Sioux Lookout Hydro Inc.
Current applications before the Board
Title: Sioux-Lookout Hydro Application for 2018 Rates
Case number: EB-2017-0073
Type: Distribution Rate Application
Filed: October 20, 2017
Sioux Lookout Hydro has applied to the Ontario Energy Board to increase typical residential electricity distribution rates by $6.77 per month. Other customers will also be affected. The distribution rate increase of $5.76 per month as provided by Sioux Lookout Hydro in its original application was revised to $6.77 due to the correction of certain technical errors and the use of the most up-to-date information.
OEB Community Meeting
The OEB held a community meeting in Sioux Lookout on November 7, 2017. The purpose of this meeting was to hear directly from Sioux Lookout Hydro customers about the requests that Sioux Lookout Hydro has made in its rate application and to tell customers about the OEB’s rate review process.
OEB Staff Community Meeting Report
November 14, 2017 - OEB staff has issued a report summarizing comments, questions and concerns raised during the community meeting by customers who attended the meeting. The report is available publicly.
OEB Staff Report to Registrar
February 14, 2018 - OEB staff has issued its report to the Registrar identifying the issues that staff recommends should be considered for hearing and the recommended process for the hearing.
OEB Decision on Scope of Review
March 29, 2018 - The OEB has issued its Decision on the Scope of Review for Sioux Lookout Hydro Inc.’s electricity distribution rate application. This is the first decision on scope of review issued under the OEB's Proportionate Review pilot project. The Proportionate Review initiative is intended to align the OEB’s regulatory review with performance based regulation and is consistent with the Directive to the OEB from the Minister of Energy in respect of Ontario’s Long Term Energy Plan 2017, and included in the OEB’s LTEP Implementation Plan.
Rate Application (pdf)
- Cover Letter - Summary of Revisions to Original Application
- Exhibit 1 – Executive/Application Summaries, Bill Impacts & Administrative Documents
- Exhibit 2 – Rate Base
- Exhibit 3 – Operating Revenue
- Exhibit 4 – Operating Costs
- Exhibit 5 – Cost of Capital
- Exhibit 6 – Revenue Deficiency
- Exhibit 7 – Cost Allocation
- Exhibit 8 – Rate Design
- Exhibit 9 – Deferral & Variance Accounts
Rate Models & Workforms (xlsx)
- Chapter 2 Appendices
- Bill Impacts and Tariff Schedules
- Revenue Requirement Workform
- Load Forecast
- Income Tax and Payment-in-lieu-of-Taxes
- Cost Allocation
- Retail Transmission Service Rates Workform
- Deferral & Variance Account Continuity Schedule
- Loss Revenue Adjustment Mechanism Variance Account
Contact this Utility:
25 Fifth Ave.
Sioux Lookout ON P8T 1B3
The electricity utility scorecards measure how well Ontario's electricity utilities are performing each year. It is designed to encourage utilities to operate effectively, continually seek ways to improve productivity and focus on improvements that their customers value. Utilities report their scorecard performance results annually, and make the results available to the public.
The scorecard can be used as a tool for consumers to assess for themselves the value of the service received from their electricity utility. For example:
- When service appointments are booked with my utility, how often did they show up on time?
- How often did my power go out, and how long did the utility take to fix the problem and restore power?
- How successful is my utility at issuing accurate bills?
- Did my utility answer phone calls from customers in a timely way?
Use our report generator tool to compare costs and performance between distributors
New residential/small business services connected on time 100% (2016)
The utility must connect new service for the customer within five business days, 90 % of the time, unless the customer agrees to a later date. This timeline depends on the customer meeting specific requirements ahead of time (such as no electrical safety concerns in the building, customer's payment information complete, etc.)
Scheduled appointments met on time 91.7% (2016)
For appointments during the utility's regular business hours, the utility must offer a window of time that is not more than four hours long, and must arrive within that window, 90 % of the time.
Telephone calls answered on time 94% (2016)
During regular call centre hours, the utility's call centre staff must answer within 30 seconds of receiving the call directly or having the call transferred to them, 65 % of the time
Billing accuracy 99.84% (2016)
An important part of business is ensuring that customer's bills are accurate. The utility must report on its success at issuing accurate bills to its customers.
More information about billing accuracy
Accurate bills issued expressed as a percentage of total bills issued. It is calculated as:
= (Total number of bills issued for the year – Number of inaccurate bills issued for the year) / Total number of bills issued for the year
This requirement must be met at least 98% of the time on a yearly basis.
Complaints 0.00 (2016)
This metric measures the number of complaints the Ontario Energy Board received from customers about matters within our authority. Complaints made directly to the utility are not reported here. We measure this per 1000 customers so utilities that serve much larger or smaller populations can be compared against each other.
|Year||Complaints per 1000 customers||Total number of complaints|
Average number of hours power to a customer was interrupted 0.67104h (2016)
An important feature of a reliable distribution system is recovering from power outages as quickly as possible. The utility must track the average length of time, in hours, that its customers have experienced a power outage over the past year.
Average number of times power to a customer was interrupted 0.568326 (2016)
Another important feature of a reliable distribution system is reducing the frequency of power outages. Utilities must also track the number of times their customers experienced a power outage during the past year.
More information about interruption frequency
We measure disruption using the System Average Interruption Duration Index (Loss of Supply). It expresses the average amount of time, per reporting period, during which supply to a customer was interrupted. It is determined by dividing the total monthly duration of all interruptions experienced by all customers (excluding interruptions caused by Loss of Supply events), in hours, by the average number of customers served:
= (Total Customer Hours of Interruptions – Total Customer Hours of Interruptions caused by Loss of Supply events)/ Average Number of Customers Served.
Efficiency rating 3 (2016)
The utility must manage its costs successfully in order to help assure its customers they are receiving value for the cost of the service they receive. Utilities' total costs are evaluated to produce a single efficiency ranking. This is divided into five groups based on how big the difference is between each utility's actual and predicted costs. Distributors whose actual costs are lower than their predicted costs are considered more efficient.
- 1 = Actual costs are 25% or more below predicted costs
- 2 = Actual costs are 10% to 25% below predicted costs
- 3 = Actual costs are within +/- 10% of predicted costs
- 4 = Actual costs are 10% to 25% above predicted costs
- 5 = Actual costs are 25% or more above predicted costs
Cost per customer $852 (2016)
A simple measure that can be used as a comparison with other utilities is the utility's total cost per customer.
Total cost is a sum of all the costs incurred by the utility to provide service to its customers. The amount is then divided by the utility's total number of customers. This amount does not represent how much customers pay for their utility services.
More information about Cost per Customer
Total cost is calculated as the sum of a utility’s capital costs and Operating, Maintenance & Administration, or OM&A, costs, including certain adjustments to make the costs more comparable between utilities, per reporting period. This amount is then divided by the total number of customers the utility serves.