges the increasing competition in the electric market and mentions that other utilities will stop offering 'LR' type rates when retail competition is implemented.
NSPl's Basis for Proposing LR Rates - Q. BESIDES DESCRIBING A GENERAL NEED AND PURPOSE FOR ITS LR RA TE, DID NSPI PROVIDE ANY SPECIFIC BASIS FOR ITS PROPOSAL? - A. No, it did not. On page 2 of his Direct Evidence, Mr. Huskilson states, "Fo...
AI summary NSPI did not provide a specific basis or supporting studies for its proposed LR rates, despite mentioning that preliminary studies suggest the strategy may be economically attractive for some customers.
Anticompetitive Effect Q. WHAT ARE YOUR CONCERNS RELATED TO THE ANTICOMPETITIVE EFFECT OF NSPI'S PROPOSAL? A. It may not be unreasonable for an entity to lower its rates to avoid a loss of customers to its competitors, however, it is not r...
AI summary The concern is that NSPI's proposal may lead to anti-competitive behavior by lowering rates to retain customers while harming captive customers in a monopolized market. It emphasizes the need for the UARB to ensure non-discriminatory access to the LR rate and prevent NSPI's affiliates from using it to strengthen monopoly power.
Minimum Rate Level Q. DID NSPI PROPOSE ANY MINIMUM RATE LEVEL WHICH IT WILL CHARGE CUSTOMERS UNDER THE LR RATE? A. Although NSPI's proposed tariff states that it will offer the LR rate to a customer where Documenc : 55451. l it can be show...
AI summary NSPI does not specify a minimum rate level for the LR rate, but it suggests that the rate should recover incremental costs and contribute to fixed costs, as stated in response to Sempra IR-12.
Availability of LR Rate Q. DID NSPI PROPOSE WHEN IT WOULD START OFFERING AND THE DURATION FOR WHICH IT WOULD OFFER THE LR RA TE? A. No, it did not. Q. DO YOU HAVE ANY COMMENTS ON THIS ISSUE? A. Yes, I do. The gas may not be available for t...
AI summary NSPI did not propose when it would start offering the LR rate. The response suggests that the LR rate should not be offered until gas becomes available and long-term capacity is secured, as the marginal cost of this capacity is higher than the LR rate revenue.
Q. DO YOU HA VE SOME EXAMPLES OF SUCH PRICES? - A. Yes. Attachment 5 shows the hourly PJM spot prices for the month of July 1999. Attachment 5 shows that during 27 hours, the spot prices were higher than $900 per MWH and during 62 hours, t...
AI summary The respondent provides examples of high hourly PJM spot prices in July 1999, including instances where prices reached up to $10,000/MWH. They also mention current long-term contract prices of $40.00/MWH. The respondent argues that recovery of exit fees and stranded costs is not a suitable regulatory response in a competitive market, advocating instead for flexible rate approaches with customer protections.
CONCLUSIONS AND RECOMMENDATIONS - Q. MR. KUMAR, PLEASE SUMMARIZE YOUR CONCLUSIONS? - A. In my opinion, NSPI's proposed LR rate provision is a proper response to a competitive market. However, NSPI's proposal lacks certain customer protecti...
AI summary Mr. Kumar concludes that NSPI's LR rate proposal is appropriate for a competitive market but requires customer protection measures. He recommends conditions for implementation, including non-discrimination, availability timelines, loss mitigation strategies, and revenue sharing incentives.
I. Representative Publications ,. "Nuclear Magnetic Relaxation Time of Water in a Porous Medium with Heterogenous Surface Wettability", Journal of Applied Physics, Vol. 40, No. 10, September 1969, p.4165 (with Dr. I. Fatt and Dr. D.N. Sara...
AI summary The text lists various publications by individuals and organizations related to topics such as nuclear magnetic resonance, porous materials, cooling water treatment, and utility cost allocation. These works span scientific research and industry practices, with some references to regulatory and utility-related topics.
II. Representative Program Appearances "Synthetic Liners for Ponds", presented at 197 6 Water and Wastewater Equipment Manufacturers Association Conference at Houston, April 1, 1976. "Corrosion of Subsurfaces Equipment in Producing Oil and...
AI summary The text lists a series of presentations and speeches on topics related to energy, utility regulation, and gas markets, presented at various conferences and meetings between 1965 and 1997. These presentations cover a range of subjects, including gas regulation, utility restructuring, and engineering aspects of energy systems.
m. Other Reports and Studies Prepared Offshore oil spills .. "Summary and Explanation of FERC Order 436". Prepared for Department of Energy, March 1986. Gas from Eastern U.S. Shale, prepared for Gulf Oil Company. Summary of Court Order Rem...
AI summary This section lists various reports and studies prepared, including summaries of FERC orders, gas pipeline flow equations, cost of service manuals, and electric utility ratemaking processes. These documents cover topics such as offshore oil spills, gas marketing strategies, and legal summaries related to the Clean Air Act and FERC orders.
JATINDER KUMAR COMPANY CASE NO. JURISDICTION PNM Gas Service 2777 New Mexico (Levelized PGAC) PJM Companies ER97-3729-000 FERC (Market Based Rate) PJM Revised Tariffs ER97-3385 & FERC ER97-3415 PJM Open Access Tariffs OA-97-678-000 FERC De...
AI summary The text lists various companies, case numbers, and jurisdictions involved in regulatory proceedings, primarily under the Federal Energy Regulatory Commission (FERC). These cases pertain to gas and electric services, market-based rates, and transmission rates.
Average Purchased Power Costs Amount\ Off System Purchased Average Rate, Purchase Rate Fuel Cost\ Year\ MWH Cost Cents/KWH Cents/KWH Cents/KWH 1993 218,900 6,469,294 2.955 2.988 2.55 1994 216,200 6,867,993 3.177 3.111 2.55 1995 499,500 15,...
AI summary The document presents historical and projected average purchased power costs from 1993 to 2004, including data on MWH, cost, and average rates. It also references specific tables from the UARB in response to an information request.
Marginal Power Cost Winter On-Peak Marginal Energy Margi nal Capacity C ost, $/KW-yr Total Marginal Total On-Peak Year Cost, $/MWH Generation Transmission Distribution Total Capacity, $/MWH Marginal Cost, $/MWH 2000 40.11 1.42 28.51 10.66...
AI summary The table presents marginal power costs, including energy and capacity costs, for winter on-peak periods from 2000 to 2010. It includes breakdowns of marginal energy cost, transmission, distribution, and total marginal cost per year. The data is sourced from Tables 1 and 2 in the Response to NSUARB Information Request Question IR-26.
PJM HOURLY ENERGY PRICES July 05, 1999 Date Time (Hours) Price, $/kWh Price, $/MWh 7/5/1999 1600 0.9440 944.0000 7/5/1999 1700 0.9440 944.0000 7/5/1999 1800 0.8735 873.5000 7/5/1999 1900 0.7625 762.5000 7/5/1999 2000 0.6208 620.8300 7/5/19...
AI summary The document presents hourly energy prices from PJM on three dates in July 1999, showing fluctuations in prices per kilowatt-hour and megawatt-hour across different times of day.
PJM HOURLY ENERGY PRICES 7/27/1999 2100 0.0793 79.2500 7/27/1999 2000 0.6197 619.6700 7/27/1999 1900 0.8425 842.5000 7/27/1999 1800 0.9350 935.0000 7/27/1999 1700 0.9350 935.0000 7/27/1999 1600 0.9350 935.0000 7/27/1999 1500 0.6201 620.080...
AI summary The text presents hourly energy prices from PJM for July 27 to July 30, 1999, showing variations in price per kilowatt-hour (kWh) and megawatt-hour (MWh) across different times of the day. Prices fluctuate significantly, with some hours showing extremely high costs, such as $0.935/kWh or $935/MWh during peak times.
PJM HOURLY ENERGY PRICES 7/30/1999 1200 0.3200 320.0000 7/30/1999 1300 0.4539 453.9300 7/30/1999 1400 0.9985 998.5000 7/30/1999 1500 0.9990 999.0000 7/30/1999 1600 0.9990 999.0000 7/30/1 999 1700 0.9990 999.0000 7/30/1999 1800 0.9793 979.3...
AI summary The document provides hourly energy prices from PJM on July 30 and July 31, 1999, and includes additional data such as load, dry bulb temperature, dew point, and energy prices. This data is likely used for regulatory analysis and planning.
77877Book of Authorities of Nova Scotia Power Inc.
38 passages
Nova Scotia Utility and Review Board IN THE MATTER OF The Public Utilities Act, R.S.N.S., 1989 c. 380, as amended - and - IN THE MATTER OF an Application ofNova Scotia Power Incorporated for approval of a Load Retention Rate BOOK OF AUTHOR...
AI summary This document pertains to an application by Nova Scotia Power Incorporated for approval of a Load Retention Rate under the Public Utilities Act. It is part of the Nova Scotia Utility and Review Board proceedings.
Re Incentive Rates for Electric Service Intervenors: Oregon Department of Justice and Oregon Department of Energy UG 23, UE 50, Order No. 87-402 March 31, 1987 ORDER identifying permissible rate classification criteria and other legal requ...
AI summary The document references an order from March 31, 1987, which outlines permissible rate classification criteria and legal requirements for discount rate offerings in the context of incentive rates for electric service.
Discrimination, § 39 — Rates — Customer classes — Cost allocation. [OR.] In determining fair and reasonable rates for utility service the commissioner has broad discretion in allocating costs among customer classes; however, the classifica...
AI summary The text outlines legal standards for determining fair and reasonable utility rates, emphasizing that cost allocation among customer classes must avoid unjust discrimination. It specifies that discounts must be based on reasonable criteria and benefit other customers by maximizing fixed cost contributions, while permissible customer classification factors include volume of use and end use.
INTRODUCTION These proceedings were bf{?ught about by energy surpluses, poor economic conditions in the region, federal regulatory changes that have increased competition in the energy industry, and improved customer ability to switch fuel...
AI summary The proceedings were initiated due to energy surpluses, economic challenges, and increased competition from federal regulatory changes, making it harder for utilities to sell services at full tariff rates. Losing customers affects fixed costs and may require rate increases for others. Regulated utilities cannot offer tailored pricing like unregulated suppliers, as they must provide uniform service and rates. The Commissioner must develop new classification criteria to identify discretionary customers and ensure fairness.
POWERS AND RESPONSIBILITIES [1] ORS 756.040(2) empowers the Commissioner to "supervise and regulate" public utilities and to do "all things necessary and convenient in the exercise of such power and jurisdiction." The authority conferred b...
AI summary This section outlines the Commissioner's powers and responsibilities under ORS 756.040 and related statutes, emphasizing the regulation of public utilities and the requirement for fair and reasonable rates. It discusses the allocation of revenue responsibility among customer classes and the prohibition of unjust discrimination in rate-setting.
PERMISSIBLE RATE CLASSIFICATIONS In General [2-6] The anti-discrimination policies established by ORS 757.310 and ORS 757.325 imply that customers should be grouped into classes. ORS 757.230 requires the Commissioner to adopt a classificat...
AI summary The document discusses permissible rate classifications under Oregon law, referencing anti-discrimination policies and the Commissioner's role in adopting a classification system. It highlights the Utility Reform Project's argument that rate differences must be based on cost factors, while the Department of Justice cites constitutional equal protection clauses. PGE challenges the reliance on Kliks, but the Commissioner concludes that government action is involved, allowing broader considerations beyond cost, value, and conditions of service.
Volume of Use Volume of use is a permissible criteria for two reasons. One is that the "amount used" is specifically mentioned by ORS 757.230. The other is that increased volumes magnify the impact of a customer's behavior on other custome...
AI summary Volume of use is a permissible criteria because it is explicitly mentioned in ORS 757.230 and because higher usage levels can significantly affect other customers. For instance, the defection of a large industrial customer may lead to significant rate increases, unlike the defection of a residential customer.
om the CPEX plant to the benefit of other customers, the Commissioner has allowed transportation of natural gas by Northwest Natural to CPEX at discounted rates. In other situations, the price of en- ergy may not dominate production costs...
AI summary The Commissioner has allowed discounted rates for natural gas transportation to CPEX and electric service to Nippon Kokan K. K. as part of incentive packages to maintain or attract load. These discounts may benefit other customers by reducing fixed costs and are considered permissible criteria for distinguishing among customers based on economic circumstances.
Past Usage ,. l j The purpose of a discount for "incremental" usage is to reduce excess capacity by encouraging individual customers to consume more than they consumed in the past. The question is whether a customer's past consumption shou...
AI summary The text discusses the issue with the base/incremental approach to energy pricing, using an example of two lumber mills to illustrate how this method can lead to unfair rate differences. The poorly managed mill receives a discount on its incremental usage after a recession, while the well-managed mill does not, despite both receiving similar service.
RATE FLEXIBILJIT The combination of circumstances that gave rise to these proceedings has created a need for rates that focus on smaller groups of customers. Some of the parties desire the ability for individual customers to negotiate rate...
AI summary The text discusses the concept of rate flexibility, particularly the 'zone of reasonableness' for negotiating rates with individual customers. It highlights three legal challenges under ORS 757.205, 757.325, and the Commissioner's duty to ensure rates are 'just and reasonable'. The discussion emphasizes the need for regulatory oversight while allowing flexibility in certain circumstances.
FAIRNESS The industrial customers assert that any negotiated rate within a zone rang- ing from variable cost to fully allocated cost would be "cost based" and therefore reasonable. There are three problems with that assertion. The first is...
AI summary Industrial customers argue that any negotiated rate between variable and fully allocated cost is reasonable. However, the text highlights three issues: the inappropriate breadth of the range, the fairness of discounted rates, and the misapplication of 'cost based' as the sole basis for reasonableness. It argues that during scarcity, rates should reflect higher costs and that value of service should determine the top of the range.
CONCLUSIONS The purpose of this phase of these proceedings has been to identify permissible rate classification criteria and other legal requirements for permissible discounting concepts. !he parties and Commissioner have not intended to d...
AI summary This proceeding concludes that permissible rate classification criteria must be based on reasonable considerations and open-ended classes, with discounts aimed at benefiting other customers by increasing their contribution to fixed costs. Discounts should only be offered to customers with viable alternatives, and negotiated rates must be available to all qualifying customers.
INTRODUCTION The New Brunswick Power Corporation (NB Power) applied on Feb. 4, 1993 for a change in its rates to provide an incentive rate for large industrial customers. More particularly, this incentive rate was to promote in-province ec...
AI summary NB Power applied for a rate change in 1993 to offer a 50% discount on demand charges for large industrial customers, aiming to stimulate economic growth. The incentive would be available until 1998 and was intended to help utilize excess generating capacity. NB Power argued that the rate would benefit all customers by recovering incremental costs and reducing the need for revenue from other sources.
OIBER The LPU re ested the Board to di=~ct NB ?ower to us~ normalized revenue in its cost of service studies should the aoard approve the incentive =ate application. The L?U stated that to do othe:r,dse would result in a potential det::-i....
AI summary The LPU requested the Board to direct NB Power to use normalized revenue in cost of service studies if the incentive rate application is approved, citing potential negative impacts on the large industrial class. NB Power recommended expanding the incentive rate to include customers of two wholesale systems, which the Board agreed to, approving the amended proposal page.
is given. If less than twelve months notice is given, the customer must pay the differcna: betwttn past billings under Schedule SUS and the LPS or LIS rate which would otherwise have been applicable. In the event that a customer desires to...
AI summary Schedule SUS outlines specific billing and termination conditions for customers, requiring compensation for rate differences if termination notice is less than twelve months. The rates are not cost-based but are determined by the economics of installing gas turbine-driven generators and related equipment, varying per customer based on demand and cost factors.
2. PURA Sections 38 and 45 (3, 4) A second legal issue raised by Mr. Mentrup is whether Schedule SUS constitutes the grant of an unreasonable preference or advantage by GSU or causes unreasonable prejudice or disadvantage, within th.; mean...
AI summary The document discusses legal issues under PURA Sections 38 and 45 regarding Schedule SUS, focusing on whether it grants unreasonable preference or causes prejudice. Staff witness George Mentrup testified that non-industrial customers would not be disadvantaged, but some industrial customers might face competitive disadvantages due to the preferential rate structure.
I. Heat Rates [ii] According to Mr. Hughes, the heat rat.es contained in Schedule SUS should apply solely to customers with steam require- ~ments close to 265 psig-4 l l°F, and a separate heat rate schedule should be prepared for customers...
AI summary Mr. Hughes argues that the heat rates in Schedule SUS are inappropriate for customers with high pressure and temperature steam requirements. He suggests that separate heat rate schedules should be created to accurately reflect fuel costs for these customers, based on General Electric data and calculations.
2. Schedule B Rates Mr. Hughes has recommended that the Schedule B rates, which are designed for use with LPS and LIS customers with electric energy to steam energy ratios in excess of 230 KWH/MLB, should not be utilized because numerous c...
AI summary The discussion centers on Schedule B rates for LPS and LIS customers with high electric-to-steam energy ratios. Mr. Hughes argues against their use due to economic inefficiencies, while CSU and Mr. Hamilton defend them, citing combined cycle units. The examiner concludes Schedule B rates are reasonable and necessary for these customers.
C. OPC's SlalnnnlJ of PosiJum OPC filed a statement of position in this d ocket which raises a number of issues which the examiner has not attempted to address in detail, for three reasons. first, the statement was not timely filed by OPC,...
AI summary The OPC filed a late statement of position in the docket, which the examiner did not address in detail due to timing issues and lack of evidence. OPC argues that GSU's generation costs are inefficient and that Schedule SUS may be unnecessary if disallowances occur in GSU's rate case. However, the examiner finds that GSU's expedited filing is prudent to avoid load loss.
- 8. Schedule SUS is a non-cost based incentive rate available to any LPS and LIS customer with a minimum process steam requirement of 10,000 pounds per hour or the thermal energy equivalent thereof. - 9. Schedule SUS is designed to provid...
AI summary Schedule SUS is a non-cost based incentive rate designed to encourage industrial customers to remain on GSU's system by offering competitive pricing for power, reducing the incentive to cogenerate. CSU has experienced significant load loss to cogeneration and anticipates further losses, but intends for any revenue loss from Schedule SUS to be borne by shareholders, not recovered in future rate proceedings.
B. Conclusions of Law l. Gulf States Utilities Company (CSU) is a public utility as defined in Section 3(c)( I) of the Public Utility Regulatory Act (the Act), Tex. Rev. Civ. Stat. Ann. art. 1446c (Vernon Supp. 1987). 2. The Commission has...
AI summary The document outlines legal conclusions regarding the proposed tariff revision by Gulf States Utilities Company (GSU), determining that the Schedule SUS Experimental Rider is equitable and does not violate relevant sections of the Public Utility Regulatory Act. The proceeding was properly suspended, and the rider is deemed just and reasonable for approval.
ORDER In public meeting at ilS offices in Austin, Texas, the Public Utility Commission of Texas finds that the above styled application was processed in accordance with applicable statutes by an administrative law judge who prepared and fi...
AI summary The Public Utility Commission of Texas has approved an application by Gulf States Utilities Company for a Schedule SUS Experimental Rider and related amendments, while prohibiting the recovery of revenue losses from this rider in future rate proceedings. The order also denies other motions and applications not explicitly granted.
PUBLIC COUNSEL'S STATEMENT OF POSITION NOW COMES the Office of Public Utility Counsel (DPC) and files this Statement of Position in lieu of testimony and briefs which would have otherwise been submitted but for the fact that OPC was effect...
AI summary The Office of Public Utility Counsel (OPC) files a Statement of Position, highlighting concerns about GSU's rate case and the potential impact of River Bend and Cajun buyback on cogeneration costs. OPC argues that GSU's inefficient generation costs and the Commission's handling of these issues may affect the need for the SUS tariff and criticizes any political use of tariff creation.
FOOTNOTES 1 GSU alleges that the rates must be implemented immediately to avoid cogenerators from leaving the system now. OPC suspects that any cogenerator that is willing to make irreversible cogeneration decisions now, without any knowle...
AI summary GSU argues that rates must be implemented immediately to prevent cogenerators from leaving the system. OPC suggests that cogenerators would likely proceed with investments regardless of the SUS tariff. The text also discusses a legal determination that Northwest Alabama is a municipality under the NGA, exempt from jurisdiction.
PROCEDURAL HISTORY On January 26, 1988, Iowa Public Service Company (IPS) filed a proposed rate, identified as TF-88-24, to be offered to Deere & Company (Deere). On February 25, 1988, the Iowa Utilities Board (Board) issued an order docke...
AI summary In January 1988, Iowa Public Service Company (IPS) filed a proposed rate (TF-88-24) for Deere & Company. The Iowa Utilities Board docketed the tariff and set a procedural schedule, requiring a contested case proceeding to determine if the rate created an unreasonable preference for Deere, as prohibited by Iowa law. Deere petitioned to intervene, which was granted, and a hearing was held for cross-examination of testimony.
DISCUSSION IPS originally filed this proposed rate and a contract incorporating the proposed rate between Deere and IPS on December 7, 1987. The proposed tariff, identified as TF-87-414, was rejected by the Board on January 6, 1988. In the...
AI summary IPS initially filed a proposed rate and contract with Deere in 1987, but the Board rejected it for not being cost-based. IPS refiled with a cost-of-service analysis, but expressed reluctance to use a flexible rate due to its newness. The Board agreed not to require a flexible rate but required IPS to demonstrate that the rate does not create unreasonable preference or prejudice. IPS argues the rate is comparable to self-generation costs and thus fair.
FINDINGS OF FACT I. Deere & Company has the ability to self-generate. 2. The proposed rate, identified as TF-88-24, is equal to the cost to Deere & Company to generate its own power. 3. If Deere & Company were to reduce its reliance on Iow...
AI summary Deere & Company can self-generate power, and the proposed rate TF-88-24 equals its self-generation cost. Reducing reliance on Iowa Public Service Company's system would shift fixed costs of $250,000 to $400,000 to IPS's other customers.
CONCLUSIONS OF LAW I. The Utilities Board has jurisdiction over the parties and subject matt.er of this proceeding, pursuant to IOWA CODE §§ 476.1 and 476.3 (1987). 2. The proposed tariff, identified as TF-88-24, docs not grant an unreason...
AI summary The Utilities Board has jurisdiction over the proceeding based on Iowa Code sections 476.1 and 476.3 (1987). The proposed tariff, TF-88-24, does not grant unreasonable preferences or advantages and does not subject any person to unreasonable prejudice or disadvantage.
IT IS THEREFORE ORDERED: - l. The proposed tariff, identified as TF-88-24, filed by Iowa Public Service Company on January 26, 1988, is approved, subject to the following conditions: - ., a. Iowa Public Service Company shall offer the disc...
AI summary The document orders the approval of a proposed tariff (TF-88-24) filed by Iowa Public Service Company, with specific conditions. The company must offer a discounted rate to certain customers, and revenue adjustments are required for rate case purposes. The approval is effective immediately and lasts for one year.
Re Pay Telephone Access Lines Docket No. RMU-87-18 Iowa Utilities Board J anuary 22, 1988 ORDER adopting regulations requiring local exchange telephone carriers to provide: access service for coin-opcrai.c:d telephone termina!J on equal te...
AI summary The Iowa Utilities Board issued an order in 1988 requiring local exchange telephone carriers to provide access service for coin-operated telephone terminals on equal terms as business telephone service, ensuring competitive market entry for coin-operated telephones.
ervice, rate of return regulation but believed it was necessary to depart from traditional treatment because . .. - ... ~ ·-..... -· - of the potential adverse affects on other ratepayers. Mr. Richard J. Rudden, President of R.J. Rudden &...
AI summary The Commission is considering whether to reject Rider GA due to concerns over high industrial rates, potential long-term cost increases, and discriminatory practices. Testimony from Mr. Richard J. Rudden highlights the high costs of electricity at Bethlehem Burns Harbor Plant compared to other facilities, though he acknowledges the plant uses other energy sources.
I.C. 8-1-2-68(a) provides: Whenever, upon an investigation, the Commission shall find any rates, tolls, charges, schedules or joint rate or rates, to be unjust, unreasonable, insufficient or unjustly discriminatory, or to be preferential o...
AI summary This text outlines provisions from Indiana's utility regulation statutes, focusing on the Commission's authority to set just and reasonable rates, the classification of services, and the regulation of surplus profit arrangements. It emphasizes the Commission's investigative role in ensuring compliance with regulatory standards.
ORDER NOW THEREFORE, IT IS HEREBY ORDER.ED That Pacific Northwest Bell Telephone Company and US West Direct Company are authorized to enter into publishing agreements which are the subject matter of this proceeding to the extent necessary...
AI summary The order authorizes Pacific Northwest Bell and US West Direct to enter into publishing agreements for telephone directories until the next general rate proceeding. It also states that the current publishing fee will not be approved due to potential adverse effects on telecommunications service cost and availability. The Commission retains jurisdiction to ensure compliance with public policy.
Re Arkansas Power and Light Company Docket No. 88-072-TF O rder No. 6 Arkansas Public Service Commission September 15, 1988 ORDER authorizing an electric utility to reduce its rates for service to a large-load industrial customer in return...
AI summary The Arkansas Public Service Commission authorized an electric utility to offer reduced rates to a large-load industrial customer in exchange for deferring on-site electric generation for four years and granting the utility an option to install utility-owned cogeneration facilities. The order found that the agreement would benefit both the utility and ratepayers by maintaining fixed cost contributions and not adversely affecting other customers.
ORDER On May 19, 1988, Arkansas Power & Light Company (AP&L) filed a lelt.er application and proposed tariff in the abovestyled docket pursuant lO Rule 11.0l(d) of the Commission's Rules of Practice and Procedure. The tariff is applicable...
AI summary AP&L filed a tariff application for Mid-America Packaging, which operates 24/7 with high energy use and plans to install on-site generation. AEEC requested intervention to address potential revenue shortfalls affecting other ratepayers, and Commission Staff requested suspension for further investigation.
THE AGREEMENT The Agreement obligates Mid-America to purchase from AP&L all electricity required for its operations until the April 30, 1992, termination date of the AgreemenL The demand and energy rates to be paid by Mid-America will esca...
AI summary The Agreement outlines Mid-America's obligation to purchase electricity from AP&L until 1992, with escalating rates and a minimum demand charge. Section 9 was amended to address concerns raised by Mr. Strode, removing language that tied Mid-America's revenue requirement to AP&L's future retail rate proceedings. The amendment also acknowledges Mid-America's merger with Gaylord Container Corporation.
CONCLUSION Based on the: evidence: presented, the Commission finds that substantial evidence: has bc:c:n presented that lhc: Agreement is in lhc: best overall interest of lhe public, AP&L. Mid-America and AP&L's olhc:r customers. It has be...
AI summary The Commission concludes that the Agreement is in the public interest and benefits AP&L and its customers. It highlights that Mid-America's continued participation as a full requirements customer contributes to AP&L's fixed costs and that the Agreement rates are just and reasonable. The Commission also reserves judgment on potential generation facilities under the Agreement.
3. RETURN, t 5 - Rc:gul:atory inccnti,'C plan - Sliding scale - Range of returns - Commission duties. (DELI The commi.ssion rejected an "incentive regulation" proposal that would have provided a range: of equity returns for a local telepho...
AI summary The commission rejected an 'incentive regulation' proposal that would have allowed a range of equity returns for a local telephone carrier, instead opting for a 'rate stability' plan that authorizes a specific return on equity in conjunction with rate reductions, while ensuring rates are unlikely to be further reduced even if actual returns exceed authorized figures.