RRR Filing Guide - April 2015

RRR Filing Guide - April 2015
Ontario Energy Board
RRR FILING GUIDE
FOR ELECTRICITY DISTRIBUTORS’ REPORTING AND RECORD
KEEPING REQUIREMENTS (RRR)
PREPARED BY OEB-STAFF
April 2015
Updated (Apr 17, 2015)
DISCLAIMER NOTICE
The RRR Filing Guide has been prepared by OEB staff as an operational document and is not intended
to create any new OEB policy or to re-define the existing in the Electricity Reporting and Record
Keeping Requirements (RRR) or other documents of the OEB. Where needed, it provides a reference
for further information, or examples to clarify reporting requirements given the various scenarios that
arise for different distributors.
All examples presented in the RRR Filing Guide are for general illustration purposes only, and may not
address the specific circumstances of any one distributor.
RRR Filing Guide April 2015
TABLE OF CONTENTS
DISCLAIMER NOTICE .............................................................................................................................................................2
PURPOSE ..............................................................................................................................................................................5
AUTHORITY ..........................................................................................................................................................................6
LOCATION OF RRR INFORMATION ........................................................................................................................................7
REGISTRATION .................................................................................................................................................................... 10
SCHEDULE ........................................................................................................................................................................... 11
SUBMISSION ....................................................................................................................................................................... 12
REVISIONS .......................................................................................................................................................................... 13
RETENTION ......................................................................................................................................................................... 14
CONTACTS .......................................................................................................................................................................... 14
FORM BY FORM EXPLANATION ..........................................................................................................................................15
2.1.1 – DEFERRAL AND VARIANCE ACCOUNTS ..................................................................................................................................16
2.1.2 – CUSTOMER NUMBERS.......................................................................................................................................................22
2.1.3 - BLANK ............................................................................................................................................................................24
2.1.4.1 – SERVICE QUALITY ..........................................................................................................................................................25
2.1.4.1 – TABLES 1 & 2 – NEW LV & HV CONNECTIONS ..................................................................................................................26
2.1.4.1 – TABLE 3 – APPOINTMENT SCHEDULING .............................................................................................................................29
2.1.4.1 – TABLE 4 – APPOINTMENTS MET ......................................................................................................................................32
2.1.4.1 – TABLE 5 – RESCHEDULING A MISSED APPOINTMENT............................................................................................................35
2.1.4.1 – TABLES 6 & 7 – TELEPHONE ACCESSIBILITY & ABANDON RATE ..............................................................................................38
2.1.4.1 – TABLE 8 – WRITTEN RESPONSE TO QUALIFIED ENQUIRIES.....................................................................................................41
2.1.4.1 – TABLES 9 & 10 – EMERGENCY RESPONSE..........................................................................................................................43
2.1.4.1 – TABLE 11 – RECONNECTION PERFORMANCE ......................................................................................................................45
2.1.4.1 – TABLE 12 – MICRO-EMBEDDED GENERATION FACILITIES ......................................................................................................47
2.1.4.2 – SERVICE RELIABILITY ......................................................................................................................................................49
2.1.5 –PERFORMANCE BASED REGULATION (PBR) - GENERAL TIPS RELATED TO RRR ..............................................................................68
2.1.5.1 - LABOUR .......................................................................................................................................................................69
2.1.5.2 - CAPITAL .......................................................................................................................................................................71
2.1.5.3 – SUPPLY & DELIVERY ......................................................................................................................................................73
2.1.5.4 – DEMAND & REVENUE ....................................................................................................................................................75
2.1.5.5 – UTILITY CHARACTERISTICS...............................................................................................................................................78
2.1.5.5 B, C & D – PEAK LOAD, AVERAGE LOAD & AVERAGE LOAD FACTOR ............................................................................................80
2.1.5.5 E & F – CIRCUIT KILOMETERS OF LINE ...................................................................................................................................81
2.1.5.5 G – STATION TYPES & TRANSFORMERS .................................................................................................................................83
2.1.5.6 – REGULATED RETURN ON EQUITY (ROE) ............................................................................................................................85
2.1.6 – AUDITED FINANCIAL STATEMENTS .................................................................................................................................... 107
2.1.7 – TRIAL BALANCE ............................................................................................................................................................ 111
2.1.8 – CUSTOMER SERVICE ...................................................................................................................................................... 166
2.1.9 - BLANK ......................................................................................................................................................................... 173
2.1.10 – AFFILIATE TRANSACTIONS ............................................................................................................................................. 174
2.1.11 – SERVICE AGREEMENTS & BILLING OPTIONS...................................................................................................................... 177
RRR Filing Guide April 2015
2.1.12 - BLANK ....................................................................................................................................................................... 179
2.1.13 - RECONCILIATION.......................................................................................................................................................... 180
2.1.14 – NET METERING & EMBEDDED GENERATION .................................................................................................................... 184
2.1.15 – CONNECTION IMPACT ASSESSMENTS .............................................................................................................................. 187
2.1.16 - LEAP ........................................................................................................................................................................ 191
2.1.17 – LARGE CUSTOMER IDENTIFICATION................................................................................................................................. 195
2.1.18 – LOSS OF LARGE CUSTOMER ........................................................................................................................................... 197
2.1.19 – EVOLVING PERFORMANCE MEASURES............................................................................................................................. 198
2.1.19A – FIRST CONTACT RESOLUTION....................................................................................................................................... 199
2.1.19B – BILLING ACCURACY .................................................................................................................................................... 200
2.1.19C – CUSTOMER SATISFACTION SURVEY RESULTS ................................................................................................................... 202
2.1.19D – PUBLIC SAFETY ......................................................................................................................................................... 203
2.1.19E – DISTRIBUTION SYSTEM PLAN IMPLEMENTATION PROGRESS ............................................................................................... 204
2.2 – ARC SELF-CERTIFICATION.................................................................................................................................................. 207
EXECUTIVE CERTIFICATION ON RRR FILINGS .................................................................................................................................. 210
RRR Filing Guide April 2015
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PURPOSE
The purpose of this RRR Filing Guide is to aid distributors complete their annual RRR filings
due on April 30 and quarterly filings due on February 28, May 31, August 31 and November 30
of each year.
OEB-staff receive inquiries from electricity distributors on reporting requirements and/or new or
modified forms in the RRR e-filing system. This update serves to provide guidance on these
issues to assist distributors.
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AUTHORITY
The OEB’s authority to collect the information required under the RRR is derived from electricity
distributors’ licences which have a condition of licence requiring electricity distributors to provide
specified information in the form and manner as required by the OEB. The OEB’s Decision and
Order RP-2002-0140 of October 23, 2002 established the OEB’s policies for reporting and
record keeping requirements for electricity distributors which are set out in the document
“Electricity Reporting & Record Keeping Requirements.”
These reporting and record keeping requirements set the minimum reporting and record
keeping requirements with which a licensee must comply. Other reporting and record keeping
requirements specific to a licensee may also be contained in codes, individual licences or
regulatory instruments specific to a licensee (for example, in a rate order).
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LOCATION OF RRR INFORMATION
The RRR Reporting portal is accessed through the “Rules and Requirements” tab on the OEB
Industry website, by clicking on “Reporting & Record Keeping Requirements (RRR).”
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Highlights of the RRR reporting web pages are:
“Electricity RRR” tab contains current documents and recent communications from the OEB.
The RRR Filing Guide is also available on this page.
e-Filing Services – The user request form ("Electronic User Form") for changing user
information is found here. This page also provides links to view changes to upcoming filings for
electricity distributors, and the reporting schedules for all filers. The link to the RRR filing portal
is found on this page.
RRR Consultations - Past and present stakeholder consultations are listed in this section.
Reporting Schedule – This section contains the filing schedule for electricity/gas distributors,
retailers, marketers, electricity transmitters and the IESO; the count down for impending filing
deadlines and a link to the upcoming changes in filings for electricity distributors.
RRR Reports & Publications - The Yearbook of Electricity Distributors are found in this
section. In addition users can view past reports created from RRR data.
Key Addresses
RRR Filing Schedule (http://www.ontarioenergyboard.ca/oeb/Industry/Rules%20and%20Requirements/Reporting%20and%20
Record%20Keeping%20Requirements/RRR%20Reporting%20Schedule)
RRR Filing Portal (https://www.pes.ontarioenergyboard.ca/eservice/)
RRR Documents
(http://www.ontarioenergyboard.ca/OEB/Industry/Rules+and+Requirements/Reporting+and+Record+Ke
eping+Requirements/RRR+Documents)
RRR Archives
(http://www.ontarioenergyboard.ca/oeb/Industry/Rules%20and%20Requirements/Reporting%20and%20
Record%20Keeping%20Requirements/RRR%20Documents%20Archive)
E-filing Services (http://www.ontarioenergyboard.ca/OEB/Industry/Regulatory+Proceedings/eFiling+Services)
RRR User Add/Remove Request Form (http://www.ontarioenergyboard.ca/oeb/_Documents/eFiling/RRR-SM-TOU-user_form.pdf)
RRR Revision Request Form
(http://www.ontarioenergyboard.ca/oeb/_Documents/RRR/RRR_data_revision_request_form.pdf)
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REGISTRATION
Registered User Privileges
Registration of at least one RRR user is necessary in order to fulfill the condition of licence
which requires submission of information “in the form and manner required by the Board.”
Only RRR registered users can access input forms for filing, based on the personal password
issued to them by the OEB. The name of the RRR user is recorded in the OEB database as the
submitter of the filing.
Registered users can view and revise past filings.
Registered users annually give or deny consent to the OEB to submit the annual Electric Utility
Financial Report to Statistics Canada on behalf of their distributor using the information
submitted to the OEB in their RRR 2.1.5 (PBR) and RRR 2.1.7 (trial balance) filings.
Removing or Adding a registered user
When the job function of a registered user changes, or when an employee leaves the distributor,
the OEB should be informed, so that the RRR password assigned to the person can be
cancelled.
To remove or add a RRR user, the primary regulatory contact for the distributor should complete
the “Electronic User Form” found on the e-Filing Services page of the OEB website (link:
http://www.ontarioenergyboard.ca/OEB/_Documents/e-Filing/RRR-SM-TOU- user_form.pdf)
The email address used by the primary regulatory contact in sending the request should match
the contact email on record with the OEB.
Other passwords
Passwords are also issued by the OEB to an executive signing officer(s) of the distributor
(e.g. Chief Executive Officer or Chief Financial Officer), to enable:
1. Electronic submission of certificate for compliance with the Affiliate Relationships Code
(RRR Section 2.2.1). In 2015, this certification must be provided electronically, i.e. paper
submissions are no longer an option.
2. Electronic sign-off on the distributor’s Scorecard.
3. Electronic sign-off on quarterly and annual distributor’s RRR filings.
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SCHEDULE
The OEB generates a filing schedule each year, which can be found on the Rules and
Requirements section of the OEB Industry website, under “Reporting Schedule” .The filing
schedule is as follows:
RRR
Section
Jan
31
Feb
28
Mar
31
Apr
30
Jun
30
Jul
31
Aug
31
Sep
30
Oct
31
Nov
30
2.1.1




2.1.2







2.1.4

2.1.5

2.1.5.6
Upload
2.1.7

2.1.8

2.1.10

2.1.11

2.1.13
Upload
2.1.14
2.1.15
Dec
31

2.1.6


2.1.16

2.1.17

2.1.18

May
31
Email as needed
2.1.19

2.2

= Electronic submission
If the “due date” above falls on a day that is a Saturday, Sunday, or legal holiday in the Province
of Ontario, then the due date is the next business day (Section 1.3 of the RRR- Electricity
document).
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SUBMISSION
Filing Status
To make sure your work has been saved or submitted, as desired, always check the Status box
on the “Report Summary” section at the beginning of the form.
The Status box will show one of the following:
Blank: At the time of opening the form.
Work in progress: After saving the form.
Submitted: When the information is filed successfully with the OEB.
Revised: When the information is re-filed subsequent to the first filing.
Submitted after deadline: When the information is filed with the OEB after due date.
Submit Box
The status changes based on the choice made on the submit box which is found at the end of
each RRR input form.
The default setting for the Submit box is a
blank.
Choose NO to save, and YES to submit.
Viewing of RRR Information
OEB staff can view filings only after successful submission. The first submitted filing is “version
0” of the filing. Subsequent submissions are numbered sequentially. Work in progress filings,
that is, filings that have been saved but not submitted, are not available for viewing by OEB
staff.
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REVISIONS
After due date:
At the end of the due date, the RRR portal is closed, and no further submissions can be made.
The last submitted filing is the filing on OEB’s record.
After the filing due date, if the contents of the input form are changed, these will appear in the
input form, but on clicking “Save” the following message appears, and changes will not be
saved or submitted:
For revisions to filings after the due date, please refer to the OEB letter dated February 17, 2010
to licensed electricity distributors which states the expectation that revisions will be required only
in exceptional circumstances.
Before due date:
If a filing has been submitted before the due date, it can be changed and submitted again as
long as the due date has not passed. The latest submission overrides all previously submitted
filings.
Extension for filing
If you know in advance that your filing will be delayed beyond the due date, you can request an
extension in filing date by emailing staff listed in the Contacts section of this RRR Filing Guide.
Please note that annual filings due April 30 must be submitted accurately and on time to enable
the timely implementation of the scorecard.
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RETENTION
No retention limits for RRR information are specified by the OEB. Distributors are expected to
follow the provincial, tax and other retention obligations. In case of an audit, distributors should
have the ability to demonstrate the calculation for the reported numbers. The OEB does not
specify any particular format for the backup information.
Archives
All submitted filings are archived in the OEB’s database. RRR registered users can view past
filings through the same portal where filings are submitted. However, the historical view is
available only for information that is currently collected.
For example, the collection of information on service charges in RRR Section 2.1.1 is now
discontinued. As a result, this historical information on service charges can no longer be viewed
through the RRR portal by the RRR user. However the information resides in the OEB’s
database, and can be obtained on request.
CONTACTS
Issue
IT issues including
submission difficulties
(e.g. log-in, passwords,
unable to save, submission
or upload attachment
difficulties)
RRR clarifications/enquiries
Add/Remove RRR User,
Extension and Revisions
Any other RRR matter
Name
Email
IT Help
[email protected]
Industry Relations Hotline
[email protected]
Stephanie Chan, Analyst
[email protected]
Anshula Ohri, Project
Advisor
[email protected]
Ben Baksh, Senior Advisor
[email protected]
Daria Babaie, Manager,
Audit & Performance
Assessment
[email protected]
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FORM BY FORM EXPLANATION
Layout
A. A summary description of what is required to be filed, changes to the electronic input form,
and tips for filing.
B. A reproduction of the electronic input form available to the RRR filer for input.
C. Each electronic form contains instructions.
Benefits
•
All information on each reporting requirement is contained in one place.
•
All information for each reporting requirement is accessible to all persons at the distributor
through this RRR Filing Guide.
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2.1.1 – Deferral and Variance Accounts
2.1.1 Deferral & variance accounts
Content
Deferral and variance accounts opening balance, accruals, carrying charges and adjustments
in the quarter, and closing balance for the quarter.
New on Form
New:
Added: New sub-account added: 1595 sub-account for disposition of account balances
approved in 2015.
Deleted: Sub-account deleted: 1508 sub-account financial assistance payment and
recovery variance – OCEB Act.
These changes will be reflected in the quarterly filing for Q1 2015 due on May 31, 2015.
Tips
Accounting standard:
There are two separate forms for reporting the trial balances. Only one is required
to be submitted but the choice of form selection would depend on which accounting
standard is being used by the distributor.
At the beginning of the form, after instruction #5, you are required to select one of
two options to inform the OEB of the accounting standard being used for reporting
to the OEB. If the distributor’s distribution rates for the reporting period were set
using Modified International Financial Reporting Standards (MIFRS), you may
choose the MIFRS option. If this however was not the case, then you may choose
second option which includes reporting under Canadian GAAP (which is in effect
for many distributors to the end of 2014), Accounting Standards for Private
Enterprises (ASPE), or US GAAP.
………………………………………………………………………………………………
Opening balance discrepancy:
If you find that the closing balance from the previous quarter in your general ledger
does not match the auto-populated opening balance on your input form for the
current quarter, two options are available to you:
• If the change is not material (either in absolute terms or in terms of impact on the
regulated entity), enter the difference between the reported and actual closing
balance for the previous quarter in column 5 (Other Adjustments this Period).
• If the change is material, email a completed RRR Data Revision Request Form to
OEB staff. If your request is approved, access will be provided to you to revise the
ending balance for the previous quarter. The revised ending balance from the
previous quarter will automatically populate your current quarter opening balance.
………………………………………………………………………………………………
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Alignment with annual filing:
For the December 31 quarterly filing, please ensure that the account balances
reported match the RRR Section 2.1.7 (trial balance) reporting.
Net accruals:
In the RRR 2.1.1 form, net accruals generally represent all recorded transactions
associated with a specific deferral or variance account in the three-month reporting
period. The basis of the accounting is prescribed in the OEB’s Accounting
Procedures Handbook (APH), APH-FAQs or other sources of OEB-issued
accounting guidance. It follows then that the reporting of the account balances
should follow the basis of the accounting and specified procedures.
………………………………………………………………………………………………
1595 sub-accounts:
The sub-accounts of 1595 are for transfer of recovery/refund amounts on
disposition of an account. When an account balance is moved to the 1595
recovery/refund account, the sub-account to which it is transferred should
correspond to the year in which the disposition rate rider became effective. For
example, if a disposition was ordered via an OEB rate order with an effective date
for the rate rider of January 1, 2015 or May 1, 2015, the transferred amount should
be recorded in the “2015” sub-account of 1595.
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2.1.2 – Customer Numbers
2.1.2 Customer numbers
Content
To minimize reporting of this requirement, the number of retailer customers is
reported in aggregate for the first three quarters Q1, Q2 and Q3. In the final quarter of
the year (Q4), reporting of retailer customer numbers is required by individual retailer.
Q1, Q2 & Q3:
Table 1: Captures distributor (Standard Supply Service – SSS) customers on RPP
and non-RPP prices along with the number of units in multi-unit properties, by rate
class.
Table 2: Distributors at less than 98% implementation of Time of Use (TOU) billing
are required to provide a breakdown of the number customers on TOU or not.
Table 3: Captures aggregate retailer customers along with the number of units in
multi-unit properties, by rate class.
Q4:
Tables 1 & 2: Same as in Q1/Q2/Q3 above.
Table 3a: Captures individual retailer customers along with the number of units in
multi-unit properties, by rate class.
Table 3b: Auto-calculated table which aggregates all retailer customers.
Table 4: Auto-calculated table which aggregates all distributor (SSS) and retailer
customers.
The above description applies to the 2.1.2 form that will be available for Q2, Q3 & Q4
2015. For Q1 2015, changes will be made to the 2.1.2 form consistent with those
made in form 2.1.5.4 (Demand & Revenue tab in the 2.1.5 form) to capture
information specific to a distributor’s own detailed rate classes as described below in
the “New on Form” section.
In subsequent years, the information according to distributor-specific rate classes will
be collected in the fourth quarter of the year, i.e. with the Q4 form.
Since the 2.1.2 form for Q1 2015 is not available at this time, a copy of the form is not
included in this Guide at this time.
New on Form
New: Wholesale market participant information is captured in separate table of the
form. As a result, the row for wholesale market participant information has been
removed from the table.
New: Reporting by distributor-specific rate classes:
Previously, the OEB requested distributors to report customer number information for
rate classes on an aggregate level that was common to all distributors (e.g.,
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Residential, GS < 50 kW, GS > 50 kW, etc.). Effective for the 2014 fiscal year
reporting, the data input forms are formatted for the input of information specific to a
distributor’s approved set of rate classes. Distributors will input and report customer
number information at this level of detail. This additional information is intended to
enable further streamlining of the application process for formulaic adjustments to
rates during an incentive rate-setting period.
To transition this change in reporting, these changes will be reflected in the quarterly
filing for Q1 2015 due May 31, 2015. In subsequent years, only the Q4 filing will require
the distributor-specific rate class information.
Tips
Table 1 – SSS only:
The first table is for reporting SSS customers only. Do not report any retailer
customers in the first table.
……………………………………………………………………………………………………………
Connections only:
For unmetered scattered load, street lighting and sentinel lighting, please report
number of connections, and not number of accounts.
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2.1.3 - Blank
This filing has been discontinued.
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2.1.4.1 – Service Quality
2.1.4.1 Service Quality Requirements
Content
Electricity Service Quality Requirements (ESQRs):
This section requires information on the OEB’s Service Quality Requirements and new microembedded generation facilities from Electricity Distributors as described in the Distribution
System Code (DSC) for the following performance standards:
1. Connection Of New Services
2. Appointment Scheduling
3. Appointments Met
4. Rescheduling A Missed Appointment
5. Telephone Accessibility
6. Telephone Call Abandon Rate
7. Written Response To Enquires
8. Emergency Response
9. Reconnection Standards
10. New Micro-Embedded Generation Facilities
New on Form
The form will not submit if any input field is blank. Please remove blanks by entering
“0” before submitting.
New: A summary table showing whether the OEB standards are met or not met in
accordance with the standard for each requirement reported. The purpose of this
summary tab is to serve as a checklist to assist a distributor with the verification of the
information reported in this section for ESQRs. The resulting “achieved” metrics from
entering the data in the relevant forms should match that of the “expected” results from
the distributor’s own records. Please review your data entries if the achieved and
expected results do not match and correct the entries, if necessary.
In the event you do not have any activities to report for an ESQR (e.g., New Microembedded Generation Facilities Connected on Time), your results would show 0% and
labelled as “Not Met”. Please disregard the label message. For purposes of this
requirement in the yearbook, the result will be shown as a “N/A” and for the scorecard
it will be shown as a “blank” for your distributor.
Please note that in order to see the calculated numbers you must select NO or YES in
the Submit box, and then SAVE or SAVE & EXIT.
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2.1.4.1 – Tables 1 & 2 – New LV & HV Connections
Table 1: Connection of new low voltage connections – DSC 7.2
Table 2: Connection of new high voltage connections – DSC 7.2
Tables 1 & 2:
On Electronic Filing Form enter:
a) Total number of new low voltage services connected in each
month;
b) Number of new low voltage services connected in each month for
which the service quality requirement set out in section 7.2 of the
Distribution System Code was met;
c) Percentage of (b) with respect to (a);
d) Total number of new high voltage services connected in each
month;
e) Number of new high voltage services connected in each month for
which the service quality requirement set out in section 7.2 of the
Distribution System Code was met; and
f) Percentage of (e) with respect to (d).
The requirement must be met 90% of the time.
Please see below for Tips on filing.
Definitions from Section 7.1 of the DSC
• The “new service” means a connection that requires an Electrical Safety Authority
(ESA) certificate before the connection can be completed. This includes, but is not
limited to, connections associated with a service upgrade and connections that
involve the installation of an additional meter on the distribution system where no
meter previously existed. Solely replacing an existing meter is not a new service.
•
"service conditions" means any condition that must be satisfied before the service
will be provided and may include the payment of connection fees, the signing of
an offer to connect, the completion of a distribution system expansion, the delivery
of any necessary equipment and the receipt of an ESA certificate.
Section 7.2 of the DSC states:
Must be completed within 5 business days from the day on which all applicable
service conditions are satisfied, or at such later date as agreed to by the customer
and distributor.
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Tips
Example 1: Connection of New Services
Distributor A
Received 6,100 new service
requests in the year
6,000 requests related to
connection of a new service
for low voltage
5,500 connections
completed within 5
business days from
the date on which all
service conditions
were satisfied, or at
a later date agreed
by customers






500 connections
completed after 5
business days from
the date on which all
service conditions
were satisfied
100 requests related to
connection of a new service
for high voltage
95 connections
completed within 10
business days from
the date on which all
service conditions
were satisfied, or at
a later date agreed
by customers
5 connections
completed within 10
business days from
the date on which all
service conditions
were satisfied
Total new LV services connected: 6,000
Total new LV services connected within 5 business days or at
a later date agreed by customers: 5,500
Connection of New Services – LV: 5,500/6,000 = 92%
Total new HV services connected: 100
Total new HV services connected within 10 business days or
at a later date agreed by customers: 95
Connection of New Services – HV: 95/100 = 95%
New service:
Please note that the definition of a new service as per the DSC refers to the need for a
certificate from the ESA. For example, if the connection of a generation meter requires an ESA
certificate, then this should be included in the new service metric.
According to Section 7.2 of the DSC, solely replacing an existing meter is not regarded as
a new service. (This includes, but is not limited to, connections associated with a service
upgrade and connections that involve the installation of an additional meter on the
distribution system where no meter previously existed.)
New service request for connection of micro-embedded generation:
When reporting on new low voltage service requests connected on time, do not include
requests for connection of micro-embedded generation facilities. The timeliness of the
connection of micro-embedded generation facilities is now reported separately since 2013.
New service request with customer present:
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If a New Residential LV connection has a request from the customer to be present, this
measure is counted for both New LV Connection and Appointments Met if all the proper
conditions are met.
Tracking of events
Important dates such as the date when the distributor was first approached by the
customer, when the appointment was made and when it was completed should be
tracked by the distributor in order to ensure accurate reporting under this requirement.
The date log will also provide the necessary backup to support the reporting.
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2.1.4.1 – Table 3 – Appointment Scheduling
Table 3: Appointment scheduling – DSC 7.3
Table 3:
On Electronic Filing Form enter:
a) Total number of appointments described in section 7.3 of the
Distribution System Code requested in each month;
b) Number of appointments in each month for which the service
quality requirement set out in section 7.3 of the Distribution
System Code was met; and
c) Percentage of (b) with respect to (a).
The requirement must be met 90% of the time.
Please see below for Tips on filing.
Section 7.3 of the DSC:
7.3.1 When a customer or a representative of a customer requests an appointment
with a distributor, the distributor shall schedule the appointment to take place
within 5 business days of the day on which all applicable service conditions are
satisfied or on such later date as may be agreed upon by the customer and
distributor.
7.3.2 Where the appointment in section 7.3.1 requires the presence of the
customer or the customer’s representative, the distributor shall fulfil the
requirements set out in section 7.4.1.
7.3.3 Where the appointment in section 7.3.1 does not require the presence of the
customer or the customer’s representative, the distributor shall arrive for the
appointment on the day scheduled under section 7.3.1.
7.3.5 All of the actions set out in:
(a) section 7.3.1; and
(b) section 7.3.2 or section 7.3.3, as applicable,
must be completed in order to fulfil this service quality requirement.
7.3.6 This service quality requirement applies regardless of whether or not the
presence of the customer or the customer’s representative is required.
7.3.7 This service quality requirement does not apply to appointments that are
subject to the requirements in sections 7.2.1 and 7.2.2.
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Section 7.4.1 of the DSC:
7.4.1 When an appointment is either:
a. requested by a customer or a representative of a customer with a
distributor; or
b. required by a distributor with a customer or representative of a customer,
the distributor must offer to schedule the appointment during the
distributor’s regular hours of operation within a window of time that is no
greater than 4 hours (i.e., morning, afternoon or, if available, evening). The
distributor must then arrive for the appointment within the scheduled
timeframe.
Sections 7.2.1 & 7.2.2 of the DSC:
7.2.1 A connection for a new service request for a low voltage (<750 volts) service
must be completed within 5 business days from the day on which all applicable
service conditions are satisfied, or at such later date as agreed to by the customer
and distributor.
7.2.2 A connection for a new service request for a high voltage (>750 volts) service
must be completed within 10 business days from the day on which all applicable
service conditions are satisfied, or at such later date as agreed to by the customer
and distributor.
Section 7.5 of the DSC states:
7.5.1 When an appointment to which sections 7.3.1, 7.3.3, or 7.4.1 apply is missed
or is going to be missed, the distributor must:
(a) attempt to contact the customer before the scheduled appointment to inform
the customer that the appointment will be missed; and
(b) attempt to contact the customer within one business day to reschedule the
appointment.
7.5.5 The rescheduled appointment becomes a new appointment for the purposes
of sections 7.3.1 or 7.4.1 as appropriate.
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Tips
Example 2: Appointment Scheduling
Distributor A
Total of 4,500 appointments
2,500 appointments
requested by customers
Total of 2,400
appointments
scheduled within 5
days or at another
time agreed by the
customer
1,400
appointments
did not
request the
presence of
the customer
1,280
appointments
completed on
the scheduled
date
2,000 appointments initiated
by distributor A for
installation of smart meters
100 appointments
not scheduled (i.e.
not scheduled within
5 days nor at
another time agreed
by the customer)
1,000
appointments
did request the
presence of
the customer
940 appointments
completed within the
scheduled 4 hour
window
60 appointments not
completed within the
scheduled 4 hour
window
120
appointments
not completed
on the
scheduled
date

Total appointments requested by customers: 2,500

Total appointments scheduled as required: 1,280 + 940 = 2,220

Appointments Scheduled metric: 2,220 / 2,500 = 89%
Generation meter installation:
Installation of a generation meter is counted under the Appointments Scheduling measure.
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2.1.4.1 – Table 4 – Appointments Met
Table 4: Appointments met – DSC 7.4
Table 4:
On Electronic Filing Form enter:
a) Total number of appointments described in section 7.4 of the
Distribution System Code requested or required in each month;
b) Number of appointments in each month for which the service
quality requirement set out in section 7.4 of the Distribution
System Code was met; and
c) Percentage of (b) with respect to (a).
The requirement must be met 90% of the time.
Please see below for Tips on filing.
Section 7.4 of the .S. C. states:
7.4.1 When an appointment is either:
(a) requested by a customer or a representative of a customer with a distributor; or
(b) required by a distributor with a customer or representative of a customer,
the distributor must offer to schedule the appointment during the
distributor’s regular hours of operation within a window of time that is no
greater than 4 hours (i.e., morning, afternoon or, if available, evening). The
distributor must then arrive for the appointment within the scheduled
timeframe.
7. 4. 3 Both of the actions set out in section 7.4.1 must be completed in order to
fulfill this service quality requirement.
7.4.4 If the distributor arrives at the scheduled appointment within the required
time period but the appointment cannot be met because the customer failed to
attend the appointment, the distributor may consider the appointment to have been
met for the purpose of determining its performance with the standard.
7.4.5 This service quality requirement applies to appointments that:
(a) require the presence of the customer or the customer’s representative;
(b) are scheduled to occur at the distributor’s office, the customer’s premises,
business or work site, or at another location agreed to by the distributor and
customer; and
(c) are a frequently recurring part of the distributor’s normal course of business,
including, but not limited to, the following:
i) disconnecting and/or reconnecting service to effect maintenance or
upgrades;
ii) connecting a new customer;
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iii) connecting a new service for an existing customer;
iv) providing underground cable locates;
v) inspections;
vi) gaining access to read or replace an inside meter or to provide the
customer with instructions on the proper use of a prepaid meter or similar
device; and
vii)appointments that are rescheduled as required by section 7.5.1.
Section 7.5 of the DSC states:
7.5.1 When an appointment to which sections 7.3.1, 7.3.3, or 7.4.1 apply is missed
or is going to be missed, the distributor must:
(a) attempt to contact the customer before the scheduled appointment to inform
the customer that the appointment will be missed; and
(b) attempt to contact the customer within one business day to reschedule the
appointment.
7.5.5 The rescheduled appointment becomes a new appointment for the purposes
of sections 7.3.1 or 7.4.1 as appropriate.
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Tips
Example 3: Appointment Met
Distributor A
Total of 10,600
appointments to be met
6,100 appointments
requested by customers for
new service (see example 1)
2,500 other appointments
requested by customers
(see example 2)
*6,100
appointments
did request the
presence of
the customer
1,000
appointments
did request the
presence of
the customer
2,000 appointments initiated
by distributor A for
installation of smart meters
(see example 2)
400
appointments
did request the
presence of
the customer
Total of 7,500 appointments did request the presence of
the customer
7,300
appointments
completed
within the
scheduled 4
hour window
200
appointments
not completed
within the
scheduled 4
hour window
*Assume all new connection appointments require the presence of the customer

Appointments requiring customer presence: 7,500

Appointments met within the scheduled 4 hour window: 7,300

Appointments Met metric: 7,300 / 7,500 = 97%
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2.1.4.1 – Table 5 – Rescheduling a Missed Appointment
Table 5: Rescheduling a missed appointment – DSC 7.5
Table 5:
On Electronic Filing Form enter:
a) Total number of missed appointments described in section 7.5 of the
Distribution System Code in each month;
b) Number of missed appointments in each month for which the service
quality requirement set out in section 7.5 of the Distribution System
Code was met; and
c) Percentage of (b) with respect to (a).
The requirement must be met 100% of the time.
Please see below for Tips on filing.
Section 7.5 of the DSC states:
7.5.1 When an appointment to which sections 7.3.1, 7.3.3, or 7.4.1 apply is missed
or is going to be missed, the distributor must:
(a) attempt to contact the customer before the scheduled appointment to inform
the customer that the appointment will be missed; and
(b) attempt to contact the customer within one business day to reschedule the
appointment.
7.5.3 Both of the actions set out in section 7.5.1 must be completed in order to fulfil
this service quality requirement.
7.5.4 This requirement does not apply if the appointment is missed due to the
failure of the customer or the representative of the customer to attend the
appointment.
Section 7.3.1, 7.3.3 & 7.4.1 of the DSC:
7.3.1 When a customer or a representative of a customer requests an appointment
with a distributor, the distributor shall schedule the appointment to take place
within 5 business days of the day on which all applicable service conditions are
satisfied or on such later date as may be agreed upon by the customer and
distributor.
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7.3.3 Where the appointment in section 7.3.1 does not require the presence of the
customer or the customer’s representative, the distributor shall arrive for the
appointment on the day scheduled under section 7.3.1.
7.4.1 When an appointment is either:
a. requested by a customer or a representative of a customer with a
distributor; or
b. required by a distributor with a customer or representative of a
customer, the distributor must offer to schedule the appointment
during the distributor’s regular hours of operation within a window of
time that is no greater than 4 hours (i.e., morning, afternoon or, if
available, evening). The distributor must then arrive for the
appointment within the scheduled timeframe.
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Tips
Example 4: Rescheduling a Missed Appointment
120 appointments not
completed on the
scheduled date
200 appointments not
completed within the
scheduled 4 hour window
320 missed
appointments
318 appointments
rescheduled as
required
Distributor A did not attempt to contact
the customer before the appointment
was missed in one case and did not
contact the customer within the next
business day in another case
 Total missed appointments: 120 + 200 = 320
 Total appointments rescheduled as required: 320 – 2 = 318
 Reschedule a Missed Appointment metric: 318 / 320 = 99%
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2.1.4.1 – Tables 6 & 7 – Telephone Accessibility & Abandon Rate
Table 6: Telephone accessibility – DSC 7.6
Table 7: Telephone call abandon rate – DSC 7.7
Table 6:
On Electronic Filing Form enter:
a) Total number of qualified incoming calls in each month;
b) Number of qualified incoming calls in each month for which the service
quality requirement set out in section 7.6 of the Distribution System
Code was met; and
c) Percentage of (b) with respect to (a).
The requirement must be met at least 65% of the time.
Table 7:
a) Total number of qualified incoming calls in each month;
b) Number of qualified incoming calls in each month that were
abandoned before they were answered as described in section
7.7.2 of the Distribution System Code; and;
c) Percentage of (b) with respect to (a).
The requirement must be met 10% or less.
Please see below for Tips on filing
Definitions from Section 7.1 of the DSC
•
“answered” means connected to a person that is a representative of the
distributor. Connection to a voice mailbox or an answering machine, or placing a
person in a queue, does not constitute answering.
•
“customer care telephone number” means any telephone number that is
dedicated exclusively to, and given to the public by the distributor for, the
purpose of contacting the distributor on matters concerning customer care,
including customer account enquiries and other customer service enquiries.
Where a distributor does not have a telephone number dedicated exclusively to
matters concerning customer care, any telephone number given to the public for
the purpose of making enquiries of the distributor shall be deemed to be a
“customer care telephone number”.
•
“qualified incoming calls” means calls that are received during the regular hours
of operation of a distributor’s customer call centre and are either:
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(a) telephone calls for which the customer normally reaches a customer service
representative directly or has been transferred to a customer care line by a
general operator; or
(b) telephone calls in which the customer has reached the distributor’s
Interactive Voice Response (“IVR”) system and selected the option of speaking
to a customer service representative.
•
The following are not “qualified incoming calls”:
(a) telephone calls that are abandoned by the customer prior to asking for a
customer service representative; and
(b) telephone calls for which the customer elects IVR self-service.
From Section 7.6 & 7.7 of the DSC:
7.6.1 Qualified incoming calls to the distributor’s customer care telephone number
must be answered within the 30 second time period established under section
7.6.3.
7.6.3 For qualified incoming calls that are transferred from the distributor’s IVR
system, the 30 seconds shall be counted from the time the customer selects to
speak to a customer service representative. In all other cases, the 30 seconds
shall be counted from the first ring.
7.7.2 For the purposes of section 7.7.1, a qualified incoming call will only be
considered abandoned if the call is abandoned after the 30 second period
established under section 7.6.1 has elapsed.
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Tips
Example 5: Telephone Accessibility and Telephone Abandon Rate
Distributor B received
50,000 calls to its customer
care number in the year
5,000 calls: The customers
were satisfied with the
information provided by the
IVR system
2,000 calls: The
customers
abandoned the
calls before
representative
answered
1,500 calls
abandoned by
customers
after 30
seconds wait
time
1,000 calls: The customers
abandoned calls before
selecting the option of
speaking to a representative
44,000 calls: The
customers selected the
option of speaking to a
representative
500 calls
abandoned by
customers
within 30
seconds
42,000 calls:
The customers
answered by a
representative
38,000 calls
answered by
representatives
within 30
seconds
4,000 calls
answered by
representatives
after 30 seconds



Total qualified incoming calls: 44,000
Total qualified incoming calls answered within 30 seconds: 38,000
Telephone Accessibility metric: 38,000 / 44,000 = 86%



Total qualified incoming calls: 44,000
Total qualified incoming calls abandoned after 30 seconds: 1,500
Telephone Call Abandon Rate metric: 1,500 / 44,000 = 3%
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2.1.4.1 – Table 8 – Written Response to Qualified Enquiries
Table 8: Written response to enquiries – DSC 7.8
Table 8:
On Electronic Filing Form enter:
a) Total number of qualified enquiries received in each month;
b) Number of qualified enquiries in each month for which the service
quality requirement set out in section 7.8 of the Distribution System
Code was met; and
c) Percentage of (b) with respect to (a).
The requirement must be met 80% of the time.
Please see below for Tips on filing.
Definitions from Section 7.1 of the DSC
•
“qualified enquiry” means an enquiry received by a distributor from a customer
or representative of a customer pertaining to the customer’s existing or
prospective service in which a written response is requested by the customer or
representative of the customer or determined by the distributor to be necessary.
A “qualified enquiry” does not include any of the following, which shall be
addressed in accordance with other applicable requirements: cable locate
requests; retailer Service Transaction Requests; and enquiries of a general
nature not relating specifically to service currently provided to a customer or to a
new service being requested by a customer.
Section 7.8 of the DSC:
7.8.3 The 10 business days shall be counted from the date on which any
conditions associated with the enquiry have been satisfied (such as the date of a
move where there is a request for a final statement of account) or, if there are no
such conditions, from the date of receipt of the enquiry.
7.8.4 A distributor may consider a written response to have been sent if the
distributor sends a written acknowledgement of receipt of the qualified enquiry and
includes a specific date in which a complete response to the qualified enquiry will
be provided.
7.8.5 A written response shall be deemed to have been sent on the date on which
it is faxed, mailed or e-mailed by the distributor.
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Tips
Example 6: Written Response to Enquiries
Distributor C
Total of 3,500 customer
enquiries in the year
1,500 enquiries were in the
form of emails and letters
1,000
customers
requested
written
responses
500 customers
did not request
a written
response
2,000 enquiries were made
by phone or in person
1,500
customers did
not request a
written
response
500 customers
requested a
written
response
Distributor C determined that a written response was
necessary for 500 enquiries
Distributor C’s total qualified enquiries for written
response = 1,000+500+500 = 2,000
Distributor C
mailed or
emailed 1,700
responses
within 10
business days
Distributor C
mailed or
emailed 200
responses
after 10
business days
For 100 cases, Distributor C
wrote to inform the customer
within 10 business days that
their responses would be sent
within 30 days.

Total qualified enquiries: 1,000 + 500 + 500 = 2,000

Total qualified enquiries that were responded by the distributor
within 10 business days: 1,700 + 100 = 1,800
 Written Response to Enquiries metric: 1,800 / 2,000 = 90%
…………………………………………………………………………………………………………….
Enquiries with no specific timeline per province or OEB:
At times, provincial regulation or the DSC prescribes a specific timeline for the processing of
certain requests. Customer enquiries, for which there is no specific timeline under provincial
regulation, or a code of the OEB, should be counted towards the ESQR for written enquiries.
For example, with respect to a request for an information package for a generation connection,
Section 6.2.3 of the DSC states that “A distributor shall promptly make available a generation
connection information package (the “package”) to any person who requests this package.”
Since a specific timeline is not prescribed in the code, a written enquiry requesting an
information package for a new generation connection could be counted as a qualifying enquiry
for the ESQR on written responses.
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2.1.4.1 – Tables 9 & 10 – Emergency Response
Table 9: Emergency response urban – DSC 7.9
Table 10:Emergency response rural – DSC 7.9
Tables 9 & 10:
On Electronic Filing Form enter:
a) Total number of emergency calls received in each month;
b) Number of emergency calls in each month for which the service
quality requirement set out in section 7.9 of the Distribution System
Code was met; and
c) Percentage of (b) with respect to (a)
The requirement must be met 80% of the time.
Please see below for Tips on filing.
Definitions from Section 7.1 of the DSC
•
“emergency call” means a call where the assistance of the distributor has been
requested by fire, ambulance or police services.
Section 7.9 of the DSC:
7.9.1 Emergency calls must be responded to within 120 minutes in rural areas and
within 60 minutes in urban areas.
7.9.3 The definition of “rural” and “urban” should correspond to the municipality’s
definition.
7.9.4 The arrival of a qualified service person on site will constitute a response.
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Tips
Example 7: Emergency Response
Distributor D received 500
emergency calls (calls requested
by fire, ambulance or police
services)
400 calls related to requests
in urban areas
350 calls:
qualified
service person
arrived on site
within 60
minutes
100 calls related to requests
in rural areas
50 calls:
qualified
service person
arrived on site
after 60
minutes
80 calls: qualified
service person
arrived on site
within 120
minutes
20 calls: qualified
service person
arrived on site
after 120 minutes



Total emergency calls - urban: 400
Total emergency urban calls responded within 60 minutes: 350
Emergency Response - Urban metric: 350 / 400 = 88%


Total emergency calls - rural: 100
Total emergency rural calls responded within 120 minutes: 80
Emergency Response - Rural metric: 80 / 100 = 80%

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2.1.4.1 – Table 11 – Reconnection Performance
Table 11: Reconnection performance standards – DSC 7.10
Table 11:
On Electronic Filing Form enter:
a) Total number of reconnections in each month;
b) Number of reconnections in each month for which the service
quality requirement as set out in section 7.10 of the Distribution
System Code was met; and
c) Percentage of (b) with respect to (a)
The requirement must be met 85% of the time.
Please see below for Tips on filing.
Section 7.10 of the DSC:
7.10.1Where a distributor has disconnected the property of a customer for nonpayment, the distributor shall reconnect the property within 2 business days, as
defined in section 2.6.7, of the date on which the customer:
(a) makes payment in full of the amount overdue for payment as specified in the
disconnection notice; or
(b) enters into an arrears payment agreement with the distributor referred to in
section 2.7.1A.
Section 2.6.7 of the DSC:
2.6.7 For the purposes of section 2.6, a distributor shall apply the following rules
relating to the computation of time:
(a) where there is reference to a number of days between two events, the days
shall be counted by excluding the day on which the first event happens and
including the day on which the second event happens;
(b) where the time for doing an act expires on a day that is not a business day, the
act may be done on the next day that is a business day;
(c) where an act, other than payment by a customer, occurs on a day that is not a
business day, it shall be deemed to have occurred on the next business day;
(d) where an act, other than payment by a customer, occurs after 5:00 p.m., it shall
be deemed to have occurred on the next business day; and
(e) receipt of a payment by a customer is effective on the date that the payment is
made, including payments made after 5:00 p.m.
For the purposes of this section, a “business day” is any day other than a Saturday
or a holiday as defined in section 88 of the Legislation Act, 2006
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Tips
Example 8: Reconnection Standards
Distributor E Total of 500
customers disconnected for nonpayment in the year
410 customers paid the
outstanding arrears
40 customers entered into
an arrears payment
agreement
10 customers
were not
reconnected
within 2
business days
of paying
arrears
400 customers
were
reconnected
within 2
business days
of paying
arrears
35 customers
were
reconnected
within 2 business
days of entering
into an arrears
payment
agreement
50 customers did not pay
outstanding arrears or enter
into an arrears payment
agreement
5 customers were
not reconnected
within 2 business
days of entering
into an arrears
payment
agreement

Total number of customers who paid arrears or who
entered into an arrears payment agreement: 410 + 40
= 450

Total number of customers reconnected within 2
business days of paying arrears or entering into an
arrears payment agreement: 400 + 35 = 435

Reconnection Standard metric: 435/450 = 97%
Full disconnection:
For the ESQR Reconnection Performance Standards, the disconnection refers to a full
disconnection of power.
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2.1.4.1 – Table 12 – Micro-embedded Generation Facilities
Table 12: Micro-embedded generation facilities – DSC 6.2.7
Table 12:
On Electronic Filing Form enter:
a) Total number of new micro-embedded generation facilities
connected in each month;
b) Number of new micro-embedded generation facilities connected in
each month for which the service quality requirement as set out in
section 6.2.7 of the Distribution System Code was met; and
c) Percentage of (b) with respect to (a)
The requirement must be met 90% of the time.
Please see below for Tips on filing.
Section 6.2.7 of the DSC:
6.2.7 The distributor shall connect the applicant’s micro-embedded generation
facility to its distribution system within 5 business days, or at such later date as
agreed to by the applicant and the distributor, of the applicant informing the
distributor that it has satisfied all applicable service conditions and received all
necessary approvals, providing the distributor with a copy of the authorization to
connect from the ESA, entering into a Connection Agreement in the form set out in
Appendix E and paying the distributor for the connection costs, including costs for
any necessary new or modified metering.
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Tips
Example 9: New micro-embedded generation facilities
Distributor F Connected
100 new micro-embedded
generation
facilities in the year
15 applicants had agreed to
a date with the distributor for
completing the connection
14 connections were
completed on the
date agreed by
customers
1 connection was
completed after the
date agreed to with
the customer
85 applicants did not ask for
a connection date
83 connections were
completed within 5
business days from
the date on which all
conditions per DSC
Section 6.2.7 were
met
2 connections were
completed after 5
business days from
the date on which all
conditions were met

Total number of connections of new micro-embedded generation facilities: 100

Total number of facilities connected within 5 business days or at a later
date agreed by customers: 14 + 83 = 97

Connection of new micro-embedded generation facilities: 97/100 = 97%
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2.1.4.2 – Service Reliability
2.1.4.2 Reliability
Content
The RRR input forms in this section are redesigned to include the complete collection of
information required for reporting under RRR sections 2.1.4.2.5, 2.1.4.2.6 and 2.1.4.2.7.
As a result of new forms to capture the reporting of specific Cause Codes, information
previously requiring input entries for the RRR sections 2.1.4.2.1, 2.1.4.2.2, 2.1.4.2.3 and
2.1.4.2.4 are now auto-calculated and auto-populated.
•
New on Form
New: Tab titled “Cause Codes” requires completion of outage information for each type of
cause code from 0 to 9. Please note that the entries for the average number of customers are
required for any one of the Cause Codes. Once the entries for average number of customers
for any Cause Code are made and saved, the fields for average number of customers for
remaining Cause Codes will be automatically populated.
New: Tab titled “Reliability Summary” auto-calculates the overall and adjusted SAIDI/SAIFI
measures from the cause code information entered.
New: Tab titled “New Practices” requires reporting in accordance with RRR sections 2.1.4.2.6
and 2.1.4.2.7 requirements on
• new measuring and reporting practices with respect to reliability, and
• identification of outage start times
Deleted: Table for collecting MAIFI information
Tips
The formulas for calculation of SAIFI and SAIDI are provided in the Electricity RRR Document.
Please note that in order to see the calculated numbers you must select NO or YES in the
Submit box, and then SAVE or SAVE & EXIT.
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2.1.5 –Performance Based Regulation (PBR) - General Tips related to RRR
2.1.5 Performance Based Regulation
General Tips
General:
1. The 2.1.5 form will appear on your portal only after the document asking for “Consent to
File with Statistics Canada” is completed. Information about the consent form and the
data sharing agreement with Statistics Canada is available at
http://www.ontarioenergyboard.ca/documents/oeb_statisticscanada_initiative.pdf and at
http://www.ontarioenergyboard.ca/documents/tools/efiling/statscan_signed_agreemen
t_2008.pdf.
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2.1.5.1 - Labour
2.1.5.1 Labour
Content
Labour:
Line crew wage rate (average)
Effective date of new line crew wage rate
New line crew wage rate (average)
Number of full-time equivalent employees
Information required for completing Statistics Canada’s “Annual Electric Utility Financial
Report” by OEB on behalf of electricity distributors:
• Average number and salaries of employees whose wages are charged to current
operating expense
• Average number and salaries of employees whose wages are charged to new
construction
New on form
No changes.
Tips
FTE – Contract staff:
Contract staff on the distributor payroll should be included in the FTE count. The same goes
for paid summer students, Co-ops and interns. Third party contractors that are not on the
distributor payroll should not be included in the FTE count.
………………………………………………………………………………………………………………
FTE – Yearbook:
The number of full-time equivalent employees reported in this section is published in the
Electricity Distributors’ Yearbook.
………………………………………………………………………………………………………………
Multiple categories of line crew:
For distributors with multiple categories of line crews an acceptable approach is to calculate
total line crew wages / Full time equivalent line crew employees.
……………………………………………………………………………………………………………
Effective date:
For distributors where there is more than one line crew wage rate in effect the effective date
is the latest date when the wage rate was changed.
Example
Example 1: Labour
Full Time Equivalent employee calculation:
The distributor employs 10 full time and 5 part time (half time) employees. In addition,
in the current calendar year, 3 employees were employed part-time as follows:
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Employee #1: Jan – Mar for 3 months
Employee #2: Feb – August for 6 months, and
Employee #3: Mar – Oct for 8 months.
Number of Full Time Equivalent employees (FTEs)
= Sum of (employee x % year worked)
= (10 employees x 100%) + (5 employees x 50%) + (1 employee x 25%) + (1 employee x
50%) + (1 employee x 67%)
= (10 + 2.5 + 0.25 + 0.5 + 0.67) FTEs
= 13.92 full time equivalent employees
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2.1.5.2 - Capital
2.1.5.2 Capital
Content
Capital:
Changes in gross capital assets (all) consisting of:
• Capital additions
• Retirements/write offs/sales/asset impairment losses
• Contributed capital, and
• Other
Changes in gross capital assets (high voltage only), consisting of:
• High voltage capital additions
• High voltage retirements/write offs/sales/asset impairment losses
• High voltage contributed capital, and
• High voltage other
Capital expenditures, consisting of:
• Direct labour (including benefits etc.)
• Equipment and materials
• Capitalized overhead
• Contract services
• Other
New on Form
There is no change to the required content for the filing.
Tips
Gross Capital Additions:
Electricity distributors are required to separately report the total capital additions and high
voltage (HV) assets additions.
RRR 2.1.5 Capital tab, Section A) Total Capital Additions (including high voltage assets)”
should include gross capital additions for the current year, contributed capital and
retirements/write offs/sales/asset impairment losses and exclude CWIP.
RRR 2.1.5 Capital tab, Section A) High Voltage Capital Additions Only:
HV assets are those assets that are used for conveying electricity at voltages higher than 50
kilovolts. These assets are regarded as HV assets, regardless of whether or not they have
been deemed as distribution assets or regardless of where their financial information are
recorded and reported in the distributor’s trial balance accounts (RRR 2.1.7). HV assets are
used in connection with “electricity transmission lines” which means a line, transformers,
plant or equipment used for conveying electricity at voltages higher than 50 kilovolts (see
Section 89 of the OEB Act).
At present, the electricity distributors are required to separately report the HV assets without
any allocation of common costs. The expenditures that are common to HV assets and low
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voltage (LV) assets are not to be allocated to these assets. The allocation of common costs
between HV assets and LV assets may be subject to a future review. At present, only HV
assets without any allocation are to be reported separately under Section RRR 2.1.5.2. a).
Retirements/write offs/sales/asset impairment losses:
This requires the reporting of the dollar amount of capital retired, written off, sold or impaired
(i.e.; gross asset value removed from PP&E). This figure should not reflect proceeds or net
book loss/gain.
Capital Expenditure:
RRR 2.1.5 Capital tab, Section B) “Capital Expenditure” should not include CWIP or assets
acquired through contributed capital. The intent of Capital Expenditure is to provide a
distributor’s spending on capital additions for the reporting year broken down by direct
labour, equipment and material, capitalized overhead, contract services, etc.
Capitalized overhead:
The reporting on capitalized overhead includes is based on each distributor’s capitalization
policy for overhead capitalized in PP&E. This may include overhead charges or labour or
both, according to the capitalization policy.
OEB’s Notice on changes to capital reporting:
For further information on changes to the capital section, please refer to the OEB’s notice of
RRR amendments addressed to all licensed electricity distributors dated March 7, 2014.
Business Rule:
If a figure is entered in "Other", must enter text in Other description or form will not submit.
Example:
The example below illustrates how the capital assets data from a distributor’s records is used
to calculate the “Change in Gross Capital Assets” under “Total Capital Additions”, and how
this information is entered in the form.
In 2014, assume a distributor’s records show capital assets information as follows: gross
capital additions for the current year are $700,000; contributed capital received is $50,000;
retirements in the current year are $150,000 and there were no other values.
The “Change in Gross Capital Assets” for the current year is calculated as follows:
i.
Gross capital additions for the current year:
$700,000
ii.
Less: Retirements/write-offs/sales/asset impairment losses: $(150,000)
iii.
Less: Contributed capital:
$(50,000)
iv.
Less: Other – value:
$0
Change in Gross Capital Assets for the Current Year: $500,000
The information from the distributor’s records outlined above is entered in Section A) “Total
Capital Additions (including high voltage assets)” of the form, as follows:
Gross capital additions for the current year:
Retirements/write-offs/sales/asset impairment losses:
Contributed capital:
Other:
Please note that the numbers in this example are inputted as positive numbers in the form.
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2.1.5.3 – Supply & Delivery
2.1.5.3 Supply & Delivery
Content
A) Supply
i.
Total kWhs of electricity that has flowed into the distributor's distribution
system from the IESO-controlled grid including long-term load transfer
supplied, or flowed into the distribution system of a host distributor
ii.
Total kWhs of electricity that has flowed into the distributor’s distribution
system from all embedded generation facilities
B) Delivery
i.
Total kWhs of electricity delivered to all customers in the distributor’s licensed
service area and to any embedded distributors.
ii.
Total kWhs of electricity delivered on long-term load transfer arrangements.
C) Distribution Losses
Distribution Loss in kWhs: Calculated by taking the sum of A(i) and A(ii) to arrive at
total supply and reducing it and reducing it by deliveries reported at B(i) and B(ii).
D) Amount Charges ($)
Amount charged by any host distributor for transmission or low voltage service in the
year.
New on Form
New: Box B(ii) – see above – for capturing long-term load transfer information is new.
Tips
No loss-adjustment:
All kWhs reported in 2.1.5 (other than in relation to distribution losses) are reported
based on a reading of the applicable meter, without being grossed up for loss factor.
Unbilled adjustment:
To match the reporting period of January 1 to December 31 of the year, supplied kWhs
and delivered kWh should be adjusted for unbilled kWh.
Supply A(i):
Under section A i) “Total kWhs of electricity that has flowed into the distributor’s
distribution system from the IESO-controlled grid, including long-term load transfer
supplied, or the distribution system of a host distributor” the kWhs reported should also
include kWhs related to an embedded wholesale market participant (WMP).
Host distributor charges in (D):
A host distributor is a distributor that supplies transmission services to other
distributors. This section is asking for the amount charged by a host distributor to an
embedded distributor for transmission or low voltage services, not electricity charges or
delivery charges. For example, if an LDC is embedded with Hydro One this would
include the costs invoiced to the LDC for Network, Connection and Low Voltage
(“Common ST Line”) charges.
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Long-Term Load Transfer Arrangements:
From Feb 20, 2015 Notice of Proposal to Amend a Code: Proposed Amendments to
the Distribution System code: Board File No.: EB-2015-0006, page 1:
“A load transfer arrangement involves two distributors. One is referred to as the
geographic distributor and the other is referred to as the physical distributor. While the
customer (“load transfer customer”) is located in the licensed service area of the
geographic distributor, the load transfer customer is physically connected to the
physical distributor’s distribution system because the geographic distributor does not
have existing assets in close proximity to serve the load transfer customer. It is
therefore the physical distributor that provides the delivery of electricity to the load
transfer customer. However, the customer is billed by the geographic distributor (i.e.
pays geographic distributor’s distribution rates which may be higher or lower than
physical distributor’s rates).”
Only the physical distributor, as defined by the DSC, is required to report the LTLT kWh
under RRR 2.1.5.3 sections A(i) and B(ii). The geographic distributor is not required to
report the LTLT kWh under RRR 2.1.5.3 sections A(i) and B(ii).
Example:
Distributor 1
i.e. the
PHYSICAL
distributor
Delivers
Distributor 2
Bills
i.e. the
GEOGRAPHIC
distributor
Customer within Geographic service area of
Distributor 2
•
Distributor 1 reports the delivered kWhs in box B(ii) in the Supply &
Delivery section of the 2.1.5 input form.
•
Distributor 2 does not report any kWhs in box B(ii) in the Supply & Delivery
section of the 2.1.5 input form.
Business rule:
Distribution losses are calculated on the input form as the difference between the
supply as reported in A(i) and A(ii) less delivery as reported in B(i) and B(ii). The form
cannot be submitted unless this calculation is correct.
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2.1.5.4 – Demand & Revenue
2.1.5.4 Demand & Revenue
Content
The information collected in RRR 2.1.5.4 is intended to capture detailed information
on the revenues and energy-related billing determinants (i.e. demand kW and
consumption kWh) within each of a distributor’s own specific rate classes. As with
RRR 2.1.2, this information is filed in order to enable further streamlining of the
application process for formulaic adjustments to rates during an incentive rate-setting
period. In addition, the information will be automatically tabulated at the generic rate
class level that is customary for the RRR.
Table 0: SSS Metered Consumption by Rate Class – this table requires input by distributorspecific rate class.
Table 1: SSS Metered Consumption by Generic Rate Class – this table is auto-populated
when Table 0 is completed and the form is Saved. It contains annual consumption for
distribution customers (SSS only) broken down by:
• a) Metered consumption for customers on RPP kWh, by rate class
• b) Metered consumption for customers on RPP kW, by rate class
• c) Metered consumption for customers not on RPP kWh, by rate class
• d) Metered consumption for customers not on RPP kW, by rate class
• Auto-calculated column for total consumption for distribution customers kWh (a+c), by
rate class
• Auto-calculated total consumption for distribution customers kW, by rate class (b+d)
Energy Sales with each Retailer: This section requires input into individual forms for each
retailer. The forms require information on
• Metered consumption in kWhs, by generic rate class
• Metered consumption in kW, by rate class by generic rate class
Table 2a: Auto-calculated table which aggregates consumption from retailer customers, by
generic rate class.
Table 2b: This table requires aggregation of all retailer demand and consumption by
distributor-specific rate class. Aggregation must be performed manually for each detailed rate
class. The information in Table 2b is vital to ensure that Table 3a is complete.
Table 3a: Total metered demand and consumption (SSS + retailer customers). This is an
auto-calculated table which aggregates tables 1 & 2b. This table calculates total metered
demand and consumption for all distributor-specific rate classes.
Table 3b: The first two columns of this table are auto-calculated with total metered demand
and consumption by generic rate class. The third column for annual billings by rate class
requires manual input.
Table 4: Wholesale market participant information.
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New on form
New: Reporting by distributor-specific rate classes:
Previously, the OEB requested distributors to report information for rate classes on an
aggregate level that was common to all distributors (e.g., Residential, GS < 50 kW, GS > 50
kW, etc.). Effective for the 2014 fiscal year reporting, the data input forms are formatted for
the input of information specific to a distributor’s approved set of rate classes. Distributors will
input and report information at this level of detail. This additional information is intended to
enable further streamlining of the application process for formulaic adjustments to rates
during an incentive rate-setting period.
New: The table for wholesale market participant information is new. The information was
previously captured through an additional row in tables 1, 2 and 3. There is no change in the
content of the filing.
Tips
Unbilled:
The metered kWhs reported in this subsection represent the consumption as read by
the meter, that is, it is not loss adjusted. The demand and supply under RRR 2.1.5.4
require the reporting of total annual metered consumption. This information should be
reported based on the actual consumption for the calendar year since any unbilled
year-end accruals would have been reversed, and thus the actual consumption would
be known to distributors by the time of their filings in April.
No loss adjustment:
Section 2.1.5.4.1 of the RRR came into effect on January 1, 2013. All energy sales are
required to be reported on a non-loss adjusted basis. The notice for the changes was
issued on December 20, 2012 and on page 3 it states, “Although the electricity charge
on customer bills is currently calculated on a loss-adjusted basis, this data is required
to be provided on a non-loss-adjusted basis so that the total reflects the kilowatt-hours
or kilowatts actually delivered.”
Retailer-enrolled customers and “Not on RPP”:
Table 1 does not include any information for Retail customers. The “Not on RPP”
phrase means “Utility (SSS) customers who are not on RPP” i.e.; those paying hourly
pricing.
Reporting of kW and kWhs:
Please note that when the distributor bills in kWhs, only kWhs are to be reported.
When the distributor bills in kWs, then both kWs and kWhs are to be reported.
Annual billings:
Please note that annual billings are a breakdown of the 4080 account balance by rate
class. The total distribution revenue for all rate classes should equal account 4080 on
the trial balance.
Business Rules:
•
If metered consumption reported (in kW or kWh), then annual billings for that rate
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class must be reported i.e. both cells for metered consumption and annual billings
must have a value.
•
If annual billings reported then should report metered consumption reported (in
kW or kWh), for that rate class i.e. both cells for metered consumption and annual
billings must have a value.
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2.1.5.5 – Utility Characteristics
2.1.5.5 Utility Characteristics
Content
A) Licensed Service Area
• Total service area (sq. km.)
• Rural service area (sq. km.)
• Urban service area (sq. km.)
B) Maximum Monthly Peak Load (kW)
• Utility winter max monthly peak load (kW) with embedded generation
• Utility winter max monthly peak load (kW) without embedded generation
• Utility summer max monthly peak load (kW) with embedded generation
• Utility summer max monthly peak load (kW) without embedded generation
C) Average Peak Load (kW)
• Average peak load with embedded
• Average peak load without embedded
D) Average Load Factor
• Average load factor with embedded
• Average load factor without embedded
E) Total Circuit Kilometers of Line
• Circuit kilometers of line (auto-calculated sum)
• Overhead circuit kilometers of line
• Underground circuit kilometers of line
F) Circuit Kilometers of Line by Type
• 3 phase
• 2 phase
• Single phase
• Total of all phases (auto-calculated sum)
G) Number of Distribution and Transmission Stations
• Distribution and Transmission Stations
 Number of stations classified as >= 50 kV
 Number of stations classified as < 50 kV
 Number of stations in total
• Transformers at Stations >= 50 kV
 Number of transformers >=50 kV at stations classified as >= 50 kV
 Number of transformers < 50 kV at stations classified as >= 50 kV
 Total number of transformers at stations classified as >= 50 kV
• Transformers at Stations < 50 kV
 Number of transformers >=50 kV at stations classified as < 50 kV
 Number of transformers < 50 kV at stations classified as < 50 kV
 Total number of transformers at stations classified as < 50 kV
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New on form
New: Layout for collection transformer information in g) above has been improved. There is
no change to the data contents of the filing.
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2.1.5.5 b, c & d – Peak load, Average load & Average load factor
Monthly peak, Average Peak & Average Load Factor
Tips
FIT and micro-FIT:
Please also note that FIT and micro-FIT contracts are included in the calculation of
peak loads.
Average load factor:
The utility average peak load refers to the annual average hourly peak load. The
average peak load based on daily peak loads may be used to determine the average
load factor.
Business Rules:
Maximum Monthly Peak Load (kW): “Utility Winter Max Monthly Peak Load with
embedded generation”, “Utility Winter Max Monthly Peak Load without embedded
generation”, Utility Summer Max with Embedded” and “Utility Summer Max without
Embedded” must be greater than 0 and cannot be 0 or blank.
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2.1.5.5 e & f – Circuit kilometers of line
Circuit Kilometers of Line – Under/Overground & By Type
Tips
CEA definition:
Circuit Kilometers - refer to the Canadian Electricity Association website for the
definition
(http://www.electricity.ca/media/pdfs/Performance%20Excellence/Circuit%20Length%
20Definition%5B1%5D.pdf).
Circuit kilometers per CEA:
For clarity, circuit length is distinct from conductor length in that one or more
conductors may be employed to create a circuit. CEA’s intention is to report circuit
length. The best analogy is to consider a single line diagram representation. For
instance, a 1 km long three-phase grounded interconnection between two points which
is built with one conductor per phase plus one neutral conductor has a total of 4 km of
conductor; however, it is only 1 km long circuit (CEA).
Totals:
The total overhead and underground circuit kilometers of line should be equal to the
total of all phases (3 phase, 2 phase, and single phase).
Submarine cables:
Submarine cables are reported in the underground cables category.
Example
Utility Characteristics - Circuit Kilometers of Line
The total distance of the feeders is 7,225 kilometers. 1,800 kilometers of the feeders are
three phase, 425 kilometers is two phase and 5,000 kilometers is single phase. There is
no over build or under build of single, two phase and three phase lines in the utility’s
service territory.
5,500 kilometers of line is overhead, 1,725 kilometers is underground. There is also no
overlapping between overhead and underground wiring and all cables are in their own
trench.
Reporting:
1 phase
2 phase
3 phase
Total
Overhead Cir Km
4,000
300
1,200
5,500
Underground Cir Km Total Circuit KM
1,000
5,000
125
425
600
1,800
1,725
7,225
Example 2a: Utility Characteristics - Circuit Kilometers of Line with overbuild
Using example 2’s data with overbuild for ALL 3 phase Overhead conductor the circuit
kms become twice their original size. This means there are 2 – 3 phase circuits on the
same set of poles.
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Reporting:
1 phase
2 phase
3 phase
Total
Overhead Cir Km
4,000
300
2,400
6,700
Underground Cir Km Total Circuit KM
1,000
5,000
125
425
600
3,000
1,725
8,425
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2.1.5.5 g – Station types & transformers
Distribution & Transmission Stations & Transformers
Tips
Reporting in prior years:
Distributors should continue reporting the number of Distribution and Transformer
Stations as they have done in previous years.
Station classification:
The classification of stations in each category is at the discretion of the distributor.
Transformers:
The OEB also requires the number of transformers within each station type. Each
transformer station reported can have more than one transformer, e.g. three single
phase transformers.
Transformer classification:
The transformers within each station type are reported according to the classification of
the individual transformer as greater than or equal to 50 kV or less than 50 kV within
the station. The classification of the individual transformer is based on the output
voltage of the transformer.
Ownership criterion:
For further clarity, this reporting includes transformer stations that are owned by the
distributor. Please do not report any transformer stations if you do not own, as may
happen with some embedded distributors, or where the transformer stations are owned
by utility’s customer. The utility is expected to report all transformer stations that it owns
including the transformers that may be located on customer’s site.
Example
A: Utility Characteristics – Distribution & Transmission Stations A
distributor has two stations, each with two transformers as follows:
Station #1 contains a 230 kV transformer and a 44 kV transformer.
Station #2 contains a 44 kV transformer and a 13.8 kV transformer.
Under RRR Section 2.1.5.5 g):
Station #1 will be reported in the category “Greater than or equal to 50
kV.” Station #2 will be reported in the category “Less than 50 kV.”
B: Utility Characteristics – Transformers within Stations
Transformers within the two categories of stations (>50kV and <50 kV) will be reported as:
Transformers within stations greater than or equal to 50 kV: 2 in total
• 1 transformer in the category greater than or equal to 50 kV
• 1 transformer in the category less than 50 kV
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Transformers with stations less than 50 kV: 2 in total
• 0 transformers in the category greater than or equal to 50 kV
• 2 transformer in the category less than 50 kV
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2.1.5.6 – Regulated Return on Equity (ROE)
2.1.5.6 Regulated Return on Equity (ROE)
Content
Calculation of Rate of Return on Equity on a Deemed Regulatory basis.
New on form
Calculation template is now in a form provided in the RRR portal instead of an excel
spreadsheet. Hence, there is no requirement to email the calculation on an excel spreadsheet
to the OEB.
Comment boxes are provided against each input cell to enable the distributor to provide any
clarifications or explanations for the numbers used in the ROE calculation.
Inputs required to complete the calculation:
From trial balance & audited financial statements (RRR 2.1.7 & 2.1.6):
1. Net income
2. Future/deferred taxes
3. Non rate regulated items
4. Cost of power
5. Operating expenses
6. Opening fixed Assets (net book value)
7. Closing fixed assets (net book value)
8. Interest expense
From last cost of service proceeding:
1. OEB-approved working capital allowance percentage
2. OEB-approved capital structure – short term debt percentage
3. OEB-approved capital structure – long term debt percentage
4. OEB-approved capital structure – deemed equity percentage
5. OEB-approved deemed return on equity percentage
6. OEB-approved short term debt rate
7. OEB-approved long term debt rate
8. Utility tax rate from last OEB proceeding (IRM or CoS)
Tips
Excel before portal:
In 2015, the ROE calculation will also be submitted within the RRR portal. The
calculation in the RRR portal is the same as the calculation on the Excel template
posted on the OEB website. It is recommended that distributors complete the Excel
template before completing the data entry of the calculation requirements in the RRR
portal.
Reminder:
The OEB reminds distributors that the Report of the Board on 3rd Generation Incentive
Regulation for Ontario’s Electricity Distributors (the “IR Report”) issued on July 15,
2008 established a trigger mechanism with an annual ROE dead band of ±300 basis
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points. When a distributor performs outside of this earnings dead band, a regulatory
review may be initiated. The OEB intends to use the information filed by distributors
under RRR Section 2.1.5.6 to assess if further action is warranted. The Achieved and
Deemed ROE% appears on the distributor’s scorecard.
Net income:
Regulatory net income should include all one-time or unusual events such as PILS
disposition amounts, LRAM, Smart meter dispositions etc. that have flowed into the
income statement. Any unrealized gains/losses on bank loan swaps should also be
reported as part of the regulatory net income in the ROE calculation template,
especially if these were considered at the time of setting short and long term debt rates
in the last cost of service (CoS) proceeding.
Please note that unless the OEB has authorized inclusion of certain costs or revenues
in the CoS proceeding, the distributor is expected to follow reporting of cost according
to the accounts specified on the form and should not include those certain costs or
revenues in the calculation of actual ROE.
Non rate-regulated income/expense:
Non rate-regulated income/expense should not be included in the ROE calculation
unless authorized by the OEB to be included in the revenue requirement in the last
Cost of Service proceeding.
Additional information:
Distributors are encouraged to use the comment boxes provided on the ROE form to
explain and include financial information for any unusual items that would generally not
otherwise be included as part of the information being reported (see one-time events
above in Net Income), and as such, could be used to subsequently “normalize” the
data in the ROE calculation. The reporting of this information is very useful to OEB
staff conducting analysis and presenting findings on review of distributors’ achieved
ROE.
Future/deferred taxes:
Future/deferred taxes shown on the ROE calculation should match the balance in
account 6115 (provision for future income taxes) in the regulatory trial balance
submitted to the OEB under RRR Section 2.1.7. Future/deferred taxes shown on the
income statement of the audited financial statements (AFS) should be shown in
account 6115 and on the ROE calculation as this impacts the reported net income for
the year.
Any future/deferred tax amounts not appearing on the income statement of the AFS
should be reported in RRR Section 2.1.7 on the balance sheet (account 2205 for
example) and not in account 6115. These tax amounts do not impact the regulatory
net income, and hence do not appear on the ROE calculation.
Donations:
Please note that donations cannot be deducted from operating costs for purposed of
the ROE calculation. Only LEAP donation may be deducted.
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Common errors:
1
Net Income
Difference
Nature of error
Caused by removing from Net Income, disposition amounts for LRAM, smart meter and
PILS, and in some cases unrealized gain on interest rate swaps. These should be left in the
net income to match the income reported in the trial balance.
Including certain revenues and costs that the OEB did not approve in the distributor’s last
CoS application such as the revenues and costs for water and sewage related activities, etc.
2
Future Tax
Difference
Caused by entering the future tax with the wrong sign, or the future tax amount did not match
the balance in 6115, or the future tax amount was reported on the Audited Financial
Statements but not reported in 6115, or the future tax amount was a future tax liability on the
AFS balance sheet, but was incorrectly shown as a future tax amount in 6115.
3
Non-Utility
Difference
Caused by not inputting non-utility amounts in the template, or by including LRAM, smart
meter and PILS disposition amounts as non-utility amounts, or non rate-regulated
income/expense is not consistent with the authorized revenue requirement in the last cost of
service proceeding.
4
COP Difference
Cost of Power inputted does not match to the sum of accounts listed under "Staff
Comments."
5
Operating Expense
Difference
Operating expense inputted does not match to the sum of accounts listed under "Staff
Comments."
6
Avg. Fixed Assets
Difference
7
Interest Expense
Difference
AFS fixed assets were commonly used, these did not match to the fixed assets as reported
in the yearbook of electricity distributors. Non-regulated assets were included as well. WIP
may have been included.
Interest expense - Incorrect amount, or omitted.
8
Working Capital
Allowance
Difference
Approve ROE
Difference
Short-term Debt
Rate Difference
Working capital allowance % - Discrepancy between staff and distributor percentages.
11
Long-term Debt
Rate Difference
Long term debt rate % - Discrepancy between staff and distributor percentages.
12
Tax Rate Difference
Tax Rate - Discrepancy between staff and distributor percentages.
9
10
Approved ROE % - Discrepancy between staff and distributor percentages.
Short term debt rate % - Discrepancy between staff and distributor percentages.
Example
An example of the completed ROE calculation is provided on the OEB website.
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2.1.6 – Audited Financial Statements
2.1.6 Audited Financial Statements (AFS)
Content
Audited Financial Statements (AFS) for the preceding calendar year.
New on form
New: This year, the AFS will be uploaded into the RRR portal. The AFS should not be
sent by email/mail to OEB staff or to the Board Secretary’s office. In case of any
difficulties with the upload, please contact ITHelp at [email protected]
Tips
Format:
Please ensure your statements are in searchable PDF format. You may not be able to
upload the audited financial statements for the purpose of the filing if the statements
are created by scanning from a printer. Word or Excel documents cannot be submitted.
The PDF file must be generated from a software.
Only one version is submitted to the Board. If multiple uploads are made, the latest
version will override previously uploaded versions. Alternatively, to remove an attached
file, click on the “x” to delete the row and click save.
Size & Path:
The file size must be less than 2 GB, and the file name (including path) should be less
than 255 characters in order to upload.
Business Rule:
Must attach a PDF document or cannot submit filing.
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2.1.7 – Trial Balance
2.1.7 Trial Balance
Content
Trial balance in the format specified in the Accounting Procedures Handbook for Electricity
Distributors.
New on form
New: The following accounts have been added/deleted to the Trial Balance for reporting
under MIFRS and CGAAP:
Added:
1557
Meter Cost Deferral Account
1508
Sub-account (Incremental Capital Expenditures) Accumulated Depreciation
2105
Sub-account Accumulated Depreciation for Specifically Identified Asset
Accounts
1595
Sub-account Principal Balances Approved in 2014
1595
Sub-account Carrying Charges Approved in 2014
1595
Sub-account Carrying Charges for Net Principal in 2014
Deleted:
1508
1508
1592
1595
Sub-account Incremental Capital Charges
Sub-account Financial Assistance Payment and Recovery variance - Ontario
Clean Energy Benefit
Sub-account HST/OVAT Input Tax Credits
Sub-account Principal Balances Approved in 2013 – comment – are there no
utilities with residual balances in these accounts or have all LDCs disposed of
final residual balances?
1595
Sub-account Carrying Charges Approved in 2013
1595
Sub-account Carrying Charges for Net Principal in 2013
A new tab has been created for reporting of Group 1 account balances. Distributors are to
input the principal and interest balances separately at the fiscal-year end for each account
in the designated fields in a new form. This additional information is intended to enable
further streamlining of the application process for formulaic adjustments to rates during an
incentive rate-setting period.
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Account Description
LV Variance Account
Smart Metering Entity Charge Variance Account
RSVA - Wholesale Market Service Charge
RSVA - Retail Transmission Network Charge
RSVA - Retail Transmission Connection Charge
RSVA - Power (excluding Global Adjustment)
RSVA - Global Adjustment
Disposition and Recovery/Refund of Regulatory Balances
Disposition and Recovery/Refund of Regulatory Balances
Disposition and Recovery/Refund of Regulatory Balances
Disposition and Recovery/Refund of Regulatory Balances
Disposition and Recovery/Refund of Regulatory Balances
Disposition and Recovery/Refund of Regulatory Balances
Disposition and Recovery/Refund of Regulatory Balances
(2008)
(2009)
(2010)
(2011)
(2012)
(2013)
(2014)
Account Principal Interest
Number
(A)
(B)
1550
1551
1580
1584
1586
1588
1589
1595
1595
1595
1595
1595
1595
1595
Total Balance
(A+B)
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Tips
To see form:
The 2.1.7 form will appear on your portal only after the document asking for “Consent to
File with Statistics Canada” is completed. Information about the consent form and the
data sharing agreement with Statistics Canada is available on the OEB website.
Accounting Standard:
The RRR 2.1.7 Trial Balance provides two separate trial balances, as shown in the
“Accounting Standard Menu Selection” drop-down menu. Distributors shall use this
menu depending on the accounting standard that the distributor was approved to use
for ratemaking and regulatory accounting and reporting to the OEB.
If your last distribution rates were set using MIFRS, as discussed below, you should
choose the MIFRS option. If this was not the case, you should choose the Canadian
GAAP/ASPE/US GAAP option as discussed below.
Once the choice for the trial balance is made, and the form is saved, the appropriate
trial balance for your use will be generated by the system. Once the form is generated,
the same template will appear every time you access the system. It is not possible to
change your choice of accounting standard once the trial balance has been generated.
MIFRS:
Distributors that have filed cost of service applications on a fully Modified International
Financial Reporting Standards (MIFRS) basis, which was approved by the OEB, and
therefore whose distribution rates are set under MIFRS should use the MIFRS trial
balance. This trial balance is based on the chart of accounts (Article 210) in the revised
2012 Accounting Procedures Handbook for Electricity Distributors.
CGAAP:
Distributors using Canadian GAAP, Accounting Standards for Private Enterprises
(ASPE), or distributors approved to use US GAAP for ratemaking and reporting
purposes shall use the trial balance “Canadian GAAP/ ASPE & USGAAP”.
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USGAAP:
Distributors reporting under US GAAP should note that while there are many similarities
as compared to reporting under previous Canadian GAAP, there may be instances
where the “old” trial balance may not include specified accounts for certain accounting
transactions under US GAAP. If this circumstance arises, these distributors should
advise the OEB by email, regarding the nature and type of transactions, and the
amounts and the account(s) that was used to report these amounts in the old trial
balance.
Input sequence:
Complete the income statement first, and ensure that the net profit/loss appears in
Account 3046 in the balance sheet, as well as in the “balancing factor” box on the trial
balance summary page.
Complete the Assets tab and the Liabilities and Equity tab after the income statement is
complete. This will ensure fewer error messages on saving during the process of entry,
before the input is complete on all tabs.
Sub-account tab:
The sub-accounts tab has been provided for distributors to report the balances for
specified sub-accounts. This template is applicable to all distributors whether reporting
under the MIFRS trial balance or the “CGAAP” trial balance.
Please report only sub-account balances in this separate stand-alone template. The
amounts reported for the sub-accounts are independent of, and are not “rolled up” or
added to their respective “control” account in either the MIFRS or old trial balance.
Saving and Submitting:
As the 2.1.7 form is large, it takes longer to open and save, as compared to other
smaller forms. In order to ensure that the form is saved, or submitted as desired, make
sure to check the Status box in the Report Summary section before exiting the form.
Sub-account 2105 (New):
With this March 2015 Guidance, the OEB established a sub-account under Account
2105 Accumulated Depreciation of Electric Utility Plant – Property, Plant and
Equipment, Sub-account Accumulated Depreciation for Specifically Identified Asset
Accounts, to record the total amount of accumulated depreciation or accumulated
amortization related to certain asset accounts. This sub-account will be reported in
RRR beginning in April 2015 for balances as at December 31, 2014. Grouping
accumulated depreciation in this sub-account will allow simpler analysis of net assets
and returns than is currently provided by data contained in RRR and financial
statements. The accounts below must be combined to determine the amounts to be
posted to the new sub-account.
A5. This sub-account will record the total amount of accumulated depreciation or
accumulated amortization related to the following detailed asset accounts:
Electric Plant in Service – Detailed Accounts
• B. Generation Plant
o 1615 Land
o 1616 Land Rights
o 1620 Buildings and Fixtures
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o 1630 Leasehold Improvements
• C. Transmission Plant
o 1705 Land
o 1706 Land Rights
o 1708 Buildings and Fixtures
o 1710 Leasehold Improvements
• D. Distribution Plant
o 1805 Land
o 1806 Land Rights (if applicable)*
o 1808 Buildings and Fixtures
o 1810 Leasehold Improvements
• E. General Plant
o 1905 Land
o 1906 Land Rights (if applicable)*
o 1908 Buildings and Fixtures
o 1910 Leasehold Improvements
o 1915 Office Furniture and Equipment
o 1920 Computer Equipment – Hardware
o 1925 Computer Software
o 1930 Transportation Equipment
*Accounts 1806 and 1906 are no longer in use under MIFRS, amounts previously
recorded in these accounts are to be recorded in Account 1612 under MIFRS.
Other Capital Assets
• 2005 Property Under Finance Leases
Business Rules:
• Sum of accounts
1005 +1010 +1020 +1030 +1040 +1060+ 1070
("cash & equivalents") cannot be less than 0 as a negative amount for these
accounts should be reported as a liability. Please reclassify the negative balance in
Accounts 1005-1070 to Account 2225 Notes and Loans Payable.
•
Sum of accounts 1200 and 1210 (intercompany receivables) cannot be less than 0
as any credit balances should be reported as a payable. Please reclassify this
credit balance in either Account 2240 or Account 2242.
•
Sum of accounts 2240 and 2242 (intercompany payables) cannot be greater than 0
as any debit balances should be reported as a receivable. Please reclassify this
debit balance in either Account 1200 or Account 1210.
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2.1.8 – Customer Service
2.1.8 Customer Service
Content
For the prior calendar year, the following data is required separately for residential customers
and eligible low-income customers:
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
Number of customer accounts
Number of customer accounts disconnected
Number of accounts in arrears
Dollar amount in arrears
Number of arrears payment agreements
Total owing under arrears payment agreements
Number of arrears payment agreements cancelled due to non-payment
Number of accounts written off in whole or in part
Dollar amount of write off
Billing frequency
Equal billing plan or equal payment plan offer
Number customer accounts enrolled in equal billing plan
Number customer accounts enrolled in equal payment plan
Number of customer accounts with security deposits
Dollar amount of security deposits
Number of customer accounts where load limiter devices installed
Number of customer accounts where timed load interrupter devices installed
Please look to the Electricity RRR document for full details of the reporting requirements.
New on form
No changes to form.
Tips
Multiple disconnections in a year:
The requirement is to report the number of customer accounts in which disconnection
occurred. In case of multiple disconnections in an account in the year, the account will
be counted once for purposes of reporting in this section.
Total amount owing under arrears payment agreements:
Please report the total amount owing throughout the course of the year, and not just at
year end.
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2.1.9 - Blank
This section is blank.
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2.1.10 – Affiliate Transactions
2.1.10 Affiliate Transactions
Content
The following information is required to be entered:
For purchase of service to affiliate:
Name of affiliate
Number of contracts with each named affiliate
Total annual dollar value of transactions for each contract with the affiliate
For sale of service to affiliate:
Name of affiliate
Number of contracts with each named affiliate
Total annual dollar value of transactions for each contract with the affiliate
Highest total value of financial support to affiliate(s) outstanding
A comment box is provided on the electronic input form for additional explanations.
New on form
There are no changes to the contents of the input form.
Tips
Reminder for electronic submission of Affiliate Relationships Code (ARC) certification
by CEO is triggered by Saving or Submitting 2.1.10 RRR filings.
Example
The reporting distributor has 5 contracts for provision of services to affiliate ABC. The
dollar value of transactions under each of the five contracts is:
Contract 1 - $100,000
Contract 2 - $200,000
Contract 3 - $300,000
Contract 4 - $400,000
Contract 5 - $500,000
Total of all 5 contracts - $1,500,000
Affiliate contracts (Distributor to Affiliate)
Number of
+ Name of Affiliate
contracts with
the affiliate
ABC
5
Total annual dollar value of
transactions for each contract
with affiliate
1,500,000
X
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2.1.11 – Service Agreements & Billing Options
2.1.11 Service Agreements & Billing Options
Content
This form requires these inputs:
•
•
•
Name of all retailers doing business with the distributor,
Confirmation that they have a service agreement with the distributor, and
An indication of billing option in place with the retailer if different from distributor
consolidated billing.
New on form
New: This form will auto-populate from the prior year’s annual filing and can then be revised,
if required.
Tips
None.
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2.1.12 - Blank
This filing has been discontinued.
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2.1.13 - Reconciliation
2.1.13 Reconciliation
Content
This filing consists of an excel spreadsheet showing the trial balance submitted under RRR
Section 2.1.7 mapped and reconciled to the audited financial statements.
New on form
New: This year, the Excel spreadsheet will be uploaded into the RRR portal. This
should not be sent by email/mail to OEB staff or to the Board Secretary’s office. In case
of any difficulties with the upload, please contact ITHelp at
[email protected]
Tips
V
Size & Path:
The file size must be less than 2 GB, and the file name (including path) should be less
than 255 characters in order to upload.
Reconciliation:
The complete mapping under this requirement consists of showing which trial balance
accounts are grouped together to form the financial statement groupings on the audited
financial statements.
Explanatory notes:
Please provide notes on the excel spreadsheets which explain the reason for any
discrepancy between the regulatory trial balance and the audited financial statements.
Business Rule:
Must attach an Excel spreadsheet or cannot submit.
Only one version is submitted to the Board. If multiple uploads are made, the latest
version will override previously uploaded versions. Alternatively, to remove an
attached file, click on the “x” to delete the row and click save.
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2.1.14 – Net Metering & Embedded Generation
2.1.14 Net Metering & Embedded Generation
Content
This section requires reporting of the number of net metered generators and their
installed capacity in kW. These net metered generators are distinct from generators
financed under the Renewable Energy Standard Offer Program (“RESOP”) or Feed-in
Tariff Program (“FIT”) administered by the Ontario Power Authority. The required
information is broken down into the following categories by type: wind, water, solar and
biomass.
In addition, the total number and installed capacity of all embedded generation
facilities, excluding net metered facilities reported under sub-sections a) and b),
are also required.
New on form
There is no change to the required content for the filing.
Tips
Conversion to RESOP/FIT:
Net metering accounts which have been converted to RESOP or FIT accounts should
not be reported in the first table where net metering facilities are reported. These
customers should be reported as embedded generators. Please note that a customer
cannot be both RESOP and net metered.
Embedded generation:
Embedded generation facilities, including FIT, microFIT, RESOP and all others which
have not been reported under the net metering category should be included in the
reporting of embedded generation facilities.
Average installed capacity:
For each type of generation, the average installed capacity per facility should generally
not exceed 500 kW.
Business Rule:
For each type of facility, if kW is reported, then the number of generators must be
reported.
If a number for generators is reported, a KW amount must be reported.
Additional column in far right calculates “Total installed capacity (kW) per net metered
generator” for each type (biomass, solar, water, wind). If any of the 4 averages exceeds
500 kW, a warning will appear to review the entered figures.
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2.1.15 – Connection Impact Assessments
2.1.15 Connection Impact Assessments
Content
This requirement was created to capture the information required by the provincial
government under Ontario Regulation 326/09 (Mandatory Information re
Connections) made on September 9, 2009.
It requires the number of connection impact assessments completed in the quarter,
by month. It further requires the installed capacity of the completed assessments,
and requires the number of completed assessments which met the timeline
prescribed by legislation, as well as the number of completed assessments that took
longer.
The section also asks for the number of offers made to connect micro generation
facilities in the quarter, by month, and the installed capacity of these facilities.
New on form
There is no change to the required content for the filing.
New: The layout of the form has been improved by changing the order of the columns
and adding an auto-calculated column for totals.
Tips
Report COMPLETED assessments, not connections:
Please do not report the number of facilities connected in the month. The
requirement is to report the number of assessments completed.
CURRENT month reporting only, not cumulative:
Please report the offers to connect made in the month in the "Number of Offers to
Connect Micro (<= 10kW)" column. This is not a cumulative number, but rather the
number of offers for the current reporting month only.
Net metering applications included:
Please also note that completion of assessment for net metering applications
facilities is to be included in the reporting in this section as well.
Business Rules:
• Table has been re-arranged with the 3rd column “Number of Connection Impact
Assessments (CIAs) Completed in this Quarter (>10kW)” auto calculated as
sum of CIAs within prescribed time + CIAs not within prescribed time.
•
If there are CIAs reported in the month, then Total kW renewable facilities
>10kW must be entered.
•
If Total kW renewable facilities >10kW reported, then number CIAs completed
must be entered.
If there are number of offers to connect reported in the month, then Total kW
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renewable facilities <10kW must be entered.
•
If Total kW renewable facilities <10kW reported, then offers to connect must be
entered.
Example
October
Distributor completed 9 Connection Impact Assessments within the quarter, and all were
completed within 120 days of the application being received by the distributor. Each of
these projects had a capacity of 15kW.
The Distribution also received 5 applications for connection of micro-generation
facilities (<=10kW). Of these 4 offers were made for connection of micro renewable
facilities with a total combined capacity of 1 kW.
November
Distributor completed 7 Connection Impact Assessments within the quarter, and all were
completed within 120 days of the application being received by the distributor. Each of
these projects had a capacity of 15kW.
The Distribution also received 5 applications for connection of micro-generation facilities
(<=10kW). Of these 4 offers were made for connection of micro renewable facilities
with a total combined capacity of 1 kW.
December
Distributor completed 6 Connection Impact Assessments within the quarter, and 5 of the
assessments were completed within 120 days of the application being received by the
distributor, and one was completed after 120 days. Each of these projects had a
capacity of 15kW.
The Distribution also received 5 applications for connection of micro-generation facilities
(<=10kW). Of these 4 offers were made for connection of micro renewable facilities
with a total combined capacity of 1 kW.
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2.1.16 - LEAP
2.1.16 LEAP
Content
The information collected in this form is compiled by the distributor from reports received
from social service agency partners regarding financial assistance provided under the
LEAP program.
Information asked for includes: source of LEAP funds, how the funds were spent, and
the number of applicants who applied for funding, and were assisted or denied. It
asks for the month in which the LEAP funds were depleted.
The input form auto-calculates the average grant disbursed per accepted LEAP
application. Finally, it asks for the distributor’s confirmation that the LEAP Emergency
Financial Assistance Manual was adhered to by the social agency partner(s) of the
distributor.
New on form
There is no change to the required content for the filing.
Tips
Please refer to the LEAP manual on the OEB website.
Business Rule:
Total number of LEAP Applicants should equal the sum of Total applicants Assisted and
Total applicants Denied.
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2.1.17 – Large Customer Identification
2.1.17 Large Customer Identification
Content
To facilitate the OEB’s monitoring of financial viability, the OEB has introduced the
reporting requirement in Section RRR 2.1.17 to report details on any customer whose
annual distribution revenue exceeds 5% of the distributor’s annual distribution revenue.
New on form
There are no changes to the content of this filing.
Tips
There is no need to provide the names of the customers, only the sector in which they
operate.
Multiple accounts:
If a customer has multiple accounts, the sum of distribution revenues arising from all
accounts must be used.
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2.1.18 – Loss of Large Customer
2.1.18 Loss of Large Customer
Content
Section RRR 2.1.18 has been introduced for a distributor to report, on an exception
basis, when a material loss of load is incurred or is expected to be incurred to facilitate
the OEB’s monitoring of financial viability.
The section reads as follows:
“A distributor shall immediately report to the Board any concern for a potential loss of
customer(s) or an incurred loss of customer(s) as well as any material* reduction in
customer load, as reported in its last annual filing.
*Materiality for a customer load reduction is considered when there is an impact of five
percent or more on the distributor’s annual distribution revenues.”
New on form
Not applicable as there is no form for this filing.
The required information must be emailed to Board Secretary as soon as it is known to
the distributor. This can happen at any time during the year.
Tips
None
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2.1.19 – Evolving Performance Measures
2.1.19 Evolving Performance Measures
General Tips
General:
1. Distributors were required to implement all evolving measures (First contact resolution,
Customer satisfaction survey results and Distribution system plan implementation
progress) in place by July 1, 2014. All distributors will be required to report on their
performance results against all Scorecard measures with their annual Electricity
Reporting and Record Keeping Requirements filings starting on April 30, 2015.
2. The evolving measures will also ultimately have definitions established by the OEB by
no later than 2018 to ensure consistency in reporting and comparability of results.
During this period of transition, the OEB will be less prescriptive with respect to most of
the evolving measures, allowing distributors some initial discretion on definition and
implementation.
3. Scorecard information:
For more details on the scorecard, please refer to the Report of the Board: Performance
Measurement for Electricity Distributors: A Scorecard Approach (EB-2010-0379) dated March
5, 2014.
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2.1.19a – First Contact Resolution
2.1.19a First Contact Resolution
Content
First Contact Resolution is a measure of a distributor’s effectiveness at satisfactorily
addressing customers’ complaints.
The OEB has determined that distributors will be required to measure First Contact
Resolution and report their results annually for the Scorecard. Distributors will be
permitted discretion as to how they implement this measure, but will be required to
describe their measure in the notes.
New on form
There are no changes to the content of this filing.
Tips
1. The data entered for the First Contact Resolution measure will be shown on the
scorecard. Due to the column limitation on the scorecard this field has a limit of 20
characters.
2. The data entered in “Notes” column will not appear on the scorecard and will be used
by the OEB for analysis. Please provide detailed information about the measure, its
description, the calculation methodology including source data and any other
information including tracking and record keeping. If the measure is reported as a
numeric figure, please provide the numerator and the denominator if applicable.
There is no character limit in this field.
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2.1.19b – Billing Accuracy
2.1.19b Billing Accuracy
Content
The OEB developed and implemented a uniform measure for billing accuracy in its July 17,
2014 letter and subsequently established a 98% target for the measure.
A Uniform Billing Accuracy Measure
The billing accuracy measure is defined as the accurate bills issued expressed as a
percentage of total bills issued. It is calculated as,
Percentage of bills accurately issued = (Total number of bills issued for the year – Number
of inaccurate bills issued for the year)/ Total number of bills issued for the year
Industry-wide Billing Accuracy Performance Target
The OEB has set a minimum industry-wide billing accuracy performance target of 98%.
The OEB will review this target level and may refine it in the future, as the OEB monitors
distributors’ performance and data and as distributors learn from each other and enhance
their billing operational and business practices.
Implementation Dates for Tracking and Reporting
Distributors are required to implement and start tracking the billing accuracy measure
effective on October 1, 2014.
New on form
Distributors will have to report two new inputs:
A) Number of inaccurate bills issued for the year and;
B) Total number of bills issued for the year.
The Annual Percentage of bills accurately issued will be automatically calculated as (BA)/B upon saving and compared against the OEB’s minimum 98% standard.
Tips
The first reporting period (October to December 2014) of the measure will be due on April 30,
2015.
Additional definitions to ensure consistency in defining the billing accuracy measure
include:
Accurate Bill
An accurate bill is a bill that contains correct meter readings, customer information and rates
resulting in an accurately calculated bill.
Bills Issued
The total number of bills issued for the year includes original and re-issued bills that are issued
in the calendar year.
As specified by the Distribution System Code section 2.6.4, a bill is considered issued:
a) if sent by mail, on the third day after the date on which the bill was printed by the
distributor;
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b) if made available over the internet, on the date on which an e-mail is sent to the
customer notifying the customer that the bill is available for viewing over the internet;
c) if sent by e-mail, on the date on which the e-mail is sent; or
d) if sent by more than one of the methods listed in paragraphs (a) to (c), on whichever
date of deemed issuance occurs last.
Inaccurate Bill Issued
A bill is considered inaccurate if:
i)
The bill has been issued to the customer and subsequently cancelled due to a
billing error and/or;
ii)
There has been a billing adjustment in a subsequent billing(s) as a result of a
previous billing error.
Note: Accurate bills that need to be cancelled in order to correct another bill should not be
counted.
Please note that all estimated bills are considered inaccurate bills.
Billing Adjustments
For the purpose of calculating billing accuracy, the distributor should include all billing
adjustments arising from billing errors in lieu of cancelling and rebilling the original bill.
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2.1.19c – Customer Satisfaction Survey Results
2.1.19c Customer Satisfaction Survey Results
Content
The OEB has determined that distributors will be required to survey customer satisfaction
and report the results for the Scorecard. Distributors will have discretion to determine how
to conduct their customer satisfaction surveys (e.g., annual perception survey, on-going
transactional survey, focus group, telephone, “in-house”, outsourced, joint, etc.). However,
the OEB expects distributors’ to adhere to the following principles:
•
Surveys will, at a minimum, canvass customer satisfaction in the following key
areas: (a) power quality and reliability; (b) price; (c) billing and payment; (d)
communications; and (e) the customer service experience.
•
Distributors will follow good survey practices (examples may include: survey goals
are clear and specific; selected samples well represent the population to be
studied; care is taken in matching question wording to the concepts being
measured and the population studied; appropriate statistical analytic and reporting
techniques are used; all methods of the survey are disclosed to allow for evaluation
and replication; etc.), having regard to the body of literature on the subject.
The OEB accepts that distributors use different tools to assess customer satisfaction (e.g.,
perception surveys, transactional surveys, focus group surveys, town hall meeting
surveys, in-depth interview surveys, etc.). At this time, the OEB thinks that the costs of
requiring all distributors to conduct the same survey may outweigh the benefits of allowing
distributors to tailor their surveys to meet the needs and characteristics of their respective
customer bases. The OEB recognizes that allowing flexibility in survey type and frequency
permits distributors to use their surveys to measure other performance outcomes of
interest to their organizations.
Distributors will be required to report their results on a biennial basis (i.e., every second
year), at a minimum.
New on form
There are no changes to the content of this filing.
Tips
1. The data entered for the Customer Satisfaction Survey Results measure will be
shown on the scorecard. Due to the column limitation on the scorecard this field has a
limit of 20 characters.
2. The data entered in “Notes” column will not appear on the scorecard and will be used
by the OEB for analysis. Please provide detailed information about the measure, its
description, the calculation methodology including source data and any other
information including tracking and record keeping. If the measure is reported as a
numeric figure, please provide the numerator and the denominator if applicable.
There is no character limit in this field.
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2.1.19d – Public Safety
2.1.19d Public Safety
Content
The OEB is consulting with the Electrical Safety Authority to identify and recommend a
public safety measure.
New on form
There are no changes to the content of this filing.
Tips
None.
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2.1.19e – Distribution System Plan Implementation Progress
2.1.19e Distribution System Plan Implementation
Progress
Content
The OEB will initiate a consultation process to further examine options for and to
develop a quantifiable distribution system plan execution measure for the Scorecard.
The work has been initiated by the Distribution Network Investment Planning Working
Group.
The OEB has determined that distributors will be required to measure Distribution
System Plan Implementation Progress and report their results annually for the
Scorecard. Distributors will be permitted discretion as to how they implement this
measure, but will be required to describe their measure in the notes.
New on form
There are no changes to the content of this filing.
Tips
1. The data entered for the Distribution System Plan Implementation Progress measure
will be shown on the scorecard. Due to the column limitation on the scorecard this
field has a limit of 20 characters.
2. The data entered in “Notes” column will not appear on the scorecard and will be used
by the OEB for analysis. Please provide detailed information about the measure, its
description, the calculation methodology including source data and any other
information including tracking and record keeping. If the measure is reported as a
numeric figure, please provide the numerator and the denominator if applicable.
There is no character limit in this field.
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2.2 – ARC Self-Certification
2.2 ARC Self-Certification
Content
An electronic self-certification statement signed by the chief executive officer of the utility
confirming that the chief executive officer is satisfied that the utility has complied with the
Affiliate Relationships Code for Electricity Distributors and Transmitters (ARC).
New on form
New: The electronic filings of CEO’s self-certifications are mandatory for all distributors. No
hardcopies of this document will be accepted.
Tips
None.
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Executive Certification on RRR Filings
Executive RRR Certification
Content
To underscore the importance that the OEB places on the accuracy and integrity of
distributor RRR reporting, particularly in the context of the new performance based
regulatory framework, the OEB requires that both quarterly and annual RRR filings with
the OEB be certified by an executive signing officer of the company (e.g., Chief Executive
Officer, Chief Financial Officer, or other officer of the company with equivalent executive
signing authority).
The executive signing officer of the company shall certify, on behalf of the company, that:
•
The information filed under the OEB’s Reporting and Record-Keeping Requirements is
complete and accurate.
•
Adequate processes and controls including quality assurance and quality control are in
place to ensure that the information filed under the OEB’s Reporting and RecordKeeping Requirements is accurate.
•
The company is able to provide records substantiating the filings made under the
OEB’s Reporting and Record-Keeping Requirements on request.
It is an offence under section 126(1)(b) of the Ontario Energy Board Act, 1998 to
knowingly furnish false or misleading information in any application, statement or return
made under that Act or in any circumstances where information is required or authorized
to be provided under that Act.
New on form
New: The electronic executive certification for RRR is mandatory for all distributors. The
RRR submission for the distributor is complete after the certification is filed.
Tips
Certification by:
The certification can be completed by an executive signing officer of the company e.g.,
Chief Executive Officer, Chief Financial Officer, President, President & CEO, or other
officer of the company with equivalent executive signing authority. Please specify the job
title in the field called “Other” when the job title in the drop-down menu is not listed.
Completeness of Filing:
All filings must be completed before the task for executive certification can be performed.
The RRR filings with the OEB will not be successful unless the executive certification of
the RRR is completed.
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RRR Filing Guide April 2015
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