Erie Thames Powerlines Corporation
Current applications before the Board
Title: Approval to amalgamate Erie Thames Powerlines Corporation and West Coast Huron Energy Inc.
Case number: EB-2018-0082
Filed: April 16, 2018
Erie Thames Powerlines Corporation (owned by ERTH Corporation), has applied to the Ontario Energy Board for approval to acquire all of the shares of West Coast Huron Energy Inc., which is owned by the Town of Goderich. In return, the Town of Goderich will receive shares in ERTH Corporation. The applicants are also seeking approval to transfer the distribution licence and rate orders of West Coast Huron Energy Inc. to Erie Thames Powerlines Corporation and to amend the distribution licence of Erie Thames Powerlines Corporation to include the service territory of West Coast Huron Energy Inc.
The applicants say that ratepayers will not pay for the transaction costs and that distribution rates for both utilities will remain separate for nine years following consolidation.
Title: Erie Thames Power Lines Corporation Application for 2018 Rates
Case number: EB-2017-0038
Type: Distribution Rate Application
Filed: November 17, 2017
Erie Thames Power Lines Corporation has applied to the Ontario Energy Board (OEB) to increase typical residential electricity distribution rates by $2.70 per month. Other customers may also be affected.
The OEB is hosting a community meeting in Ingersoll on December 12, 2017. The purpose of this meeting is to hear directly from Erie Thames Power Lines Corporation’s customers about the requests that it has made in its rate application and to tell customers about the OEB’s rate review process. OEB representatives will be at the meeting to explain who we are and what we do. Most importantly, we are there to hear your comments and to answer your questions. We have asked Erie Thames Power Lines Corporation to be at the meeting to give an overview of its rate application and to explain the reasons for its requests. You can find a link to Erie Thames Power Lines Corporation’s full rate application below.
If you have questions or comments about Erie Thames Power Lines Corporation’s rate application or its performance, the OEB wants to know about it. Your participation and input are important aspects of the OEB’s review. For information about your utility’s performance in areas such as reliability, customer service and operational efficiency, visit its Performance Dashboard.
The OEB is not accepting requests for intervenor status at this time. The decision on whether to invite intervenor participation and to offer cost eligibility for any intervenor participation will be made later.
Community Meeting – December 12, 2017
6:30pm - 8:30pm
Unifor Local 88 Union Hall
364 Victoria Street, Ingersoll
- Bill Insert (pdf)
- Register for this event
- Information on Community Meetings and Rate Hearings
Rate Application (pdf)
- Exhibit 1 – Executive/Application Summaries, Bill Impacts & Administrative Documents
- Exhibit 2 – Rate Base (part 1 | part 2)
- 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 & Work Forms (xlsx)
- Application Checklist
- Chapter 2 Appendices
- Bill Impacts
- Tariff Schedules
- Income Tax and Payment-in-lieu-of-Taxes
- Retail Transmission Service Rates Work Form
- Lost Revenue Adjustment Mechanism Variance Account
- Deferral & Variance Account Work Form
Contact this Utility:
143 Bell Street
Ingersoll ON N5C 3K5
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 99.6% (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 100% (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 98.4% (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 99.5% (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 0.38 (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 1.46495h (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 0.235852 (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 $676 (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.