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Decision 3100-D01-2015
EPCOR Distribution & Transmission Inc. 2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast January 25, 2015
Alberta Utilities Commission
Decision 3100-D01-2015
EPCOR Distribution & Transmission Inc.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast
Proceedings 3216 and 3100
Applications 1610565 and 1610362
January 25, 2015
Published by the:
Alberta Utilities Commission
Fifth Avenue Place, Fourth Floor, 425 First Street S.W.
Calgary, Alberta
T2P 3L8
Telephone: 403-592-8845
Fax: 403-592-4406
Website: www.auc.ab.ca
Decision 3100-D01-2015 (January 25, 2015) • i
Contents
1 Introduction ........................................................................................................................... 1
2 Background ........................................................................................................................... 3
3 Commission process for reviewing 2013 true-up and 2014-2015 forecast capital tracker
applications ............................................................................................................................ 6
4 Summary of projects included in the 2013 capital tracker true-up application and the
2014-2015 capital tracker forecast application .................................................................. 8
5 Grouping of projects for capital tracker purposes .......................................................... 11 5.1 Project grouping and incentives ................................................................................... 11
5.2 EDTI’s proposed grouping of projects ......................................................................... 16
6 Deferral of capital expenditures planned in 2013 ............................................................ 21
7 Project assessment under Criterion 1 – the project must be outside of the normal
course of the company’s ongoing operations .................................................................... 32 7.1 Common issues ............................................................................................................ 33
7.1.1 Common assumptions in EDTI’s capital expenditure forecasts ..................... 33 7.1.2 Controls and accountability ............................................................................ 37
7.1.3 Requirement that in the absence of the proposed capital expenditures,
deterioration in service quality and safety would result ................................. 38
7.2 Previously approved capital tracker projects or programs ........................................... 40 7.2.1 Third-party Driven Relocations ...................................................................... 41
7.2.2 IT-related projects ........................................................................................... 46 7.2.3 Distribution Contributions to Transmission Assets ........................................ 48
7.2.4 Life Cycle Replacement and Extension of Underground Distribution Cable. 50 7.2.5 New 15-kV and 25-kV Circuit Additions ....................................................... 54 7.2.6 New Underground Cable and Aerial Line Reconfigurations and Extensions to
Meet Customer Growth................................................................................... 58 7.2.7 Distribution Pole and Aerial Line Life Cycle Replacements .......................... 62 7.2.8 Aerial and Underground Distribution Transformers – New Services and Life
Cycle Replacement ......................................................................................... 65 7.2.9 Capitalized Underground System Damage ..................................................... 69 7.2.10 Vehicles – Growth and Life Cycle Replacements .......................................... 71 7.2.11 New Underground and Aerial Service Connections for Commercial,
Industrial, Multi-family and Miscellaneous Customers .................................. 75 7.2.12 Underground Residential Distribution (URD) Servicing – Rebates,
Acceptance Inspections & Terminations ........................................................ 78
7.2.13 Capital Tools and Instrument Purchases ......................................................... 82 7.2.14 Poundmaker Feeders ....................................................................................... 87
7.3 New capital trackers ..................................................................................................... 93 7.3.1 OMS/DMS Life Cycle Replacement .............................................................. 93 7.3.2 Capitalized Aerial System Damage ................................................................ 96 7.3.3 Underground Industrial Distribution (UID) Servicing – Rebates, Acceptance
Inspections & Terminations ............................................................................ 98 7.3.4 Replacement of Faulted Distribution PILC Cables ...................................... 101
ii • Decision 3100-D01-2015 (January 25, 2015)
7.3.5 Neighbourhood Renewal program ................................................................ 104 7.3.6 Customer Revenue Metering – Growth & Life Cycle Replacements ........... 107
7.3.7 Life Cycle Replacement of Network Transformers ...................................... 111 7.3.8 Street Light Service Connections and Security Lighting Addition and Capital
Replacement .................................................................................................. 114 7.3.9 Life Cycle Replacement of PILC Cable Systems ......................................... 116
8 Accounting test under Criterion 1 – the project must be outside of the normal course
of the company’s ongoing operations and Commission conclusion on Criterion 1 .... 118 8.1 EDTI’s accounting test model .................................................................................... 118 8.2 I-X index and Q factor used in the accounting test .................................................... 120 8.3 WACC rate ................................................................................................................. 122 8.4 Asset service lives ...................................................................................................... 123
8.5 Commission’s conclusions on Criterion 1 ................................................................. 127
9 Criterion 2 – ordinarily the project must be for replacement of existing capital assets
or undertaking the project must be required by an external party ............................. 127
10 Criterion 3 – the project must have a material effect on the company’s finances ...... 131
11 Advanced Metering Infrastructure project .................................................................... 134 11.1 AMI as the solution for customer revenue metering .................................................. 134
11.2 Utility asset disposition implications on the retirement of existing meters ............... 139 11.3 Capital tracker treatment for the AMI project............................................................ 147
12 Other matters raised by the CCA .................................................................................... 151 12.1 Reporting capital tracker and non-capital tracker capital costs separately ................ 151
12.2 Changes to the efficiency carry-over mechanism ...................................................... 152
13 K factor calculation ........................................................................................................... 153 13.1 2013 K factor true-up ................................................................................................. 153
13.2 2014-2015 K factor forecast....................................................................................... 156
14 Order .................................................................................................................................. 158
Appendix 1 – Proceeding participants .................................................................................... 159
Appendix 2 – Oral hearing – registered appearances ........................................................... 160
Appendix 3 – Summary of Commission directions ................................................................ 161
List of tables
Table 1. 2013 K factor true-up adjustments ($ million) ......................................................... 8
Table 2. Applied-for 2014 and 2015 capital tracker projects ($ million) ........................... 10
Table 3. 2013 capital additions deferred due to capital tracker mechanism uncertainty
($ million) ................................................................................................................... 23
Decision 3100-D01-2015 (January 25, 2015) • iii
Table 4. Actual and approved capital additions for Third-party Driven Relocations
projects ($ million) .................................................................................................... 41
Table 5. 2014-2015 forecast capital additions for Third-party Driven Relocations projects
($ million) ................................................................................................................... 43
Table 6. New 15-kV and 25-kV Circuit Additions forecast capital expenditures 2014-2015
..................................................................................................................................... 56
Table 7. 2013 actuals for new underground cable and aerial line reconfigurations and
extensions to meet customer growth ....................................................................... 60
Table 8. Variance between forecasts and actuals on capital tool and instrument purchases
2008-2013 ($ million)................................................................................................. 84
Table 9. Variance between forecasts and actuals on Replacement of Faulted Distribution
PILC Cables 2008-2013 ($ million) ....................................................................... 103
Table 10. Applied-for 2013-2015 capital tracker projects or programs and Criterion 2
requirements ............................................................................................................ 129
Table 11. Net present value analysis of alternatives to AMI($ million) .............................. 137
Decision 3100-D01-2015 (January 25, 2015) • 1
Alberta Utilities Commission
Calgary, Alberta
EPCOR Distribution & Transmission Inc. Decision 3100-D01-2015
2013 PBR Capital Tracker True-up and Proceedings 3216 and 3100
2014-2015 PBR Capital Tracker Forecast Applications 1610565 and 1610362
1 Introduction
1. On February 28, 2014, EPCOR Distribution & Transmission Inc. (EPCOR or EDTI) filed
an application with the Alberta Utilities Commission (the AUC or the Commission) requesting
approval of certain capital projects for capital tracker treatment in 2014 and 2015. EDTI further
requested that the associated revenue requirement for the capital tracker projects would be
included, in the applicable year, in the K factor component of the performance-based regulation
(PBR) rate formula approved in Decision 2012-237.1 This application, herein referred to as the
“2014-2015 capital tracker forecast application,” was assigned Proceeding 3100.
2. On March 4, 2014, the Commission issued a notice of application that required interested
parties to submit a statement of intent to participate (SIP) by 2 p.m., March 18, 2014. In their
SIPs, parties were to indicate whether they supported or objected to the application, reasons for
their positions, and the need for further process and the supporting rationale. The Commission
received SIPs from FortisAlberta Inc. (Fortis), AltaLink Management Ltd. (AltaLink),
ATCO Gas, a division of ATCO Gas and Pipelines Ltd. (ATCO Gas), ATCO Electric Ltd.
(ATCO Electric), the Consumers’ Coalition of Alberta (CCA) and the Office of the Utilities
Consumer Advocate (UCA).
3. On May 15, 2014, EDTI filed an application with the Commission requesting approval of
its 2013 capital tracker true-up application. EDTI further requested that the resulting
2013 K factor true-up adjustment and associated Rider DJ be reflected in its 2015 PBR rates.
This application, herein referred to as the “2013 capital tracker true-up application,” was
assigned Proceeding 3216.
4. On May 16, 2014, the Commission issued a notice of application that required interested
parties to submit a SIP by 2 p.m., May 22, 2014. The Commission received SIPs from Fortis,
AltaLink, AltaGas Utilities Inc. (AltaGas), ATCO Electric, the CCA and the UCA.
5. After reviewing the two applications and the SIPs, the Commission determined that the
applications would be considered by way of a full process proceeding. Additionally, given that
many of EDTI’s approved 2013 capital tracker projects were also proposed for 2014 and 2015,
the Commission anticipated that many of the relevant issues in the 2014-2015 capital tracker
forecast application and in the 2013 capital tracker true-up application would be similar in
nature. The Commission anticipated that this commonality of relevant issues provided an
opportunity to achieve efficiencies and cost savings in processing the applications. Therefore, the
Commission issued a process letter,2 with subsequent revisions,3 which staggered the written
1 Decision 2012-237: Rate Regulation Initiative, Distribution Performance-Based Regulation, Application
No. 1606029, Proceeding ID No. 566, September 12, 2012. 2 Proceeding 3100, Exhibit 89 and Proceeding 3216, Exhibit 48.
3 Proceeding 3100, Exhibit 103 and Proceeding 3216, Exhibit 56.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
2 • Decision 3100-D01-2015 (January 25, 2015)
evidentiary portion of the two proceedings, combined the proceeding records and convened a
joint oral hearing.
6. During the hearing, the Commission requested EDTI to direct certain supplemental
information requests (IRs) to Mr. Kennedy of Gannett Fleming Inc., depreciation consultants to
EDTI, and provided for an additional round of IRs to EDTI, following receipt of Mr. Kennedy’s
responses. The Commission also revised dates for argument and reply argument.4 The resulting
schedule for the two proceedings is set out in the table below.
Process step for the 2014-2015 capital tracker
forecast application Proceeding 3100
Deadline
Process step for the 2013 capital tracker true-up
application Proceeding 3216
Deadline
IRs to EDTI April 11, 2014
EDTI IR responses May 2, 2014
Application is filed May 15, 2014
Intervener evidence May 22, 2014 SIPs are due May 22, 2014
IRs to EDTI June 5, 2014
IRs to interveners June 12, 2014
EDTI IR responses June 20, 2014
Intervener IR responses July 11, 2014
Rebuttal evidence July 31, 2014
Combined oral hearing September 8, 2014 to September 19, 2014
Combined oral hearing
September 8, 2014 to September 19, 2014
EDTI responses to Commission’s supplemental IRs
September 24, 2014 EDTI responses to Commission’s supplemental IRs
September 24, 2014
Round 2 IRs to EDTI October 1, 2014 Round 2 IRs to EDTI October 1, 2014
Round 2 EDTI IR responses October 8, 2014 Round 2 EDTI IR responses October 8, 2014
Argument October 15, 2014 Argument October 15, 2014
Reply argument October 27, 2014 Reply argument October 27, 2014
7. The Commission considers the record for the two proceedings to have closed on October
27, 2014, when reply arguments were filed. In reaching the determinations set out within this
decision, the Commission has considered all relevant materials comprising the record of
proceedings 3100 and 3216, as well as findings in Decision 2012-237 and Decision 2013-435.5
Accordingly, reference in this decision to specific parts of the records are intended to assist the
reader in understanding the Commission’s reasoning relating to a particular matter and should
not be taken as an indication that the Commission did not consider all relevant portions of the
records with respect to a particular matter.
4 Transcript, Volume 6, pages 898-899.
5 Decision 2013-435: Distribution Performance-Based Regulation 2013 Capital Tracker Applications,
Application No. 1608827, Proceeding ID No. 2131, December 6, 2013.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 3
2 Background
8. On September 12, 2012, the Commission issued Decision 2012-237, approving PBR
plans for the distribution utility services of certain Alberta electric and gas companies, including
EDTI. The PBR plans were approved for a five-year term commencing January 1, 2013. PBR
replaces traditional cost of service regulation as the annual rate-setting mechanism for
distribution utility rates.
9. As set out in Decision 2012-237, the PBR framework provides a formula mechanism for
the annual adjustment of rates for those companies under an approved PBR plan. In general, the
rates are adjusted annually by means of an indexing mechanism that tracks the rate of inflation
(I) relevant to the prices of inputs the companies use less an offset (X) to reflect the productivity
improvements the company can be expected to achieve during the PBR plan period. As a result,
with the exception of specifically approved adjustments, a utility’s revenues are no longer linked
to its costs. Companies subject to a PBR regime must manage their businesses and service
obligations with the revenues derived under the PBR indexing mechanism and adjustments
provided for in the formula. The PBR framework is intended to provide incentives for
productivity increases and cost savings similar to those operating in competitive markets.
10. A company may apply for approval for certain rate adjustments to enable the recovery of
specific costs where it can be demonstrated that the costs cannot be recovered under the I-X
mechanism and where certain other criteria have been satisfied. These possible adjustments
include an adjustment to fund necessary capital expenditures (a K factor), an adjustment for
certain flow-through costs that should be recovered from, or refunded to, customers directly (a
Y factor), or an adjustment to account for the effect of material exogenous events for which the
company has no other reasonable cost recovery or refund mechanism within the PBR plan
(a Z factor).
11. In Decision 2012-237, the Commission determined that a mechanism to fund certain
capital-related costs may be required under the approved PBR plans.6 This supplemental funding
mechanism was referred to in Decision 2012-237 as a “capital tracker” with the revenue
requirement associated with approved amounts to be collected from ratepayers by way of a
“K factor” adjustment to the annual PBR rate setting formula.
12. At paragraph 592 of Decision 2012-237, the Commission set out three criteria that any
capital project or program would have to satisfy in order to receive capital tracker treatment:
(1) The project must be outside of the normal course of the company’s ongoing
operations.
(2) Ordinarily the project must be for replacement of existing capital assets or
undertaking the project must be required by an external party.
(3) The project must have a material effect on the company’s finances.
13. Further, at paragraph 593 of Decision 2012-237, the Commission indicated that the party
recommending the capital tracker must demonstrate that all of the criteria have been satisfied in
order for a capital project or program to receive consideration as a capital tracker.
6 Decision 2012-237, paragraph 586.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
4 • Decision 3100-D01-2015 (January 25, 2015)
14. The implementation and application of the above capital tracker criteria was considered
as part of the 2013 capital trackers Proceeding 2131, leading to Decision 2013-435. The
Commission indicated that the implementation methodology established in that decision will be
used not only to evaluate the capital tracker projects or programs proposed by the parties for
2013, but also for subsequent capital tracker applications throughout the PBR term.7
15. With respect to the first capital tracker criterion, the Commission concluded that, in
general, in order for a capital project or program to be considered outside of the normal course of
the company’s ongoing operations, the increase in associated revenue provided under the I-X
mechanism would not be sufficient to recover the entire revenue requirement associated with the
prudent capital expenditures for this project or program. Accordingly, the Commission found
that the concept of normal course is mainly a financial and accounting consideration, rather than
strictly an engineering consideration. The Commission referred to this comparison of revenues as
the “accounting test” under Criterion 1. At the same time, the Commission indicated an
engineering study and a business case will aid the Commission in assessing whether a project
proposed for capital tracker treatment is (i) required to provide utility service at adequate levels
and, if so, (ii) that the scope, level and timing of the project are prudent, and the forecast or
actual costs of the project are reasonable. The Commission referred to this assessment as the
“project assessment” under Criterion 1. Therefore, the applicant must satisfy the Commission’s
requirements for both the accounting test and the project assessment in order to satisfy the
requirements of Criterion 1.8
16. Regarding the accounting test component of Criterion 1, the Commission determined that
this test should be based on the project net cost approach, under which the revenue generated
under the I-X mechanism for each capital project (or capital program or project category) is
compared to the forecast revenue requirement associated with that capital project (or capital
program or project category) in a PBR year. No consideration of operating and maintenance
costs or savings and potential productivity offsets above those implied by the approved X factor
is required for the accounting test.
17. For purposes of the project assessment, the Commission determined that each project or
program proposed for capital tracker treatment must generally be supported by a business case
and an engineering study. However, the Commission recognized that in some circumstances an
engineering study may not be required. In Section 10.2 of Decision 2013-435, the Commission
found that for the purpose of the project assessment, a project or program proposed for capital
tracker treatment typically should address the following:
a. The rationale for the project, including the nature, scope, location, timing and cost of
the project.
b. Any context for the project, which may include related past, present and future plans
(e.g., for multi-year capital expenditures).
c. Evidence demonstrating that in the absence of the proposed capital expenditures,
deterioration in service quality and safety would result.
d. Qualitative and, to the extent possible, quantitative descriptions of the service quality
and safety risks addressed by the project.
e. Evidence that the capital project could not have been undertaken in the past as part of
a prudent capital maintenance and replacement program.
7 Decision 2013-435, paragraph 120.
8 Decision 2013-435, paragraphs 149-150.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 5
f. A discussion of any reasonable alternatives, including the rationale for
recommending the proposed solution.
g. A detailed forecast of costs for the project or project components, in sufficient detail
to allow an evaluation of the reasonableness of the forecast.
h. A comparison of actual expenditures to forecast expenditures on similar projects over
at least the previous five years, if available, including an explanation of any
differences.
i. With respect to proposed capital trackers, an explanation of any differences between
the forecast costs of projects proposed for capital tracker treatment and the actual or
updated forecast costs of similar projects undertaken in the prior year. This
explanation should provide a breakdown of the project costs that includes both units
and costs-per-unit on a forecast and actual or updated forecast basis.
j. With respect to the true-up of capital tracker projects, an explanation of any
differences between the forecast costs of projects approved for capital tracker
treatment and the actual cost of these projects undertaken in the prior year. This
explanation should provide a breakdown of the project costs that includes both units
and costs-per-unit on a forecast and actual basis.9
18. At paragraph 615 of Decision 2012-237, the Commission indicated that a company may
choose to undertake a capital investment prior to applying for capital tracker treatment in the
subsequent annual capital tracker filing. The Commission further clarified at paragraph 48 of
Decision 2013-435:
48. It was acknowledged by the Commission that superior incentives for capital
trackers would result if the companies were required to spend money on capital
expenditures prior to receiving approval for capital tracker recovery of the expenditures.
However, given the lack of experience with the capital tracker mechanism, for the first
generation PBR plans, it was determined that the companies will be permitted to apply
for capital trackers on a forecast basis. The approved forecast cost of a capital tracker
project will be included in rates on an interim basis and will be subject to a true-up to
prudently incurred actual expenditures, after the project is completed. The true-up
process will test the prudence of the actual capital expenditures and imprudent
expenditures will be subject to disallowance. As a result, the capital tracker mechanism
retains some efficiency incentives due to the risk of regulatory disallowances in the true-
up process if expenditures are not prudently incurred. The true-up mechanism with a
prudence review also mitigates somewhat the incentive for companies to overstate the
initial capital tracker forecasts. Nonetheless, the companies remained free to incur
expenditures prior to applying for capital tracker approval. [footnotes removed]
19. With respect to Criterion 2, in Decision 2013-435, the Commission clarified that, in
addition to asset replacement projects and projects required by an external party, in principle, a
growth-related project will satisfy the requirements of Criterion 2 where it can be demonstrated
that customer contributions, together with incremental revenues allocated to the project on some
reasonable basis, when added to the revenue provided under the I-X mechanism, are insufficient
to offset the revenue requirement associated with the project in a PBR year.10 Criterion 2 also
permits consideration of certain projects for capital tracker treatment that do not fall into any of
the growth-related, asset replacement or external party related categories.
9 Decision 2013-435, paragraph 1092.
10 Decision 2013-435, paragraph 309.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
6 • Decision 3100-D01-2015 (January 25, 2015)
20. Under Criterion 3, the Commission determined that applying the materiality threshold to
that portion of the revenue requirement for a project that is not funded under the I-X mechanism
is warranted. The Commission established a two-tier materiality threshold. The first tier of the
materiality threshold, a “four basis point threshold,” is to be applied at a project level (grouped in
the manner approved by the Commission). The second tier of the materiality threshold, a
“40 basis point threshold,” is to be applied to the aggregate revenue requirement proposed to be
recovered by way of all capital trackers.
21. Additionally, the Commission recognized the significance of the grouping of projects
proposed for capital tracker treatment when it stated in paragraph 601 of Decision 2012-237:
601. … The Commission also considers that it would not be suitable to group together
several dissimilar projects into a single large project to give the appearance of materiality.
However, a number of smaller related items required as part of a larger project might
qualify for capital tracker treatment.
22. In Decision 2013-435, the Commission further elaborated that grouping of projects will
require close scrutiny, since it will have a direct effect on the results of the accounting test and
the project assessment under Criterion 1, as well as the assessment of materiality under
Criterion 3. The Commission determined that the reasonableness of the grouping of capital
projects is best assessed on a case-by-case basis for each individual company. The Commission
indicated that it will require each company to provide a justification for its proposed grouping of
projects for capital tracker treatment.11
23. Finally, in Section 4.4 of Decision 2013-435, the Commission set out the K factor
calculation methodology. The Commission determined that basing the K factor calculations on
the incremental revenue requirement amounts (i.e., above the amounts provided under the
I-X mechanism) for each project or program proposed for capital tracker treatment, as is done
under the project net cost approach, is commensurate with the Commission’s definition of
outside the normal course of the company’s ongoing operations. Specific elements of the
approved K factor calculation methodology are further discussed in Section 13 of this decision,
which deals with EDTI’s 2013, 2014 and 2015 K factor calculations.
3 Commission process for reviewing 2013 true-up and 2014-2015 forecast capital
tracker applications
24. In the remainder of this decision, the Commission assesses the company’s 2013 true-up
and 2014-2015 forecast capital tracker requests. With respect to the 2013 true-up of capital
tracker projects previously approved, the Commission stated the following:
975. … the March 1st capital tracker application shall true-up the costs of projects that
have been completed since the prior year‘s capital tracker filing together with sufficient
information to permit a prudence review of these completed projects. To facilitate a
prudence review of a project, the company must submit information showing that it has
completed the project in the most cost effective manner possible. This information will
include the results of competitive bidding processes, comparisons of in-house resources
11
Decision 2013-435, paragraphs 403 and 406.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 7
to external resources, and any other evidence that may be of assistance in demonstrating
the prudence of the expenditures.12
25. Consistent with these determinations, the Commission considers that for the purposes of
the true-up of capital tracker projects previously approved for 2013, if there is no evidence on the
record of the true-up proceeding demonstrating that a project is not required, then there is no
need to demonstrate that a project is needed in order to provide utility service at adequate levels,
which constitutes the assessment of need under Criterion 1. However, the second part of the
project assessment under Criterion 1 is still required so that the Commission can be satisfied that
the scope, level and timing of each project is prudent, and the actual costs of the project were
prudently incurred.
26. The Commission also considers that for the purposes of the true-up of capital tracker
projects or programs previously approved, unless the driver for the project or program has
changed, there is no need to undertake a reassessment against the Criterion 2 requirements.
However, the Commission will undertake an assessment with respect to Criterion 3.
27. For any new projects in 2013 not previously approved, the Commission will undertake
assessments with respect to all three criteria for capital tracker treatment.
28. With respect to forecast capital projects for 2014 and 2015 for which the company is
seeking capital tracker treatment, the Commission will generally undertake assessments with
respect to all three criteria for capital tracker treatment. However, in those instances where a
project or program is part of an ongoing multi-year program, or if a project or program is of an
annual recurring nature (e.g., relocations) that has been previously approved by the Commission
for capital tracker treatment, in the absence of evidence that the ongoing or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1. However, the Commission will undertake assessments with respect to all remaining
aspects of the three criteria for capital tracker treatment.
29. Section 4 of this decision provides an overview of the projects or programs for which
EDTI is seeking capital tracker treatment in 2013, 2014 and 2015. The evaluation of EDTI’s
proposed capital project groupings is set out in Section 5. Section 6 deals with EDTI’s decision
to defer some expenditures on capital tracker projects planned in 2013. The assessment of how
EDTI’s projects or programs proposed for capital tracker treatment satisfy Criterion 1 is set out
in sections 7 and 8 dealing with the project assessment and the accounting test, respectively. The
assessment under Criterion 2 is undertaken in Section 9 and the assessment under Criterion 3 is
set out in Section 10. Given the complexity of issues related to the Advanced Metering
Infrastructure (AMI) project, the Commission has considered all aspects of the project in a
separate section, Section 11. Section 12 deals with other matters raised throughout the
proceedings. Finally, Section 13 deals with the K factor calculation methodology and the
K factor true-up for 2013, as well as K factor forecasts for 2014 and 2015.
12
Decision 2012-237, paragraph 975.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
8 • Decision 3100-D01-2015 (January 25, 2015)
4 Summary of projects included in the 2013 capital tracker true-up application and
the 2014-2015 capital tracker forecast application
30. In the 2013 capital tracker true-up application, EDTI applied for the K factor true-up of
14 projects or programs approved by the Commission for capital tracker treatment on a forecast
basis in Decision 2013-435. In addition, EDTI applied for capital tracker treatment and the
resulting K factor true-up for three projects that were not previously approved by the
Commission. The projects and programs included in the 2013 capital tracker true-up application
and the resulting variance from approved forecast resulting in a K factor true-up for 2013, as
proposed by EDTI, are presented in the table below.
Table 1. 2013 K factor true-up adjustments ($ million)13
No. Project name 2013 decision
K factor 2013 actual
K factor Variance
Applied-for projects or programs approved for capital tracker treatment in Decision 2013-435
1 Third-party Driven Relocations 0.37 0.59 0.22
2 Information Technology (IT)-related projects 0.14 (0.08) (0.14)
3 Distribution Contributions 0.64 0.34 (0.30)
4 Life Cycle Replacement and Extension of Underground Distribution Cable 0.76 0.41 (0.35)
5 New 15-kilovolt (kV) and 25-kV Circuit Additions 0.23 0.11 (0.12)
6 New Underground Cable and Aerial Line Reconfigurations and Extensions to Meet Customer Growth 0.44 0.46 0.02
7 Distribution Pole and Aerial Line Life Cycle Replacements 0.32 (0.03) (0.32)
8 Aerial and Underground Distribution Transformers – New Services and Life Cycle Replacement 0.22 0.31 0.09
9 Capitalized Underground System Damage 0.15 0.29 0.14
10 Vehicles – Growth and Life Cycle Replacements 0.23 0.06 (0.17)
11 New Underground and Aerial Service Connections for Commercial, Industrial, Multi-family and Misc. Customers 0.37 0.69 0.32
12 Underground Residential Distribution (URD) Servicing – Rebates, Acceptance Inspections & Terminations 0.60 1.52 0.92
13 Capital Tools and Instrument Purchases 0.11 0.07 (0.04)
14 Poundmaker Feeders 0.29 0.65 0.36
Total capital tracker approved in Decision 2013-435 4.87 5.39 0.63
Applied-for projects that have not been previously approved for capital tracker treatment
15 Underground Industrial Distribution (UID) Servicing – Rebates, Acceptance Inspections & Terminations 0.18 0.18
16 Neighbourhood Renewal Program 0.13 0.13
17 Customer Revenue Metering – Growth & Life Cycle Replacements 0.26 0.26
Total not previously approved capital trackers 0.57 0.57
2013 K factor total 4.87 5.96 1.20
13
Proceeding 3216, Exhibit 1, 2013 true-up application, Table 1.0-1 on page 1.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 9
31. In its 2014-2015 capital tracker forecast application, EDTI applied for capital tracker
treatment for 23 of its capital projects or programs in either or both of the years 2014 and 2015.
Of these, 13 projects or programs were previously approved for capital tracker treatment in 2013
on a forecast basis in Decision 2013-435. The remaining 10 projects or programs have not been
previously approved for capital tracker treatment.
32. In response to the Commission’s IR AUC-EDTI-1, EDTI provided updated information,
correcting for errors and typos in the K factor calculation model that EDTI included in its
application. This updated data is reflected in the following table, which summarizes EDTI’s
applied-for 2014 and 2015 capital trackers, the portion of the K factor adjustments related to
each capital tracker project, and the total applied-for K factor adjustment for each of 2014 and
2015.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
10 • Decision 3100-D01-2015 (January 25, 2015)
Table 2. Applied-for 2014 and 2015 capital tracker projects ($ million)14
Applied-for K factor
No. Project name 2014 2015
Applied-for projects or programs approved for capital tracker treatment in Decision 2013-435
1 Third-party Driven Relocations 1.83 3.81
2 IT-Related Capital Trackers [Note 1] - -
3 Life Cycle Replacement and Extension of Underground Distribution Cable 0.96 2.06
4 New 15-kV and 25-kV Circuit Additions 0.27 0.75
5 New Underground Cable and Aerial Line Reconfigurations and Extensions to Meet Customer Growth 0.89 1.45
6 Distribution Pole and Aerial Line Life Cycle Replacements - 0.34
7 Aerial and Underground Distribution Transformers – New Services and Life Cycle Replacement 0.50 0.75
8 Capitalized Underground System Damage 0.48 0.72
9 Vehicles – Growth and Life Cycle Replacements 0.15 0.41
10 New Underground and Aerial Service Connections for Commercial, Industrial, Multi-family and Misc. Customers 1.10 1.58
11 Underground Residential Distribution (URD) Servicing – Rebates, Acceptance Inspections & Terminations 2.66 3.83
12 Capital Tools and Instrument Purchases 0.11 0.16
13 Poundmaker Feeders 0.60 0.55
Total trackers approved in Decision 2013-435 9.54 16.41
Applied-for projects or programs that have not been previously approved for capital tracker treatment
14 OMS/DMS Life Cycle Replacement - 0.74
15 Capitalized Aerial System Damage 0.14 0.22
16 Underground Industrial Distribution (UID) Servicing – Rebates, Acceptance Inspections & Terminations 0.22 0.28
17 Replacement of Faulted Distribution PILC Cables 0.10 0.16
18 Neighbourhood Renewal Program 0.16 0.24
19 Customer Revenue Metering – Growth & Life Cycle Replacements 0.59 0.94
20 Advanced Metering Infrastructure - 0.69
21 Life Cycle Replacement of Network Transformers - 0.20
22 Street Light Service Connections and Security Lighting Addition and Capital Replacement - 0.12
23 Life Cycle Replacement of PILC Cable Systems - 0.12
Total not previously approved trackers 1.22 3.70
2014-2015 K factor total 10.76 20.12
Note 1: In the 2014-2015 capital tracker forecast application, EDTI applied for capital tracker treatment of the IT-related program, consisting of several projects. As a result of corrections, EDTI determined that the IT-related program no longer meets the first tier materiality threshold in 2014 or 2015. Therefore, EDTI is no longer requesting capital tracker treatment for this program.
14
Exhibit 93.02, AUC-EDTI-1, Attachment 1, Table 1.0-1.
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Decision 3100-D01-2015 (January 25, 2015) • 11
5 Grouping of projects for capital tracker purposes
33. In Decision 2013-435, the Commission determined that the accounting test and the first
tier of the materiality test will be applied to the approved groupings (i.e., either at a project or at
a program level). The Commission also indicated that while the project assessment will generally
be applied at the level of an approved grouping of projects, the Commission will, where
necessary, consider the individual component projects comprising the approved groupings in
order to assess the need for the capital expenditures and the reasonableness of the forecast costs.
The second tier of the materiality test will be applied at the level of all capital tracker projects, in
the aggregate.15 The Commission also determined that the reasonableness of the grouping of
capital projects is best assessed on a case-by-case basis for each individual company.16
34. In these proceedings, the discussion on EDTI’s proposed grouping of projects for capital
tracker purposes was centered on two issues. The first issue, discussed in Section 5.1 below,
relates to the relationship between the grouping of projects and a company’s earnings under the
approved PBR plans and the resulting incentives. The second issue, discussed in Section 5.2,
focused on the organization of EDTI’s proposed groupings.
5.1 Project grouping and incentives
35. In its argument, the CCA discussed at length the issue of project grouping for capital
tracker purposes and how grouping of trackers, fluctuations in expenditure levels and delaying
capital expenditures can affect incentives and a company’s net income and return on equity
(ROE).
36. The CCA presented a number of conclusions on the incentives that a company may have
with respect to project grouping in order to maximize the amount of revenue provided under the
capital tracker mechanism. According to the CCA, the first incentive is that a company may
propose to group together, as an applied-for capital tracker, projects that would otherwise not
satisfy the accounting test in order to exceed the accounting test threshold or, alternatively, group
a project that is below the threshold with other projects that exceed the threshold.17
37. The CCA further argued that a company may isolate projects for which the accounting
test is negative, rather than group them with like projects in order to increase the K factor
amount. If projects for which the accounting test is negative are grouped with projects for which
the accounting test is positive, they decrease the amount to be funded by way of a K factor for
the resulting capital tracker group. The CCA concluded “the incentive is clearly to keep negative
trackers to themselves and not group them with anything else.”18
38. Finally, the CCA argued that a company has an incentive to create “non-smooth, erratic,
chunky capital addition expenditure patterns above and below the accounting test threshold to
increase capital tracker revenue.”19 In the CCA’s view, this incentive may manifest itself by way
of a deferral of capital expenditures to a re-basing year to increase going-in rates in the next PBR
15
Decision 2013-435, paragraph 407. 16
Decision 2013-435, paragraph 406. 17
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 27. 18
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 30. 19
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 36.
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12 • Decision 3100-D01-2015 (January 25, 2015)
term. The CCA pointed out that, in an exchange with the EDTI panel, the Commission referred
to these incentive as a “strategic substitution or strategic delay of projects.”20
39. The CCA proposed that delays in capital expenditure or uneven expenditure patterns can
have a significant impact on the outcome of the accounting test. Using numerical examples, the
CCA demonstrated that by engaging in patterns of high expenditure followed by low expenditure
or vice versa, a “stop and go” expenditure pattern, a company’s net income “can be clearly
influenced […] without spending a penny more than it had originally intended to spend.”21
Therefore, the CCA submitted it is important to disclose the accounting tests for all projects, in
order to detect the “stop and go” expenditure patterns.
40. Nonetheless, the CCA acknowledged that patterns of high expenditure followed by low
expenditure or vice versa can occur naturally with short-lived assets, depending upon the
replacement cycle, without any strategic motive to benefit from tracker timing. The CCA
maintained that the “same net income effects will hold whether the pattern is strategic or not.
The utility will benefit at the expense of ratepayers. The risk is all one way.” The CCA urged the
Commission to address this skewing of risk.22
41. The CCA submitted that in addressing the concerns of strategic substitution or strategic
delay of projects, the Commission “should be reviewing those situations where negative
accounting tests result and determine whether they arose from strategic substitution or delay, or
from other factors.”23 Specifically, the CCA recommended that
… some retrospective mechanism would be useful to review the circumstances of asset
expenditure deferral and strategic shifting. This could be thought of as the logical
equivalent or mirror image to the denial power which the Commission has for capital
trackers. In other words the Commission can deny a tracker … if the company cannot
show why the expenditure was not done earlier.24
42. In Section 8.1.5 of its argument, the CCA outlined changes to the PBR design of the
capital tracker mechanism to “help rebalance the incentives of capital trackers back towards
neutrality for customers and utilities.”25
43. In reply, EDTI expressed its view that the CCA’s submissions on its grouping of projects
are “an improper attempt to proffer new evidence in argument.”26 EDTI also stated that the
numeric examples on which the CCA relied to support its views are “far too simplistic and
unrealistic to demonstrate anything”27 since they use a depreciation rate of 100 per cent, ignore
the half year rule for new additions and fail to reflect the time value of money, among other
simplifying assumptions.
44. With respect to the incentives identified by the CCA concerning delays or uneven capital
expenditure patterns, EDTI highlighted the fact that, in accordance with the filing requirements
20
Transcript, Volume 5, page 731, lines 13-14. 21
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 39. 22
Proceeding 3100 Exhibit 136.01, CCA argument, paragraph 64. 23
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 52. 24
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 63. 25
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 108. 26
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 51. 27
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 56.
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Decision 3100-D01-2015 (January 25, 2015) • 13
set out by the Commission, it provides a detailed explanation of variances between historical and
forecast capital expenditures and additions for the five-year period preceding the application.
EDTI submitted that “the filing of this information provides more than adequate data upon which
the Commission can identify, review and scrutinize what might appear to be year-over-year
capital spending anomalies.”28
45. On the same issue, EDTI pointed out that the Commission’s capital tracker criteria
require that the company demonstrate that the project could not have been undertaken previously
as part of a prudent capital maintenance program. EDTI stated it complied with this requirement
in its business cases and engineering studies filed in support of each capital tracker and provided
detailed explanations as to why a project is required now and could not have been undertaken as
part of a program in the past. Therefore, EDTI argued the Commission is provided with ample
evidence to ensure that strategic substitution or delay of projects has not occurred.29
46. EDTI did not agree with the CCA’s proposal to implement a “retrospective mechanism”30
to the Commission’s capital tracker review process. In EDTI’s view, a retrospective ROE review
“is nonsensical in the context of a Capital Tracker project, as one would have to consider
operating costs and their effect on ROE, what is happening with all capital projects (Tracker and
non-Tracker) and their effect on ROE, and the results of the Tracker true-up process and its
effect on ROE.”31
47. Finally, with respect to the CCA’s proposals in Section 8.1.5 of its argument to change
the design of the PBR plans and capital tracker mechanism EDTI argued:
These submissions have no bearing on this proceeding. The PBR regime was established
in Decision 2012-237 and the Capital Tracker mechanism was further clarified in
Decision 2013-435. The purpose of this proceeding is to test EDTI’s Capital Tracker
Applications pursuant to the framework established by the Commission in those
decisions. This is not the forum for the CCA to lobby for wholesale changes to the
Capital Tracker mechanism or to attempt to launch a review and variance of the
Commission’s previous decisions. The submissions of the CCA at section 8.1.5 of its
argument should be disregarded.32
Commission findings
48. In its argument, the CCA elaborated on the incentives a company has to manipulate the
grouping of capital trackers or the timing of capital expenditures to increase its net income and
ROE.
49. In Decision 2012-237, the Commission recognized the significance of the grouping of
projects proposed for capital tracker treatment when it stated:
601. … The Commission also considers that it would not be suitable to group together
several dissimilar projects into a single large project to give the appearance of materiality.
28
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 64. 29
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 66. 30
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 63. 31
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 70. 32
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 83.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
14 • Decision 3100-D01-2015 (January 25, 2015)
However, a number of smaller related items required as part of a larger project might
qualify for capital tracker treatment.33
50. Consistent with these determinations, it is the Commission’s view that grouping projects
for the sole purpose to either minimize or maximize the capital tracker revenue, is contrary to the
PBR decision. Projects are to be grouped together to reflect the requirement referenced above
that they be “a number of smaller related items required as part of a larger project” or program.
Any challenge to the company’s groupings must be made because the groupings do not comply
with this requirement. Once the proposed groupings are approved, the accounting test and the
first tier of the materiality test will be applied to that level of grouping (i.e., either at a project or
at a program level). The resulting K factor revenue is a result of this process.
51. The Commission generally agrees with the CCA’s view that the grouping of projects
affects a company’s earnings and its incentives related to capital expenditures. The Commission
recognizes that a company has an incentive to group projects resulting in a positive accounting
test result but below the first tier of the materiality threshold together as an applied-for tracker in
order to exceed the materiality threshold or group a project that is below the first tier of the
materiality threshold with another group that exceeds the threshold. The Commission also
recognizes that a company has an incentive to isolate projects for which the accounting test is
negative to avoid providing any offset to the K factor calculation in the accounting test.34
52. However, the Commission recognized these incentives in Decision 2013-435, where it
stated in paragraphs 403 and 404:
403. At the same time, the Commission shares the UCA’s view that, given the
importance of project grouping, “the method of aggregating projects into a program-level
will require close scrutiny.” This is because grouping of projects will have a direct impact
on the results of the accounting test and the project assessment under Criterion 1, as well
as the assessment of materiality under Criterion 3.
404. Specifically, with respect to the accounting test under Criterion 1, it would be
possible for a company to group projects together for the sole purpose of ensuring that
the revenue from the I-X mechanism is insufficient to fund a portion of the revenue
requirement associated with capital expenditures for the proposed projects, as grouped.
The UCA reached a similar conclusion when it stated that “it would be possible for
Utilities to group projects together in such a way as to artificially inflate the numbers in a
single program to fall outside historic levels of spending.” Likewise, with respect to
Criterion 3 dealing with materiality, the UCA noted that the companies may attempt “to
roll projects together to meet the materiality criterion.” The Commission agrees and finds
that this is a relevant consideration for the four basis point threshold under the first tier of
the materiality test set out in Section 3.3. [footnotes omitted]
53. A company’s proposed grouping of capital tracker projects must conform with the
requirement of the accounting test “to compare the forecast or actual revenue requirement for [a]
project to the going-in revenue historically associated with a similar type of capital
expenditures ...”35 in order to determine the extent to which a project or program is underfunded
by the I-X mechanism. The resulting project grouping is usually consistent with the historical
33
Decision 2012-237, paragraph 601. 34
Proceeding 3100, Exhibit 136.01, CCA argument, paragraphs 27 and 29. 35
Decision 2013-435, paragraph 262.
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Decision 3100-D01-2015 (January 25, 2015) • 15
grouping of projects for accounting and regulatory reporting purposes under cost of service
regulation, prior to the implementation of PBR. Where this is the case, there is little reason to
suspect the company has manipulated the grouping of projects. However, where the company’s
proposed grouping of projects is at odds with its past accounting and reporting practices, as the
Commission cautioned in Decision 2013-435, the Commission must assess the reasonableness of
the proposed grouping on a case-by-case basis, taking into account “the unique differences
among the companies with respect to their historical project classifications in cost-of-service
applications, limitations of the companies’ accounting systems, and the nature and geographic
location of the companies’ facilities.”36
54. With respect to the timing of capital expenditures, as EDTI pointed out, the
Commission’s implemented review process under the project assessment as part of Criterion 1
allows it to deal sufficiently with the strategic substitution or strategic delay of projects.
55. Specifically, in accordance with the filing requirements set out by the Commission for
capital tracker projects, for the purpose of the project assessment, a program or project proposed
for capital tracker treatment typically should address the following, among other requirements:
…
e. Evidence that the capital project could not have been undertaken in the past as part of a
prudent capital maintenance and replacement program.
…
h. A comparison of actual expenditures to forecast expenditures on similar projects over
at least the previous five years, if available, including an explanation of any differences.
i. With respect to proposed capital trackers, an explanation of any differences between
the forecast costs of projects proposed for capital tracker treatment and the actual or
updated forecast costs of similar projects undertaken in the prior year. This explanation
should provide a breakdown of the project costs that includes both units and costs-per-
unit on a forecast and actual or updated forecast basis.
j. With respect to the true-up of capital tracker projects, an explanation of any differences
between the forecast costs of projects approved for capital tracker treatment and the
actual cost of these projects undertaken in the prior year. This explanation should provide
a breakdown of the project costs that includes both units and costs-per-unit on a forecast
and actual basis.37
56. The Commission agrees with EDTI that the filing of this information provides necessary
data upon which the Commission and interested parties can identify, review and scrutinize any
irregular expenditure patterns, which may be an indication of the strategic substitution or
strategic delay of projects.38 Therefore, the Commission does not accept the CCA’s proposal to
implement an additional retrospective review mechanism.39 Nor does the Commission accept the
CCA’s proposal to review “those situations where negative accounting tests result and determine
whether they arose from strategic substitution or delay, or from other factors.”40 If accepted, this
method would in effect require the Commission and interested parties to examine and verify the
entirety of the company’s capital forecasts. As explained in Decision 2013-435, only those
36
Decision 2013-435, paragraph 405. 37
Decision 2013-435, paragraph 1092. 38
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 64. 39
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 63. 40
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 52.
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16 • Decision 3100-D01-2015 (January 25, 2015)
projects proposed for capital tracker treatment shall be scrutinized.41 The CCA also proposed to
make changes to the design of the capital tracker mechanism to “help rebalance the incentives of
capital trackers back towards neutrality for customers and utilities.”42 The Commission agrees
with EDTI’s view that these CCA submissions are outside the scope of the present proceedings.43
57. However, the Commission also notes that in Proceeding 3558 the Commission will be
considering possible changes to the minimum filing requirements for capital trackers. In that
proceeding, the Commission will examine, among other matters, whether the companies should
be required to list all projects, including projects with negative accounting test results, in the
accounting test model to facilitate the Commission’s examination of the reasonableness of the
company’s proposed grouping.
5.2 EDTI’s proposed grouping of projects
58. As observed in Decision 2013-435, EDTI’s approach to grouping is generally based on
the approximately 60 relatively granular capital project categories that EDTI used for purposes
of its last three general tariff applications (GTAs) under cost of service regulation.44 In that
decision, the Commission has generally approved EDTI’s proposed grouping of projects, with
three exceptions. Specifically, the Commission directed EDTI to group three types of projects
included in its 2013 capital tracker forecast, including Third-party Driven Relocations projects,
IT-related projects and projects related to Distribution Contributions for Transmission Assets.45
59. EDTI indicated that in the 2013 capital tracker true-up application and in the 2014-2015
capital tracker forecast application, it has grouped its applied-for projects consistent with the
findings and directions of the Commission in Decision 2013-435. EDTI further clarified that
while it has grouped its Third-party Driven Relocations, IT-related projects and Distribution
Contributions for Transmission Assets projects, it has maintained separate business cases and
engineering studies for each applied-for project within a group to facilitate project assessment
under Criterion 1.
60. When questioned by Commission counsel on why the Neighbourhood Renewal program
was not included in other asset lifecycle replacement projects, EDTI explained that since it was a
new program in 2010, it made more sense to separate it from other projects, rather than trying to
explain its grouping with other projects. Further, the Neighbourhood Renewal program
represented the replacement of cables, transformers and switching cubicles rather than just a
single type of asset.46
61. In his evidence, Mr. Shymanski for the UCA observed that EDTI included, as part of the
2014-2015 capital tracker forecast application, the North Light Rail Transit (LRT) project, with a
negative K factor value. Mr. Shymanski referred to paragraphs 964 to 967 of Decision 2013-435,
where the Commission determined that negative K factor amounts are not to be included in the
41
Decision 2013-435, paragraph 193. 42
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 108. 43
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 83. 44
Decision 2013-435, paragraph 833. 45
Decision 2013-435, paragraphs 837-841. 46
Transcript, Volume 2, page 493, lines 3-17 (Mr. Elford).
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Decision 3100-D01-2015 (January 25, 2015) • 17
calculation of the K factor, and recommended that the North LRT project be removed from
EDTI’s K factor calculations.47 The UCA supported this recommendation.48
62. In reply, EDTI pointed out that it has not included the North LRT project as a capital
tracker in this proceeding. Rather, EDTI complied with the Commission’s explicit direction in
Decision 2013-435 to group together all of its Third-party Driven Relocations capital projects
into a single capital tracker program for purposes of applying the accounting test and the first tier
of the materiality test at the program level.49
63. In its argument, the CCA submitted that EDTI’s “groupings are confusing.”50 The CCA
pointed out that EDTI has 75 asset categories or projects for which it performed the accounting
test. Out of these resulting 75 asset categories or projects, EDTI requested capital tracker
treatment for over 20 projects with K factors ranging from $60,000 to $3.8 million.
64. The CCA observed that EDTI has a capital tracker for an IT-related group of projects, but
it does not include all IT projects within the capital tracker. In addition, EDTI has a contribution
account which does not include all contributions. The CCA also observed that there are three
separate service centre accounts and separate accounts for different pole categories and other
aerial groupings.51 The CCA also noted that during the hearing, when questioned by Commission
counsel, EDTI acknowledged that many of its capital tracker projects involve the same asset
types that are grouped into different projects. For example, underground cables are dealt with in
11 different projects or subprojects.52 On the other hand, with respect to EDTI’s New
Underground Cable and Aerial Line Reconfigurations and Extensions to Meet Customer Growth
project, the CCA submitted that “[h]ere we have underground and aerial mixed together with a
second variable tossed in, that being reconfigurations or extensions. This is not an intuitive
grouping.”53
65. After analyzing EDTI’s grouping and reviewing the individual projects, the CCA
concluded that “one does not appear to be any further ahead than if the grouping step was
skipped.”54 The CCA prepared an alternative grouping that it believed to be simple to understand
and provided it in its argument. The changes proposed by the CCA resulted in aggregating
capital tracker projects into several higher level groupings based mostly on asset types (e.g.,
grouping together all IT projects, all contributions, all feeders, all aerial and all meters).55
66. As a result of these considerations, the CCA suggested a move to fewer capital trackers
and more high level groupings for EDTI. According to the CCA, this should reduce the impact of
year-over-year changes in expenditures on the accounting test results for individual capital
trackers. The CCA further stated that fewer capital trackers would reduce the “erratic nature of
47
Proceeding 3100, Exhibit 97.02, Evidence of Mr. Shymanski, paragraphs 58-65. 48
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 53. 49
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 33. 50
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 135. 51
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 134. 52
Transcript, Volume 2, pages 331-332 (Mr. Elford). 53
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 28. 54
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 145. 55
Proceeding 3100, Exhibit 136.01, CCA argument, pages 32-36.
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18 • Decision 3100-D01-2015 (January 25, 2015)
[EDTI’s] applied for trackers,” which “complicates the Commission’s ability to monitor future
attempts to strategically group capital trackers or strategically time capital additions.”56
67. The CCA clarified it is not recommending that its proposed groupings be applied to the
2014-2015 forecast years. However, it did recommend that EDTI’s groupings “be cleaned up and
aggregated such that EPCOR reduces the number of ungrouped projects.” Therefore, the CCA
recommended that for future capital tracker applications, EDTI substantially revise and regroup
its trackers so that:
Like assets and projects are together in an applied-for tracker.
The accounting test compares “apples to apples” and does not include the
revenue requirement from some assets that are in a different tracker and
exclude others that are picked up in a different tracker.
There are a reduced number of trackers.57
68. In the CCA’s view, these steps would reduce the regulatory burden, increase the clarity of
capital tracker applications and allow parties to focus on prudence issues rather than
classification of projects. The CCA stated that these steps would also reduce the ability to “shift
things around and group them together or mash a couple together or split some apart”58 and
reduce the ability to group trackers strategically or time capital additions strategically to increase
the K factor artificially.59
69. In reply, EDTI explained that the work and assets included in each grouping category
reflect the drivers of capital work, and the manner in which EDTI budgets for, carries out that
work and tracks its costs on a project-by-project basis. It is not built to align with specific asset
types. EDTI expressed its view that using the same capital project categories as it has done
historically, facilitates transparent comparisons of forecast and actual costs to its historical costs.
70. EDTI acknowledged that many of its project categories cross a number of asset types.
However, it did not agree with the CCA’s recommended approach to grouping. EDTI indicated
that “re-bucketing” its capital work into different categories to reflect asset type would take a
considerable amount of time. It would also create administrative issues with EDTI’s budgeting
processes, and with its field staff who would be required to change significantly the way they
record their work in the field on a project-by-project basis.60
71. Further, EDTI submitted that:
… [T]he CCA’s suggestion would do anything but reduce regulatory burden and increase
clarity. Disintegrating and re-bucketing EDTI’s project categories would not only take
considerable work on EDTI’s part, but would create substantial regulatory burden for the
Commission and interveners who would be faced with information in a form they had
never seen before. Rather than simplifying matters, the Business Cases and Engineering
Studies would have to be re-vamped considerably, and would be far more complex as
they would have to include explanations of various types of work and related forecasts,
56
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 155. 57
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 156. 58
Transcript, Volume 3, page 525, lines 13-14 (Mr. Baraniecki). 59
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 157. 60
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 91.
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Decision 3100-D01-2015 (January 25, 2015) • 19
justifications, and forecast to actual variances, irrespective of the fact that all the work
would be related to a specific asset type.61
72. In a similar vein, Mr. Elford for EDTI testified that “[a]lthough you would have fewer –
maybe fewer trackers by title, you’d have much longer and more confusing trackers.”62 In an
exchange with Commission counsel, Mr. Elford expressed his view that a major change to
EDTI’s approach to grouping (such as basing project grouping on asset type) is best considered
in conjunction with the review of the capital tracker mechanism as a whole:
However, if we could -- and we would have to do some more thinking about this, but if
we could look at those asset categories and determine ways to -- to get more efficient
through the use of, you know, something maybe akin to the K-bar mechanism that we
talked about in the previous capital tracker application applied at that level, or something
like that, there may be a way to do that. But it would have to be something more different
than just saying repackage the trackers into this function because I think we would just
create more confusion, at least from my perspective.63
73. Finally, EDTI submitted that in proposing its suggested groupings, the CCA has not
provided any analysis or other justification for why its alternative groupings make sense and why
the projects it has put in those groupings are appropriately grouped together. According to EDTI,
the CCA proposed groupings “are arbitrary and make little practical sense” and would create
significant and unnecessary administrative issues for EDTI’s personnel and regulatory burden for
all parties.64
Commission findings
74. In Decision 2013-435, the Commission highlighted the importance of project grouping
because it has a direct effect on the results of the accounting test and the project assessment
under Criterion 1, as well as the assessment of materiality under Criterion 3. The Commission
also stated that projects are to be grouped together to reflect the requirement in Decision
2012-237 that groupings include “a number of smaller related items required as part of a larger
project”65 or program. Any challenge to the company’s groupings must be made because the
groupings do not comply with this requirement.
75. In the 2013 capital tracker true-up application and in the 2014-2015 capital tracker
forecast application, EDTI used the same approach to project grouping, as approved in
Decision 2013-435. Nevertheless, with 60 relatively granular capital project categories, EDTI’s
approach to project grouping raises the prospect that it is overly refined for purposes of a capital
tracker proceeding where the objective is to ascertain logical groupings of capital. Further, it is
not based on asset type and, as such, many capital tracker projects involve the same asset types.
However, as EDTI noted, its grouping uses the same capital project categories it has used
historically, which facilitates comparisons of forecast and actual costs to EDTI’s historical costs
and activities on these projects.66 In addition, since this approach reflects the manner in which
EDTI budgets for, and tracks its costs on a project-by-project basis, EDTI’s grouping of projects
61
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 92. 62
Transcript, Volume 2, page 335, lines 17-18 (Mr. Elford). 63
Transcript, Volume 2, page 335, line 19 to page 336, line 4 (Mr. Elford). 64
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 96. 65
Decision 2012-237, paragraph 601. 66
Transcript, Volume 2, pages 331-334 (Mr. Elford).
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20 • Decision 3100-D01-2015 (January 25, 2015)
allows for administrative efficiency. EDTI explained that if it were to change its approach, it
would “create administrative issues with EDTI’s budgeting processes, as well as with its field
staff who would be required to significantly change the way they record their work in the field
on a project-by-project basis.”67
76. In addition, the Commission observes that the historical categorization and tracking of
capital additions highlights that much of the capital cannot be categorized into specific unique,
stand-alone projects. Rather, the capital is associated with a type of recurring activity generated
by a common or overlapping set of causes or events. In these circumstances, consolidating
capital project categories into a higher level of capital spending may serve to blur the rationale
for the particular spending under review.
77. Nevertheless, given that EDTI’s grouping uses the same capital project categories as it
has used historically, the Commission finds no evidence that the company has manipulated the
groupings in the capital tracker application. The Commission agrees with Mr. Elford that a major
change to EDTI’s approach to grouping (such as basing project grouping on asset type) is best
considered together with the review of the capital tracker mechanism as a whole,68 in a future
proceeding dealing with the second generation of a PBR plan for EDTI.
78. At the same time, the Commission considers that it may be warranted to group all of
EDTI’s life cycle replacement and like projects together with the Neighbourhood Renewal
program for the purposes of the accounting test, given that it appears these projects are all
intended to replace or renew aging assets. Accordingly, EDTI is directed to explain, in its next
capital tracker application, whether it is possible to do so and whether such grouping is
warranted.
79. The CCA proposed an alternative grouping of EDTI’s projects for capital tracker
purposes in Appendix A of its argument; however, the CCA clarified it is not recommending that
its proposed groupings be applied to the 2014-2015 capital tracker forecast application. The CCA
did not file evidence in either of the two proceedings with respect to grouping. Filing of the
CCA’s alternative grouping approach in argument did not allow the Commission and interested
parties to test the reasonableness of the CCA’s suggested groupings, and whether the projects in
the five aggregate categories proposed by the CCA are reasonably grouped.69 For these reasons,
the Commission will not consider the alternative approach to grouping of EDTI’s projects, as
proposed by the CCA for the purposes of this decision.
80. Mr. Shymanski for the UCA recommended that EDTI’s North LRT project, included as
part of the Third-party Driven Relocations group, be removed from K factor calculations.70 In
support of his view, Mr. Shymanski referred to paragraphs 964 to 967 of Decision 2013-435,
where the Commission determined that negative K factor amounts are not to be included in the
calculation of the K factor. In this regard, as EDTI pointed out, it has not included the North
LRT project as a capital tracker in this proceeding. Rather, EDTI complied with the
Commission’s explicit direction in Decision 2013-435 to group together all of its Third-party
67
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 91. 68
Transcript, Volume 2, page 335, line 19 to page 336, line 4 (Mr. Elford). 69
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 96. 70
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraphs 58-65.
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Decision 3100-D01-2015 (January 25, 2015) • 21
Driven Relocations projects into a single capital tracker program for purposes of applying the
accounting test and the first tier of the materiality test at the program level.71
81. While capital tracker projects resulting in a negative accounting test result should not be
included in the calculation of the K factor on a stand-alone basis for the sole purpose of reducing
the K factor amount, the Commission will accept all such projects as part of a capital tracker
program or group, where it is reasonable to do so, because the projects are of a similar nature.
This approach is consistent with the Commission’s determinations in Section 5.1 of this decision
that a company’s proposed grouping of capital tracker projects must conform with the
requirement of the accounting test “to compare the forecast or actual revenue requirement for [a]
project to the going-in revenue historically associated with a similar type of capital
expenditures….”72
82. In this particular case, the cost of new and ongoing Third-party Driven Relocations
projects is partially offset by the amount of the I-X revenue provided for the completed North
LRT project, a historically similar capital expenditure. By the same token, the costs of new
projects in the IT-related group and Distribution Contributions to Transmission Assets group are
partially offset by I-X revenue provided for completed projects of a similar nature, as discussed
in Section 7 below.
83. In light of the above considerations, the Commission finds that the grouping of EDTI
projects or programs proposed for capital tracker treatment appears to be reasonable. EDTI’s
project grouping is consistent with the Commission’s determinations in Decision 2013-435,
reflects projects that are of a sufficiently similar nature to warrant grouping into a single
program, as described in paragraph 839 of that decision, and reflects the company’s practice in
its last three GTAs.
84. For the purpose of this decision, the Commission accepts EDTI’s grouping of projects, as
proposed in the 2013 capital tracker true-up application and the 2014-2015 capital tracker
forecast application. Accordingly, the Commission’s accounting test and the first tier of its
materiality test will be applied to EDTI’s projects and programs proposed for capital tracker
treatment as filed. With respect to the project assessment component of Criterion 1, the
Commission will, consistent with paragraph 841 of Decision 2013-435, “assess the component
projects of EPCOR’s programs because, even though individual projects within a program
address similar issues, each project requires individual justification.”
6 Deferral of capital expenditures planned in 2013
85. In 2013, EDTI made a decision to delay expenditures on several 2013 capital tracker
projects due to what it referred to as “uncertainty respecting the capital tracker mechanism.”
EDTI elaborated on this issue in the 2014-2015 capital tracker forecast application as follows:
During the 2013 Capital Tracker [forecast] proceeding, EDTI noted that due to the
substantial capital funding shortfall under the I-X mechanism and the uncertainty
respecting the capital tracker mechanism (including the manner in which the Commission
would interpret and apply the three criteria for approval from Decision 2012-237), EDTI
71
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 33. 72
Decision 2013-435, paragraph 262.
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22 • Decision 3100-D01-2015 (January 25, 2015)
had made the decision to temporarily delay certain projects and components of projects
for a short time, pending the Commission issuing a decision in that proceeding. EDTI’s
witnesses made it clear that this applied to a small number of projects, and that the delays
would be targeted and of short duration, chosen with a view to minimizing the risk of
immediate and short term adverse effects on safety, service quality and reliability.
EDTI’s witnesses also noted that once certainty was provided by the Commission
respecting the capital tracker mechanism, EDTI would assess its circumstances and,
assuming that the Commission appropriately addressed the capital funding shortfall under
the PBR Plan, would move ahead with any temporarily delayed projects as quickly as it
could. EDTI noted that depending on the timing of the Commission’s Decision, some of
this work might not be completed by the end of 2013, but would carry over into
subsequent years.
With the issuance of Decision 2013-435 in early December, 2013, EDTI was not able to
complete all of its originally planned work for 2013. Consistent with its evidence in the
2013 Capital Tracker proceeding, however, EDTI will generally complete this work in
early 2014. In those limited cases where EDTI will not have the resources (internal as
well as external) to handle significant levels of carry over work, EDTI will spread the
outstanding work and the work required in 2014 and 2015 over both years. In doing so
and where appropriate, EDTI will prioritize the total amount of work to be done over
2014 and 2015 to ensure that the most critical work is completed earlier over the two year
period.
…In all cases, EDTI will schedule the completion of this outstanding work having regard
for potential impacts on safety and reliability, and the resources it will have available to
complete not only the outstanding work from 2013, but also the level of required capital
work specific to 2014 and 2015.73
86. Table 3 summarizes EDTI’s initial estimates for completing work on capital tracker
projects or programs that EDTI temporarily deferred in 2013 for the reasons outlined above.
73
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 22-24.
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Decision 3100-D01-2015 (January 25, 2015) • 23
Table 3. 2013 capital additions deferred due to capital tracker mechanism uncertainty ($ million)74
Project description 2013
decision 2013
actual
2013 work to be completed in 2014 work displaced from 2014 to 2015?
2014 2015 2016 and
future
The Interval Meter Data Collection and Processing System project
1.85 - 1.85 - - No
Life Cycle Replacement and Extension of Underground Distribution Cable
10.20 3.21 3.59 3.71 - Yes
Distribution Pole and Aerial Line Life Cycle Replacements
5.60 1.44 1.42 2.06 - Yes
Vehicle and Fleet Equipment Purchases
2.90 1.36 0.35 0.15 - No
New Underground Cable and Aerial Line Reconfigurations and Extensions to Meet Customer Growth
8.08 6.70 1.31 - - No
Neighbourhood Renewal Program [Note 1]
1.31 1.17 0.28 - - No
Life Cycle Replacement of PILC Cable Systems [Note 1]
1.04 - 0.42 0.62 - No
New 15-kV and 25-kV Circuit Additions
4.61 1.55 2.99 - - No
Total 35.59 15.43 12.21 6.54 -
Note 1: During the hearing, Mr. Elford for EDTI clarified that the life cycle replacement of PILC cable systems was not approved for capital tracker treatment in 2013 and, therefore, cannot be considered a capital tracker project that was temporarily deferred.75 The same reasoning applies to the Neighbourhood Renewal Program.
87. In his written evidence, Mr. Shymanski, acting on behalf of the UCA, indicated that
EDTI was able to defer some expenditures for the Life Cycle Replacement and Extension of
Underground Distribution Cable project and the Distribution Pole and Aerial Line Life Cycle
Replacement project for two years, from 2013 to 2015, without adverse impacts to customer
service. Therefore, Mr. Shymanski expressed his view that the capital additions deferred from
2013 to 2015 do not meet the requirements of Criterion 1 that projects proposed for capital
tracker treatment must be “of sufficient importance that the company’s ability to provide utility
service at adequate levels would be compromised if these expenditures were not undertaken” and
that projects “are required to prevent deterioration in service quality and safety.”76
Mr. Shymanski recommended that 2015 forecast capital additions for these two projects be
excluded from the K factor calculation.77
88. In rebuttal evidence, EDTI clarified that it did not delay the work on the two projects
referenced by Mr. Shymanski from 2013 to 2015. Instead, EDTI clarified that it expected to
complete, and place into service, all of the underground distribution cable work, as well as the
distribution pole and aerial line work, deferred from 2013, by the end of 2014.78 In turn, as EDTI
explained in response to a Commission information request, for some projects, “this essentially
results in 2013 carry over work ultimately displacing some 2014 work into 2015 to ensure that
74
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 17, Table CCA-EDTI-02-1 (Corrected). 75
Transcript, Volume 2, page 286, lines 1-15 (Mr. Elford). 76
Decision 2013-435, paragraph 278. 77
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, pages 4-6. 78
Proceeding 3100, Exhibit 107, EDTI rebuttal evidence, pages 13-20.
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24 • Decision 3100-D01-2015 (January 25, 2015)
the 2013 work is addressed as soon as reasonably possible.”79 During the hearing, Mr. Elford
provided further explanation on this matter:
… this bumping of work would take place because we're not going to take work
identified in '13 and simply drop it into '15 by spreading it that way. We're going to deal
with the highest priority work first, which involves taking the '13 work, doing it in '14,
put that in some '14 work will unfortunately cascade into '15.80
89. In response to an undertaking given at the hearing to the UCA, EDTI confirmed its
expectation that all of the 2013 deferred work, with the exception of the Cube Van vehicle as
part of the vehicles capital tracker project, will be completed by the end of 2014 despite the
indication in the above table that some 2013 work would be deferred into 2015.81 EDTI
submitted that these efforts confirm that it was acting in a manner that is consistent with the need
to complete the displaced work as soon as reasonably possible.82
90. In light of this clarification, during the hearing, Mr. Shymanski made the following
comment regarding his evidence on this matter:
If, in fact, this work is completed in 2014, as is now expected, there will be no 2015
capital additions for the 2013 carryover work and, thus, my recommendations on these
two projects [the Lifecycle Replacement and Extension of Underground Distribution
Cable and the Distribution Pole and Aerial Line Lifecycle Replacement projects] for
2015 would be rendered moot.83
91. In argument, the UCA submitted that, for the reasons set out in Mr. Shymanski’s
evidence, “if, despite EDTI’s intention, as stated in its rebuttal evidence, to complete the 2013
carry over work in 2014, EDTI does not in fact complete the work in 2014, it should not be
approved for Capital Tracker treatment in 2015.”84
92. In response to a Commission information request regarding any consequences for EDTI
or its customers of the decision to defer work on certain projects in 2013, EDTI indicated that:
On December 22nd, 2013, EDTI experienced one cable failure on a section of cable
which EDTI had planned to replace in 2013, but which, as a result of EDTI’s decision to
temporarily delay a portion of its planned cable replacement work (due to uncertainty
relating to the Capital Tracker mechanism), EDTI did not replace in 2013 as originally
planned. The outage relating to this cable failure resulted in 6,934 customer hours of
interruptions and the associated distribution feeder being one of EDTI’s worst performing
distribution feeders in 2013 as reported in EDTI’s 2013 AUC Rule 002 submission
(Service Quality and Reliability Performance Monitoring Plan for Owners of Electric
Distribution Systems).85
79
Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(d). 80
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford). 81
Proceeding 3100, Exhibit 118. 82
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 22. 83
Transcript, Volume 5, page 750, lines 8-11 (Mr. Shymanski). 84
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 48. 85
Proceeding 3100, Exhibit 93.01, AUC-EDTI-10(c).
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Decision 3100-D01-2015 (January 25, 2015) • 25
93. During the hearing, Ms. Hull elaborated further on the underground cable failures
experienced by EDTI as a result of deferring 2013 planned work and the resulting service
interruptions:
MS. HULL: On the 2013 deferred work we've had four cable failures: the one that we
had referenced in December of 2013, and then we've had three cable failures in August
[of 2014] for a total of 25,000 customer hours of interruption on those three alone. So
year to date on the system, we've had 51 cable faults over a system of 2,919 kilometres.
So the fault per kilometre for the whole system is 0.017 faults per kilometre. If you look
at just the deferred work, we've had four faults over the 12.27 kilometres of deferred
cable; therefore, we have a 19 times higher fault rate on just the deferred work from
2013.86
94. In response to a CCA information request, EDTI indicated that there was an outage in the
two areas served by circuit N13, which was identified for reconfiguration in 2013 as part of the
new underground cable and aerial line reconfigurations and extensions to meet customer growth
project, but deferred in 2013. EDTI stated:
While no outage occurred on this circuit in 2013, EDTI’s assessment of that risk was
validated in April, 2014 when an outage did occur on the N13 circuit resulting in a
13 hour service disruption. 12 hours of this outage could have been prevented had this
project’s loop feed been installed as originally planned.87
95. In its argument, the CCA expressed its concern that there do not appear to be any
consequences to EDTI for the failure to provide reliable utility service. The CCA noted that
EDTI, in its professional judgment, determined that certain underground cable needed to be
replaced and identified a capital tracker for this type of expenditure, but yet did not replace the
cable because of uncertainty with respect to its 2013 capital tracker application. As a result,
customers experienced 6,900 hours of interruption. In the CCA’s view, “there should be some
consequence to EPCOR for putting budgetary concerns ahead of reliability concerns.”88
96. In response, EDTI explained that its decision to delay certain projects, including the Life
Cycle Replacement and Extension of Underground Distribution Cable project, was in response to
the “substantial uncertainty that EDTI found itself facing pending the Commission’s decision on
EDTI’s first Capital Tracker Application in terms of the capital funding shortfall under PBR,”
rather than “budgetary constraints,” as characterized by the CCA.89 EDTI pointed to the fact that
in the 2013 capital tracker proceeding, Proceeding 2131, the CCA argued that EDTI should not
be allowed to recover its capital funding shortfall under the PBR plan through the capital tracker
mechanism, adding to the uncertainty with respect to the ability of EDTI to recover capital
expenditures.90
86
Transcript, Volume 2, page 304 line 18 to page 305 line 5 (Ms. Hull). 87
Proceeding 3100, Exhibit 94.01, CCA-EDTI-25(c). 88
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 161. 89
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 100. 90
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 101.
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26 • Decision 3100-D01-2015 (January 25, 2015)
97. The UCA noted that regulatory uncertainty is not an adequate reason to delay a project
that is necessary for continued safety and reliability on the system. In its argument, the UCA
stated:
The UCA is also strongly of the view that whether or not a utility receives approval for a
project as a capital tracker should not be the determining factor in its decision to proceed
with the project or to not proceed. A utility has an overriding obligation to provide safe
and reliable service, and to take prudent measures in achieving that goal. Capital trackers
were not intended to provide funding for every prudent capital project, just those that met
each of the Commission’s criteria.91
98. EDTI submitted that the reliability impacts resulting from delaying some of the deferred
projects for even a short period (as described earlier in this section), as well as EDTI’s evidence
that all delayed 2013 work will be completed in 2014, confirm EDTI’s evidence that the delays
were of very short duration. According to EDTI, this information also confirms the need for the
work and the appropriateness of the original timing of the work.
99. In its response to AUC-EDTI-6(d), EDTI explained the approach it took to prioritize its
work in 2014 and 2015 to ensure that its delayed 2013 work and its 2014 and 2015 work were
completed prudently. EDTI went on in its response to provide a detailed explanation of the
specific steps taken to prioritize its work in 2014 and 2015 for each project that had delayed
work from 2013.92
100. Overall, EDTI maintained that its actions in delaying capital expenditures for certain
capital tracker projects in 2013 were reasonable; that EDTI acted prudently in determining which
portions of which projects to delay and, further, in prioritizing its overall work requirements in
2014 and 2015 to complete the 2013 delayed work along with the work required to be completed
in 2014 and 2015 (with some 2014 work cascading into 2015). EDTI further stated the delays
were of very short duration and do not form any reasonable basis for arguing that EDTI can
similarly and as a matter of course delay portions of these or any other projects. EDTI further
submitted that the evidence demonstrates that its planned projects for 2014 and 2015 are required
to be completed on the timelines described in the business cases and engineering studies
provided for each project.93
101. In its reply argument, the CCA took issue with EDTI’s conclusion that the delay of
projects in 2013 cannot be used as “any reasonable basis for arguing that EDTI can similarly and
as a matter of course prudently delay portions of these or any other projects.” According to the
CCA, if EDTI could defer projects “due to financial concerns over regulatory uncertainty,” then
“it is not clear why capital expenditure cannot be cut back to reduce impact on customers.”94
102. The CCA submitted that EDTI has not demonstrated that there was anything unique
about the deferred 2013 work that makes it different from work scheduled for 2014 and 2015 or
subsequent years. According to the CCA, EDTI has made no case that the same activities could
not be deferred in 2014 or 2015, as was done in 2013, given that it was able to defer projects in
2013 without a significant increase in risks as a result of most of the delayed projects.
91
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 9. 92
Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(d). 93
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 28. 94
Proceeding 3100, Exhibit 139.01, CCA reply argument, paragraph 6.
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Decision 3100-D01-2015 (January 25, 2015) • 27
103. The CCA further pointed out that in the 2013 capital tracker forecast proceeding, EDTI
argued that all its recommended projects were required for utility service but then it did not
proceed with some of the work. According to the CCA, because EDTI delayed the forecast work
in 2013, it “certainly reduces the weight which the Commission should attach to similar evidence
in this proceeding for 2014 and 2015.”95 The CCA concluded by indicating that it does not have
recommendations for areas to cut back in capital additions for 2014, but given this history of
delayed projects, it will be reviewing them closely in subsequent applications.96
Commission findings
104. Table 3 in this section sets out the planned work on certain capital tracker projects or
programs that EDTI deferred, in whole or in part, in 2013 due to the “substantial capital funding
shortfall under the I-X mechanism and the uncertainty respecting the capital tracker
mechanism.”97 Of the eight projects or programs presented in Table 3, the Life Cycle
Replacement of PILC Cable Systems project and the Neighbourhood Renewal program were not
approved for capital tracker treatment in 2013 and, therefore, cannot be considered as capital
tracker projects that were temporarily deferred. Also, as discussed in Section 7 below, the
Commission accepts EDTI’s withdrawal of the IT-related program from capital tracker treatment
in EDTI’s 2013 capital tracker true-up and 2014-2015 capital tracker forecast applications. The
interval meter data collection and processing system project included in Table 3 is a part of the
IT-related program.
105. Accordingly, findings in this section apply to the five capital tracker projects approved
for 2013 for which EDTI deferred the planned work as a result of a perceived capital funding
shortfall under the I-X mechanism and uncertainty respecting approval of EDTI’s 2013 capital
tracker application:
New 15-kV and 25-kV Circuit Additions
Life Cycle Replacement and Extension of Underground Distribution Cable
Distribution Pole and Aerial Line Life Cycle Replacements
Vehicles – Growth and Life Cycle Replacements
New Underground Cable and Aerial Line Reconfigurations and Extensions to Meet
Customer Growth
106. In Decision 2013-435, the Commission assessed each of the above projects against the
project assessment requirements of Criterion 1 and determined based on the evidence, that each
of the projects was required to maintain service reliability and safety at adequate levels in 2013.
Further, the Commission determined that the scope, level, timing and forecast costs for each of
the projects referenced above were reasonable as proposed for 2013. Following the issuance of
Decision 2013-435 in early December 2013, EDTI indicated it was not able to complete all of its
originally planned work for 2013.
95
Proceeding 3100, Exhibit 139.01, CCA reply argument, paragraph 10. 96
Proceeding 3100, Exhibit 139.01, CCA reply argument, paragraph 12. 97
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 22.
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28 • Decision 3100-D01-2015 (January 25, 2015)
107. In Decision 2014-37398 dealing with AltaGas’ 2013 true-up and 2014-2015 forecast
capital tracker applications, the Commission stated the following with respect to the deferral of
projects previously approved on a forecast basis for capital tracker treatment:
96. The Commission does not consider that a project proposed for capital tracker
treatment in the current year should be denied simply because it was approved in a prior
year and deferred. It may be the case that the project was determined to be no longer
necessary in a prior period, or there may have been a valid business reason to defer the
project, even though it was required. In general, a previously approved project that has
been deferred may qualify for capital tracker treatment if there is sufficient evidence that
the deferral was a prudent decision at the time and given evidence of the continuing
necessity to complete the proposed project to maintain service quality and safety.99
108. EDTI maintained that these delayed projects were required and in the absence of the
uncertainty surrounding approval of its 2013 capital tracker application, these projects would
have proceeded as planned in 2013. However, given the uncertainty with respect to approval of
its 2013 capital tracker application, EDTI delayed certain projects, indicating that this decision
“applied to a small number of projects, and that the delays would be targeted and of short
duration, chosen with a view to minimizing the risk of immediate and short term adverse effects
on safety, service quality and reliability.”100
109. The Commission agrees with the UCA101 that the “substantial capital funding shortfall
under the I-X mechanism and the uncertainty respecting the capital tracker mechanism” does not
constitute a valid business reason for deferring work planned for 2013 that was required and
approved by the Commission for reasons of service reliability or safety. Indeed, at paragraph 615
of Decision 2012-237, which was issued prior to Decision 2013-435, the Commission indicated
that a company may choose to undertake a capital investment prior to applying for capital tracker
treatment in a subsequent annual capital tracker filing. In other words, a company does not have
to wait for the Commission’s approval of its forecast for capital tracker treatment to proceed with
projects required to maintain service reliability and safety at adequate levels.
110. The Commission further observed in Decision 2014-373 at paragraph 176:
176. AltaGas has an obligation to provide safe and reliable service. The PBR regime
does not alter this fundamental obligation of the company, and the deferral of the
Athabasca project due, in part, to a funding constraint is of concern. The Commission
expects that AltaGas will efficiently manage its system and acquire the funding necessary
to satisfy its obligation to provide safe and reliable service. As noted by the Alberta
Energy and Utilities Board in Decision 2005-019:
The Board is concerned with the position taken by AltaLink. AltaLink
appears to acknowledge that it has a responsibility to provide safe and
reliable service, however, it also chose to defer activities that it
considered necessary once the allowed revenue requirement could no
98
Decision 2014-373: AltaGas Utilities Inc. 2014-2015 Capital Tracker Application and 2013 Capital Tracker
True-up Application, Application nos.1610446 and 1610600, Proceeding nos. 3152 and 3244, December 24,
2014. 99
Decision 2014-373, paragraph 96. 100
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 22-24. 101
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 9.
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Decision 3100-D01-2015 (January 25, 2015) • 29
longer fund them. AltaLink itself has used the words “These were not
easy decisions to essentially place the transmission system at increased
risk because of lack of required resources”. The Board does not consider
this approach to be correct or acceptable.
…
In Decision 2003-061,[102] the Board agreed with AltaLink that certain
activities were necessary however, it did not agree with the revenue
requirement requested by AltaLink to perform these activities. It
determined, based on the evidence before it, that a different revenue
requirement was appropriate. AltaLink, in turn, was obligated to conduct
its affairs in a manner to ensure that it did not compromise service and
reliability, seeking efficiencies as means to achieve any perceived extra
resources, and to better present its case in future test periods. This was
not an invitation to AltaLink to deliberately reduce the level of service it
provided, particularly if the deferred activities involved actions which
could affect reliability and safety. (footnotes omitted)
111. The Commission cannot countenance the delay of capital tracker projects that have been
demonstrated and approved as necessary to maintain service reliability and safety within a given
period where the delay arises because of uncertainty over approval of a capital tracker
application. Nevertheless, the Commission recognizes that for the companies under PBR,
including EDTI, 2013 was a transition year as the companies moved from cost of service
regulation to PBR. Additionally, the Commission notes that during this transition, EDTI held
back its expenditures on a number of capital projects for which it did not expect to receive
capital tracker treatment, not just those considered and subsequently approved for capital tracker
treatment.
112. In response to a Commission information request, EDTI confirmed that it deferred a total
of approximately $44 million of capital expenditures in 2013 due to uncertainties surrounding
the treatment of capital under PBR.103 Of this $44 million, Table 3 above demonstrates that EDTI
deferred approximately $17 million in capital additions associated with the five projects
subsequently approved for capital tracker treatment in 2013. Mr. Elford provided further
confirmation on this matter when questioned by Commission counsel.
Q. So what I'm trying to understand, sir, is in making your capital allocation decisions,
did you make a distinction between non-capital tracker work and capital tracker work and
deciding what was to be delayed and then what was to be completed in '14?
A. MR. ELFORD: For the 2013 capital?
Q. Yes.
A. MR. ELFORD: No, we were holding back in areas where we thought we could hold
back temporarily for -- the same criteria were applying. Whether it's a tracker or not,
there's things you have to do because you're required to service customers. There's things
you have to do because it's immediate safety risk. There's things that you think you can
wait on for a short period of time.104
102
Decision 2003-061: AltaLink Management Ltd. and TransAlta Utilities Corporation, Transmission Tariff for
May 1, 2002 – April 30, 2004, TransAlta Utilities Corporation, Transmission Tariff for January 1, 2002 –
April 30, 2002, Application Nos. 1279345, 1279347, and 1287507, August 3, 2003. 103
Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(a). 104
Transcript, Volume 2, page 278, line 17 to page 279, line 5 (Mr. Elford).
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113. In addition to considering the reasons for why a project has been delayed, paragraph 96
of Decision 2014-373 also indicated that the Commission must consider whether there is a
continuing necessity to complete the proposed project to maintain service quality and safety. As
discussed in the respective parts of Section 7 of this decision, for each of the five projects
deferred in 2013, other than the fact that certain aspects of these projects were delayed from
2013 and then completed in 2014, the Commission finds no evidence on the record of
Proceeding 3216 to indicate that these projects were not required in 2013. In addition, the
Commission finds no evidence on the record of Proceeding 3100 to indicate that each of these
projects is not required to continue in 2014 and 2015.
114. In his evidence, Mr. Shymanski initially recommended that the Commission should not
afford capital tracker treatment to the Life Cycle Replacement and Extension of Underground
Distribution Cable Project and the Distribution Pole and Aerial Line Life Cycle Replacement
project, since EDTI deferred the expenditures on these projects for two years, from 2013 to 2015,
without adverse impacts on customer service.105 However, when EDTI clarified that it will
complete all the 2013 deferred work by the end of 2014, with some 2014 work being displaced
into 2015,106 Mr. Shymanski indicated that his recommendations on these two projects “would be
rendered moot.”107 Mr. Shymanski did not object to capital tracker treatment in 2014 for work
delayed from 2013.
115. Ms. Hull, for EDTI, provided evidence that there were four underground cable failures
associated with the 2013 deferred work resulting in approximately 32,000 customer hours of
service interruption. Ms. Hull also indicated that EDTI had a 19 times higher fault rate on the
deferred underground cable work from 2013 as compared to the rest of EDTI’s system.108 EDTI
also noted that there was a 12-hour service disruption in the two areas served by circuit N13,
which was identified for reconfiguration in 2013 as part of the New Underground Cable and
Aerial Line Reconfigurations and Extensions to Meet Customer Growth project, but deferred
from 2013 to 2014.109 EDTI did not identify any incidents of service interruption associated with
other deferred projects. However, this may be due to the fact that EDTI had prioritized its work
to deal with imminent failures:
But we picked places where we could defer some work for a short period without
substantially increasing the risk. And we set out how we did that throughout the
application. But, for example, with critical poles, or lifecycle replacement of poles, we
made sure we went out and got all the poles that were in a state of imminent failure,
where we knew these poles had to be addressed. Those poles that were in poor condition
but, from our analysis, we believed we could wait a short period of time and still get to
them prior to failure, we deferred those and are getting to them now. So that was the
approach we took across those programs. And now we're working hard to get that work
done because it is needed and there have been places, as we indicated in some of IRs,
where we had a failure of a cable that was planned for replacement in 2013 or we had a
failure on a circuit where we had intended to install a loop feed to address a radial feed
issue that resulted in a longer duration outage for customers. So there were a few places
where, because it took us longer than we anticipated to get back on the work, we saw the
impacts of that decision, but we're working to catch up on that, and then also, you know,
105
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, pages 4-6. 106
Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(d). 107
Transcript, Volume 5, page 750, lines 8-11 (Mr. Shymanski). 108
Transcript, Volume 2, page 304, line 18 to page 305, line 5 (Ms. Hull). 109
Proceeding 3100, Exhibit 94.01, CCA-EDTI-25(c).
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provide -- shows that these -- these -- this work is needed to be completed in order to
maintain the safety and reliability of the system.110
116. Overall, the Commission finds that the “substantial capital funding shortfall under the
I-X mechanism and the uncertainty respecting the capital tracker mechanism” is not a valid
business reason for EDTI to have delayed the work planned for 2013. However, given the above
considerations, the Commission will not disqualify from capital tracker treatment the five 2013
capital tracker projects delayed, in whole or in part, because of the “substantial capital funding
shortfall under the I-X mechanism and the uncertainty respecting the capital tracker mechanism.”
With respect to the portion of these five projects completed in 2013, the Commission will
consider the prudence of the actual 2013 capital additions in the 2013 capital tracker true-up
application. In addition, the Commission will consider, for capital tracker treatment in 2014, the
portions of the five projects approved for capital tracker treatment in 2013 deferred from 2013
into 2014. The Commission will also consider the portions of the 2014 work deferred to 2015,
due to the “cascading effect” described by EDTI.111
117. When questioned by the Commission during the hearing, EDTI could not identify any
specific cost increases resulting from its decision to defer some work from 2013 into 2014 and to
defer some of the 2014 work into 2015.112 However, EDTI acknowledged that there may be such
costs:
A. MR. ELFORD: So speaking on the capital costs side, I mean, obviously there's going
to be inflation. Hourly rates for unionized workers increase year over year, but that's
offset by the fact that these capital adds are being placed into service one year later.113
118. At the time of EDTI’s 2014 and 2015 capital tracker true-up applications, the
Commission will consider the prudence of the actual costs for the five projects deferred in 2013,
including any additional net costs that could have been avoided had the projects proceeded in
2013, as planned.
119. In argument, the UCA submitted that, “if, despite EDTI’s intention, as stated in its
rebuttal evidence, to complete the 2013 carry over work in 2014, EDTI does not in fact complete
the work in 2014, it should not be approved for Capital Tracker treatment in 2015.”114 In a similar
vein, when assessing the prudency of EDTI’s future forecast and actual expenditures on
proposed capital tracker projects, the CCA proposed the Commission take into account the fact
that EDTI was able to defer some projects in 2013, albeit for a short time and “with a view to
minimizing the risk of immediate and short term adverse effects on safety, service quality and
reliability.”115 In a number of IRs dealing with the projects deferred in 2013, the Commission
queried whether a similar amount of work could also be deferred in 2014 and 2015.116
120. The Commission will examine the prudence of EDTI’s capital additions associated with
the 2014 and 2015 capital tracker projects at the time of the 2014 and 2015 capital tracker true-
110
Transcript, Volume 2, pages 221-222 (Mr. Elford). 111
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford). 112
Transcript, Volume 2, pages 329-331 (Mr. Elford). 113
Transcript, Volume 2, page 328, lines 6-10 (Mr. Elford). 114
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 48. 115
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 22. 116
See, for example, Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(c).
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32 • Decision 3100-D01-2015 (January 25, 2015)
up application. In assessing the prudency of the 2014 and 2015 capital additions, the
Commission will consider all relevant factors, including any impact arising as a result of the
deferral of 2013 capital tracker projects. The Commission will also consider the fact that EDTI
was able to defer some projects in 2013 when assessing the forecast need and costs for capital
projects proposed for capital tracker treatment in both Proceeding 3100 and future EDTI capital
tracker forecast applications.
7 Project assessment under Criterion 1 – the project must be outside of the normal
course of the company’s ongoing operations
121. As discussed in Section 3 of this decision, consistent with paragraph 841 of Decision
2013-435, each of EDTI’s projects or programs proposed for capital tracker treatment will be
evaluated against the project assessment requirements of Criterion 1. The purpose of the project
assessment is to demonstrate that a project proposed for capital tracker treatment is (i) required
to provide utility service at adequate levels and, if so, (ii) the scope, level and timing of the
project are prudent, and the forecast or actual costs of the project are reasonable.117
122. EDTI’s applied-for capital trackers, in both the 2013 capital tracker true-up application
and the 2014-2015 capital tracker forecast application, can be broadly divided into two
categories. The first category consists of applied-for projects or programs approved for capital
tracker treatment in Decision 2013-435 for implementation in 2013. The second category
consists of projects or programs implemented in 2013, or to be implemented in 2014 or 2015 that
have not been previously approved for capital tracker treatment in Decision 2013-435
123. As also noted in Section 3, in assessing the prudence of a capital tracker program or
project that has been previously approved on a forecast basis for capital tracker treatment in 2013
and is now put forward for a true-up to actual 2013 costs, if there is no evidence on the record of
the true-up proceeding demonstrating that a project is not required, then there is no need to
demonstrate that a project is needed in order to provide utility service at adequate levels, which
constitutes the assessment of need under Criterion 1. However, the second part of the project
assessment under Criterion 1 is still required so that the Commission can be satisfied that the
scope, level and timing of each project is prudent, and the actual costs of the project were
prudently incurred.
124. With respect to projects or programs proposed for capital tracker treatment in 2014 or
2015 on a forecast basis, the applicant must satisfy all of the Commission’s requirements for the
project assessment under Criterion 1. To that end, a business case and an engineering study will
generally aid the Commission in conducting project assessments under Criterion 1. However, as
discussed in Section 3, in those instances where a project or program is part of an ongoing multi-
year program, or if a project or program is of an annual recurring nature (e.g., relocations) that
has been previously approved by the Commission for capital tracker treatment, in the absence of
evidence that the ongoing or recurring project or program is no longer required, the Commission
will not undertake a reassessment of need under Criterion 1.
125. EDTI provided a business case together with an engineering study (where EDTI
considered either document to be applicable) for each of its projects or programs proposed for
117
Decision 2013-435, paragraph 278.
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Decision 3100-D01-2015 (January 25, 2015) • 33
capital tracker treatment in 2014 or 2015. In its business cases, as supplemented by other
evidence filed in the proceeding, EDTI has generally provided an assessment of proposed capital
tracker projects consistent with the minimum filing requirement guidelines set out in
Section 10.2 of Decision 2013-435.118
126. The Commission has evaluated the EDTI business cases, engineering studies, cost related
information, and related evidence and argument against each of the project assessment minimum
filing requirements. However, for the purposes of this decision, the Commission has commented
only on those aspects of the minimum filing requirements that the Commission considers are
insufficiently addressed by EDTI’s evidence or were otherwise raised as an issue in the
proceedings. In future capital tracker applications, EDTI should continue to provide similar
information with respect to each of the minimum filing requirements, including business cases,
engineering studies and cost related information, including costs by cost category, unit costs and
historical cost comparators, in sufficient detail to allow an evaluation of the reasonableness of its
forecasts and the prudence of its incurred costs.
127. The balance of this section is organized as follows: Section 7.1 deals with common issues
related to the project assessment of EDTI’s projects, such as assumptions in developing EDTI’s
capital expenditure forecasts; the company’s internal cost controls and accountability
mechanisms with respect to quality, safety and cost for capital projects approved for capital
tracker treatment; and the UCA’s comments on the Criterion 1 requirement that, in the absence
of the proposed capital expenditures, deterioration in service quality and safety would result. The
Commission’s project assessment under Criterion 1 of EDTI’s projects or programs previously
approved for capital tracker treatment in Decision 2013-435 is set out in Section 7.2. The project
assessment of EDTI’s projects or programs that have not been previously approved for capital
tracker treatment is set out in Section 7.3.
7.1 Common issues
7.1.1 Common assumptions in EDTI’s capital expenditure forecasts
128. In the 2014-2015 capital tracker forecast application, project estimates were generally
prepared by internal engineering and management personnel, and in some cases by external
consulting engineers with direct involvement in certain projects.
129. For labour cost forecasts, EDTI used a man-hours by employee classification basis and
applied standard rates based on available collective bargaining agreements. The 2014 and 2015
labour rates for members of the International Brotherhood of Electrical Workers (IBEW) were
derived from the collective bargaining agreement currently in place. For members of the Civic
Service Union (CSU), labour rates were estimated by applying an escalation factor to the 2013
rates because the previous collective bargaining agreement had expired and a new collective
bargaining agreement had not been finalized when EDTI submitted its application.119
130. Engineering salary costs were estimated on a man-hour basis by resource type using
standard engineering rates based on actual payroll costs. The 2014 salary costs were based on
2013 actual payroll costs and the 2015 salary costs were based on 2014 payroll costs. EDTI
explained that its 2014 salary costs were prepared in a detailed forecast in 2013. However, EDTI
118
Decision 2013-435, paragraph 1092. 119
Proceeding 3100, Exhibit 93.01, AUC-EDTI-4(a).
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34 • Decision 3100-D01-2015 (January 25, 2015)
did not update this forecast in early 2014 given it would have required a significant amount of
time and yield little benefit. The 2015 salary cost forecast was updated in early 2014, because a
detailed forecast for 2015 had not yet been prepared.120
131. Material and contractor resources were estimated using current costs based on the scope
of work identified by the group initiating the work. EDTI also used cost information from similar
previously constructed projects, where available, in its estimates. EDTI used external resources,
such as suppliers of materials and construction contractors, to assist in developing expenditure
forecasts. For special order material not maintained in stock by EDTI, it consulted suppliers for
forecast estimates of the required materials. Construction contractors were also consulted for
forecast estimates for specialized construction services normally not carried out by EDTI’s
internal labour force.
132. EDTI indicated that its 2014 and 2015 capital expenditures were forecast in 2013 dollars
and 2014 dollars, by expense type such as union labour, engineering, materials, contractors and
vehicles. All costs were then inflated using escalation factors for 2014 and 2015. EDTI stated
that it did not engage external consultants to provide forecasts and reports in support of EDTI’s
chosen escalation factors, as was EDTI’s practice under cost-of-service regulation.
133. EDTI used the following inflation factors for its 2014 and 2015 capital tracker forecasts:
A four per cent salary escalation factor was applied for non-union staff.
A 3.2 per cent and 3.4 per cent salary escalation was applied for unionized CSU staff for
2014 and 2015, respectively. A 3.5 per cent salary escalation factor was applied for
unionized IBEW staff for both 2014 and 2015.
Employee fringe benefit rates of 42.3 per cent and 43.69 per cent were applied to all
salary and labour costs, for 2014 and 2015, respectively.
For 2014 and 2015, contractor cost inflators were 3.2 per cent and 3.4 per cent, material
cost inflators were 1.8 per cent for both years, and inflators for other costs were
2.2 per cent and 2.1 per cent, respectively.121
134. EDTI confirmed that its 2014 forecast escalation factor for non-union (salary) staff was
based on advice provided by Towers Watson in respect of the level of escalation applicable to
non-union salaries for 2014 and was consistent with the escalation factors used in its 2013-2014
transmission facility owner (TFO) tariff application, reviewed in Proceeding 2758.122 For 2015,
EDTI used the same escalation factor and the same inflation rate that it applied in its 2014
forecast. EDTI further confirmed that the labour rates for the unionized IBEW staff were subject
to a collective bargaining agreement for 2014 and 2015. EDTI also provided, for each proposed
capital tracker, the proportion of capital additions associated with CSU, IBEW and non-union
labour costs. In regard to non-union labour costs, the highest proportion of costs for a proposed
capital tracker in either 2014 or 2015 was three per cent.123
120
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 39. 121
Proceeding 3100, Exhibit 80, application, paragraph 39. 122
Proceeding 2758, EPCOR Distribution & Transmission Inc., 2013-2014 Transmission Facility Owner Tariff
Application, Application 1609817. 123
Proceeding 3100, Exhibit 95.01, UCA-EDTI-7, Attachment 2.
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Decision 3100-D01-2015 (January 25, 2015) • 35
135. In an IR response to the UCA, EDTI performed a sensitivity analysis, applying a
0.5 per cent reduction in all its escalation factors to calculate the applied-for 2014 and 2015
K factor amounts. EDTI explained that a 0.5 per cent reduction in all its escalation factors in
2014 would lower the K factor from $3.80 million to $3.78 million and in 2015 the K factor
would decrease from $9.43 million to $9.40 million. EDTI also confirmed that the 0.5 per cent
escalation factor reduction would not result in any of its applied-for capital tracker projects
failing to meet Criterion 3.124
136. After inflating all costs, EDTI applied employee fringe benefits to all salary and labour
costs using the fringe benefit rates of 42.3 per cent and 43.69 per cent for 2014 and 2015. EDTI
also noted that the 2012 actual and 2013 preliminary actual fringe benefit rates were 41.3 and
41.1 per cent, respectively. EDTI explained that the increase in employee benefit costs, as a
percentage of base compensation, from the 2011 actual amount of 37.8 per cent to the 2014 and
2015 forecast amounts was primarily due to an increase in contribution rates for the Local
Authorities Pension Plan (LAPP). Contribution rates for the LAPP are determined by the LAPP
administrator and not under EDTI’s control.125 EDTI based its 2015 forecast LAPP contribution
rate on an average of the 2011 to 2013 annual contribution rate increase. EDTI provided a table
comparing the historical actual and forecast fringe benefit rates from 2008 to 2015.126
137. Further contributing to the increase in fringe benefit rates is the change to the EDTI
Management Savings Plan (MSP). EDTI indicated that as of July 2012, the maximum amount of
employer matching under the MSP increased from three per cent to five per cent.127
138. EDTI used a capital overhead rate forecast of six per cent for both 2014 and 2015. The
same overheard rate was used for both 2014 and 2015 because EDTI had not completed its
operating budget for 2015 at the time of this application.128
139. In certain cases, EDTI relied on its computerized Work Management System (WMS) to
develop capital project forecasts by breaking down the forecast work into its basic construction
components. The basic construction components include defining the capital project design,
reviewing the practicality of the proposed capital or maintenance work and the various work
components (labour, materials, vehicles, contractors). The WMS then produces cost expenditure
forecasts and man-hour forecasts by the labour class required to carry out the work. EDTI’s
operations, engineering and management personnel also review standard tasks and estimates of
man hours by task type to ensure the reasonableness of the forecast and to reflect any changes in
resource requirements resulting from changes in safety or construction standards, changes to
crew complements or other factors impacting the estimates.
140. For other types of work that could not be broken down into construction components
because of insufficient information, EDTI provided the other forecasting methods used, such as a
three-year normalized average. EDTI also applied a project-specific estimation process for
known tasks that were not easily broken down into standard tasks, and for tasks that are not
considered standard due to the uniqueness or specificity of the work. EDTI stated that for
projects not easily broken down into standard tasks for processing through the WMS, estimates
124
Proceeding 3100, Exhibit 95.01, UCA-EDTI-7(d). 125
Proceeding 3100, Exhibit 93.01, AUC-EDTI-04(b). 126
Proceeding 3100, Exhibit 93.01, AUC-EDTI-4(b). 127
Proceeding 3100, Exhibit 93.01, AUC-EDTI-4(b). 128
Proceeding 3100, Exhibit 80, application, paragraph 39.
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36 • Decision 3100-D01-2015 (January 25, 2015)
were based on preliminary engineering designs and the project scope described in the business
cases. Cost data from previous jobs of a similar nature was also used to validate any forecast
estimates.
141. In an IR response to the Commission, EDTI explained that under PBR, there exists an
incentive for EDTI to minimize these costs regardless of the fact that capitalized expenditures
associated with approved capital trackers are trued-up. Specifically, EDTI stated the assumptions
for inflation, fringe and overhead costs are applied to both capital tracker forecast costs and
operating costs, the latter of which are subject to the I-X mechanism. EDTI explained that it,
therefore, has an incentive to minimize these costs so the operating costs are fully recovered
under the I-X mechanism and so that potential cost savings are realized under PBR.129
142. EDTI also acknowledged that the true-up of approved capital tracker costs are subject to
a prudency review by the Commission. EDTI submitted that it expects “rigorous scrutiny” of its
costs and the prudency review further provides an incentive for EDTI to minimize its standard
costs as much as possible.130
Commission findings
143. The Commission recognizes that a portion of EDTI’s labour and salary costs are based on
the negotiated results of collective bargaining agreements between EDTI and employee unions.
Furthermore, where no collective bargaining agreement was in place for 2014 and 2015, EDTI
indicated that it used previous agreement amounts to determine its forecasts. The Commission
notes that the unionized CSU staff escalation rates of 3.2 and 3.4 per cent for 2014 and 2015,
respectively, are consistent with the 3.5 per cent escalator in 2013 and 3.2 per cent escalator in
2014 approved by the Commission in EDTI’s 2013 and 2014 TFO tariff Decision 2014-269.131
Furthermore, the 2014 and 2015 unionized IBEW staff escalation rate of 3.5 per cent is
consistent with the 3.5 per cent rate approved by the Commission in Decision 2014-269 for
2014.132
144. Accordingly, the Commission finds the IBEW union escalation rates established through
the collective bargaining processes to be reasonable for the purposes of determining the labour
cost associated with proposed capital tracker expenditures. The Commission finds the escalation
rates used by EDTI in relation to the CSU, in the absence of a finalized collective bargaining
agreement, to be consistent with past agreements and Commission decisions. Accordingly the
Commission finds these escalation rates to be reasonable.
145. EDTI applied for a 4.0 per cent escalation factor for the non-union (salary) employees for
2014 and 2015. The Commission notes that this is the same escalation factor EDTI proposed in
its 2013-2014 TFO Tariff application for 2014. In Decision 2014-269, the Commission found
that a 2014 escalation factor of 3.5 per cent for non-union employees would allow EDTI to
remain market competitive.133
129
Proceeding 3100, Exhibit 93.01, AUC-EDTI-4(c). 130
Proceeding 3100, Exhibit 93.01, AUC-EDTI-4(c). 131
Decision 2014-269: EPCOR Distribution & Transmission Inc., 2013 and 2014 Transmission Facility Owner
Tariff, Application No. 1609817, Proceeding No. 2758, September 18, 2014, paragraph 160. 132
Decision 2014-269, paragraph 162. 133
Decision 2014-269, paragraphs 169 and 170.
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146. The Commission notes that under PBR, the non-union salary costs are common to
forecasting both O&M salary expenses and capital expenditures for projects that are fully funded
under the I-X mechanism and those that require incremental funding through capital trackers.
Given that these salary costs are common costs, the Commission recognizes there remains an
incentive for EDTI to minimize these costs in order to realize potential cost savings under PBR.
147. The Commission further acknowledges that the impact of the difference in non-union
salary cost escalators between the 4.0 per cent applied for in this application and the 3.5 per cent
approved in Decision 2014-269 is likely not significant on a forecast basis for capital tracker
expenditures, given the sensitivity analysis performed by EDTI on all its escalation factors in
UCA-EDTI-7(d).134 In addition, the Commission notes that there would likely be substantial time
and effort involved in EDTI recalculating all its 2014-2015 forecast capital tracker expenditures
to account for the 0.5 per cent difference in non-union salary escalators. The Commission finds
that regulatory efficiency is best served in this case, recognizing there is a true-up mechanism
and considering the likely minimal impact of the 0.5 per cent change in salary escalation, by not
requiring EDTI to recalculate all the capital tracker costs with a reduced salary escalator. Neither
the UCA nor the CCA objected to EDTI’s salary escalators for 2014 or 2015.
148. The Commission does recognize that Decision 2014-269 reduced EDTI’s salary
escalation factor from 4.0 per cent to 3.5 per cent. However, the Commission is cognizant of the
differences in purpose between this decision and Decision 2014-269. The purpose of
Decision 2014-269 was to set rates for the transmission function of EDTI on a forecast basis,
whereas the purpose of this decision is to establish forecast capital tracker amounts as part of a
PBR plan for EDTI’s distribution function. Unlike EDTI’s TFO tariff approved revenue
requirement, the 2014-2015 capital tracker forecasts approved in this application are subject to a
full true-up following a prudency review of actual capital expenditures. Given the different
purposes between the two applications, for the purposes of this decision, the Commission finds
that it is not necessary to ensure that all factors used by EDTI in forecasting capital expenditures
are the same for both the transmission and distribution functions.
7.1.2 Controls and accountability
149. During the hearing, EDTI was questioned by Commission counsel on its internal controls
and accountability mechanisms with respect to quality, safety and cost for capital projects
approved for capital tracker treatment, and whether these controls and mechanisms were any
different than the measures put in place for capital projects that have not been extended capital
tracker treatment. EDTI reviewed its internal control procedures and confirmed that there are no
differences in how these procedures are applied among its capital project, apart from the
difference in the process of filing capital trackers. EDTI also discussed its cost overrun review
process and confirmed that the review of cost overruns is not treated any differently among its
capital projects as between capital tracker projects and capital projects that have not been
extended capital tracker treatment.135
150. With respect to the accountability of project managers, directors and related EDTI
executives, EDTI confirmed that the performance and compensation of such individuals is, in
134
Proceeding 3100, Exhibit 95.01, UCA-EDTI-7(d). 135
Transcript, Volume 2, page 244, lines 8-11 (Mr. Elford).
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part, measured against the capital program plan and the cost control performance objectives for
the capital projects they manage directly or indirectly.136
Commission findings
151. PBR encourages a company to seek out and realize cost reductions continually with
respect to those functions and activities funded under the I-X mechanism in order to enhance
overall profitability. These activities will in turn benefit ratepayers immediately through the X
factor and over the longer term through lower costs than might otherwise be the case thereby
keeping rates lower than they might be otherwise. Capital projects funded through capital tracker
treatment with a true-up to actual costs are not, however, subject to these same, high powered,
incentives. Accordingly, the Commission requires sufficient information in capital tracker
forecast and true-up applications on the proposed capital tracker projects themselves, as well as
the processes in place to manage those projects, in order to confirm the need for the project in the
manner that is proposed, and to ensure the prudence of the costs incurred.
152. The Commission considers that formal project management policies and procedures are
necessary to ensure the Commission understands that the scope, level, timing and costs of
forecast capital projects are reasonable and actual costs are prudently incurred. The Commission
directs EDTI to describe fully its formal project management policies and procedures in its next
capital tracker application.
7.1.3 Requirement that in the absence of the proposed capital expenditures,
deterioration in service quality and safety would result
153. In Decision 2012-237, the Commission stated the following regarding the first capital
tracker criterion:
594. … This criterion is also required to ensure that capital tracker projects are of
sufficient importance that the company’s ability to provide utility service at adequate
levels would be compromised if the expenditures are not undertaken. Projects that do not
carry this level of importance are likely subject to a reasonable level of management
discretion, therefore allowing special treatment for this type of capital would eliminate
the incentive for the company to examine all alternatives. Therefore, this criterion would
require that an engineering study be filed to justify the level of capital expenditures being
proposed. That is, the company must demonstrate that the capital expenditures are
required to prevent deterioration in service quality and safety, and that service quality and
safety cannot be maintained by continuing with O&M and capital spending at levels that
are not substantially different from historical levels...137 [footnote omitted]
154. In Decision 2013-435, the Commission further elaborated on Criterion 1 requirements
and determined that for the purpose of the project assessment, in support of a project or program
proposed for capital tracker treatment, a company should provide, among other requirements:
1092. …
c. Evidence demonstrating that in the absence of the proposed capital expenditures,
deterioration in service quality and safety would result.138
136
Transcript, Volume 2, page 248, line 9 to page 249, line 2 (Mr. Elford). 137
Decision 2012-237, paragraph 594. 138
Decision 2013-435, paragraph 1092 c.
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155. In its argument, the UCA explained its interpretation of this requirement as:
Evidence demonstrating that in absence of the capital expenditures associated with a
proposed capital tracker project for a given year, deterioration in service quality and
safety would result in that year.139 [emphasis added]
156. According to the UCA, the fact that service quality may be impacted at some
indeterminate time in the future does not constitute a basis for affording capital tracker treatment.
Therefore, the UCA argued:
In the UCA’s view, if the projects are of a sufficient level of importance to satisfy the
capital tracker criteria, they are truly required in the year applied for, and must be
completed in that year absent some extraordinary event. Capital Tracker Applications are
made for particular years, and in the UCA’s view, it is logical that the Commission
intended that the criteria must be met with respect to the years for which Capital Tracker
treatment is sought.140
157. In its argument, EDTI explained that “the relationship between undertaking the capital
program and the impact to service quality is broader than the direct and immediate impact of the
program.”141 During the hearing, Mr. Elford explained:
In the case of other capital trackers, the impact can show over time. And so things like
lifecycle replacement of underground cables. We've studied it and we know that if we
don't deal with a certain amount of cable on average on a year-over-year basis, our
reliability will deteriorate over time.
And to hold off on that and simply run things to failure is going to degrade reliability and
make the problem worse and worse over time. And we don't have just-in-time
replacement. We select the worst assets on our systems to deal with on a year-over-year
basis to maintain reliability, but we can't -- we can't always say this cable will fail on
September 5th of 2014 so we should change it on September 4th of 2014 in order to
maintain reliability. These are ongoing programs based on the age and the condition of
our system that we have to continue to do or reliability will degrade.142
158. EDTI further explained its aversion to the “just in time” approach to life-cycle
replacements and noted that as a company falls further behind on a replacement program, it
becomes more difficult to catch up and replace the aged assets. EDTI stated that the “just in
time” approach “would result in the deterioration of its service reliability and safety in both a
gradual degradation of its reliability statistics, as well as the possibility for sudden drops.”143 As
an example of these “sudden drops,” EDTI highlighted that a temporary delay in Life-Cycle
Replacement programs in 2013 resulted in 32,000 hours of customer interruption due to
underground cable failures and another 12 hours of customer interruption due to an outage on the
N13 circuit.144
139
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 2. 140
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 8. 141
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 33. 142
Transcript, Volume 2, pages 219-220 (Mr. Elford). 143
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 38. 144
Proceeding 3100, Exhibit 93.01, AUC-EDTI-10(c). Transcript, Volume 2, page 304, line 18 to page 305, line 5
(Ms. Hull). Proceeding 3100, Exhibit 94.01, CCA-EDTI-25(c).
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159. In its reply argument, EDTI further elaborated on the UCA’s proposal:
EDTI also submits that whether measurable deterioration in safety and reliability would
occur within the particular year is not meaningful. EDTI’s evidence demonstrates that
failure to do the work will inevitably result in deterioration in safety and reliability, and
dealing with the problem at a later time (e.g., using a “just in time” or “run to failure”
approach) will simply place EDTI and customers at substantially increased ongoing risk
from a safety and reliability perspective, and it will cost customers more in the end than
dealing with the problem on a sensible, prudent, proactive basis as EDTI has done in the
past and proposes to continue to do under PBR.145
Commission findings
160. The Commission does not agree that the requirement under Criterion 1 specified in
paragraph 1092 c. of Decision 2013-435 should be interpreted so as to require the company to
provide evidence demonstrating that, in absence of the capital expenditures associated with a
proposed capital tracker project “for a given year,” deterioration in service quality and safety
would result “in that year,” as recommended by the UCA.146 For the reasons below, the
Commission considers that the UCA’s interpretation is too restrictive in the circumstances of
most capital replacement and upgrade programs intended to maintain system reliability and
safety.
161. EDTI submitted “the relationship between undertaking the capital program and the
impact to service quality is broader than the direct and immediate impact of the program.”147
Capital projects typically involve the construction of long-lived assets, which provide service to
customers for many years. As such, requiring the company to demonstrate that, in absence of the
capital expenditures for a capital tracker project, deterioration in service quality and safety would
result “in that year” does not comport, in most instances, with the long-lived nature of capital
assets. The Commission agrees with Mr. Elford that, while there might not be a direct and
immediate impact to not completing the project in a specific year, not proceeding with the
project will result in a deterioration in reliability over time.148
162. Furthermore, a requirement that deterioration in service quality and safety would result
“in that year” may prevent the company from selecting the best course of action, including the
best timing, to achieve the least cost alternative for a particular capital tracker project. As a
result, the company is charged with presenting compelling evidence that the scope, level, and
timing of the proposed capital tracker program is prudent and that the forecast costs are
reasonable in that year to maintain system reliability and safety to prevent deterioration in system
reliability and safety, either in that year or over time.
7.2 Previously approved capital tracker projects or programs
163. This section deals with EDTI’s projects or programs that were approved for capital
tracker treatment on a forecast basis in Decision 2013-435. It considers these projects or
programs in the context of the true-up of 2013 actual expenditures and, if they are proposed to
continue in 2014 and 2015, this section also considers the 2014 and 2015 forecasts.
145
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 11. 146
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 2. 147
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 33. 148
Transcript, Volume 2, pages 219-220 (Mr. Elford).
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7.2.1 Third-party Driven Relocations
164. EDTI explained that this capital tracker program is composed of individual projects that
involve the relocation of existing distribution facilities as required by third parties, such as the
City of Edmonton (City) under the terms of EDTI’s franchise agreement with the City. The
grouping of Third-party Driven Relocations under a single program was directed and approved
by the Commission in Decision 2013-435.149
165. The four Third-party Driven Relocation projects included in the 2013 capital tracker true-
up application consist of the Southeast and West LRT Distribution System Relocations,
Franchise Agreement Driven Relocations and Conversions, the Queen Elizabeth II (QEII) and 41
Avenue Interchange Distribution System Relocations, and the North LRT Distribution System
Relocations. In the 2014-2015 capital tracker forecast application, a fifth project was added to
this program, the Walterdale Bridge Replacement Distribution System Franchise Relocation.
166. EDTI explained that all projects within this program are required to meet the terms of its
franchise agreement with the City of Edmonton and to comply with its obligations under
sections 105 and 127 of the Electric Utilities Act.150 EDTI indicated that the franchise agreement
provides that EDTI must relocate its distribution facilities and perform any other work respecting
its distribution facilities as may be required by the City to accommodate any relocation,
installation, modification, repair, construction, upgrading or removal of City facilities.
167. Table 4 below shows EDTI’s approved forecast and actual costs of the four projects
comprising this program in 2013.
Table 4. Actual and approved capital additions for Third-party Driven Relocations projects ($ million)151
Project 2013
approved 2013
actual Variance
Southeast and West LRT Distribution System Relocation 3.99 5.22 1.23
Franchise Agreement Driven Relocations and Conversions 5.04 3.25 (1.79)
QEII and 41 Avenue Interchange Distribution System Relocations 2.00 2.50 0.50
North LRT Distribution System Relocations -- -- --
Program Total 11.03 10.97 (0.06)
168. The Southeast and West LRT Distribution System Relocation project involved the
relocation of EDTI’s distribution infrastructure at the direction of the City of Edmonton, in
connection with the City’s transportation plan to extend the LRT route from southeast to west
Edmonton via downtown. EDTI explained that its 2013 forecast was based on the City’s
preliminary design for this project. Throughout 2013, the City continued to refine the LRT
extension design and progressed to the 90 per cent design stage. This refinement resulted in
several changes to the LRT route alignment, for example, the location of the downtown
terminus, 75 Street route alignment changes, and changes to the elevated LRT structure crossing
Argyll Road, Coronet Road and the CPR tracks along 75 Street. These changes to the LRT route
149
Decision 2013-435, paragraph 838. 150
Proceeding 3100, Exhibit 80, application, paragraph 93. 151
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 50, 91, 124 and 154.
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alignment resulted in EDTI’s 2013 actual capital additions for this project being $1.23 million
higher than the 2013 approved amount, as shown in Table 4.152
169. Under the Franchise Agreement Driven Relocations and Conversions project, EDTI
removes and relocates its distribution facilities that are in conflict with the City’s road-widening
or other types of construction, and development or municipal infrastructure improvement plans,
not included in any other major projects of the Third-party Driven Relocations program. The
level of capital expenditures for the Franchise Agreement Driven Relocations and Conversions
project is driven by the number and complexity of relocations and conversions required by the
City.
170. EDTI explained that its 2013 forecast capital additions for this project were based on the
City of Edmonton’s Implementation Plan of the Transportation Master Plan, which identified the
major roadway widening and relocation projects the City expected to proceed with in 2013
through 2014. EDTI indicated that its 2013 actual capital additions for this project were
$1.79 million lower than the 2013 approved amount due to a lower number of City-mandated
franchise projects than was contemplated in EDTI’s 2013 forecast.153
171. The QEII and 41 Avenue Interchange Distribution System Relocations project consisted
of the relocation of EDTI’s distribution infrastructure that was in conflict with the City’s
construction plans for a partial cloverleaf interchange at QE II Highway and 41 Avenue SW in
Edmonton. The City directed EDTI to complete its distribution infrastructure relocations in 2013
to facilitate the planned timing of the construction of the interchange. In 2013, EDTI completed
the vast majority of the work associated with this project and placed it into service. The project
continued into 2014.
172. As shown in Table 4, EDTI’s 2013 actual capital additions for this project were
$0.50 million higher than the 2013 approved amount. The $0.50 million increase was primarily
driven by revisions to the project scope with respect to the crossing of the railway and pipeline
corridor adjacent to the highway:
EDTI’s 2013 PBR Capital Tracker Application for this project was based on EDTI’s
expectation that EDTI would be able to directionally drill from the west side of the QEII
Highway in order to relocate its distribution feeder under the QEII Highway interchange,
and then connect the new cable to an existing cable on the east side of the highway at a
point before that cable ran under an adjacent railway and pipeline corridor. On December
14, 2012, subsequent to EDTI submitting its 2013 PBR Capital Tracker Application,
CH2M Hill, Alberta Transportation’s engineering and project management consultant,
informed EDTI that EDTI could not use the existing cable crossing under the railway and
pipeline corridor as the pipelines within the corridor were not deep enough based on the
most up to date interchange design and needed to be lowered. As such, EDTI’s existing
cable crossing location was in conflict with the newly proposed pipeline depths and
therefore could not be used as originally contemplated. EDTI was required to complete
two separate directional drills and install a longer length of cable.154
152
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 85-87. 153
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 115-117. 154
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 122.
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173. The North LRT Distribution System Relocations project was completed in 2011 and
involved the relocation of both aerial and underground power facilities that were in conflict with
the planned route for North LRT extension. This project was included in the Third-party Driven
Relocations program as a negative K factor project, pursuant to the Commission’s direction in
Decision 2013-435. As such, there were no forecast capital additions associated with this project
in 2013 and, therefore, EDTI did not provide a business case for this project.
174. In the 2014-2015 capital tracker forecast application, EDTI applied for continuation of
capital tracker treatment for the Third-party Driven Relocations program. As noted earlier in this
section, in addition to the four projects continued from 2013, EDTI applied for capital tracker
treatment for the Walterdale Bridge Replacement Distribution System Franchise Relocation
project. Table 5 below presents forecast capital additions associated with this program in 2014
and 2015.
Table 5. 2014-2015 forecast capital additions for Third-party Driven Relocations projects ($ million)155
Project name Business case
(Proceeding 3100) 2014
forecast 2015
forecast
Southeast LRT Distribution System Relocation Appendix A-1-1 21.58 18.02
Franchise Agreement Driven Relocations and Conversions Appendix A-1-2 3.64 3.77
Walterdale Bridge Replacement Distribution System Franchise Appendix A-1-3 0.45 4.22
QEII and 41 Avenue Interchange Distribution System Relocations -- 0.13 0.00
North LRT Distribution System Relocations -- -- --
Program Total 25.80 26.01
175. EDTI indicated that its forecast for the Southeast LRT Distribution System Relocation
project is based on the City’s 90 per cent preliminary design package issued to EDTI in
January 2013, extensive dialogue with the City and the City’s LRT design and utility relocations
consultant, Connect Ed Transit Partnership (CETP), and EDTI’s ongoing review of design and
scope changes and related project updates provided by the City and CETP. On January 22, 2014,
EDTI was advised at a utility coordination meeting with CETP that it has until the end of 2015 to
complete its distribution infrastructure relocations for the Southeast LRT route. This work was
previously scheduled for the end of 2014.
176. Also, at the January 22, 2014 utility coordination meeting, EDTI was advised that the
City will not require utility companies to begin any relocations for the West LRT expansion
route at this time. As such, EDTI does not plan to carry out any preliminary engineering work on
the West LRT extension in 2014 and 2015 as previously planned, and has removed the work
relating to the West LRT system expansion from the scope of work originally included in the
2013 forecast application. Further work will be required by 2016 to accommodate the West route
and by 2017 to accommodate construction in the downtown core.
177. Finally, because the Southeast LRT design has not been finalized, EDTI noted that as the
City of Edmonton plans continue to evolve, additional utility work can be expected to be
identified and, as a result, the 2014-2015 forecast costs shown in Table 5 are likely conservative.
EDTI indicated it continues to work closely with the City and its design and utility relocation
consultant to minimize the number and extent of the distribution facility relocations where
155
Proceeding 3100, Exhibit 93.02, AUC-EDTI-01 Attachment 1, revised Table 2.3-1.
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possible, and to identify and implement the least cost alternative for addressing each conflict that
cannot be avoided.156
178. With respect to the Franchise Agreement Driven Relocations and Conversions project
forecast expenditures, EDTI advised that its forecast is composed of both specific, known
projects that the City has identified at the time and other relatively small, and recurring capital
projects that EDTI must undertake each year under the terms of its Franchise Agreement with the
City. At the time of filing the 2014-2015 capital tracker forecast application, the City did not
forecast any major projects for 2015. Therefore, EDTI’s forecast capital additions for 2015 for
this project were based on an expectation, informed by its ongoing discussions with the City, of a
similar overall volume of franchise work in 2015 compared to the forecast total demand for
franchise work in 2014 and the preliminary actual demand in 2013.157
179. The Walterdale Bridge Replacement Distribution System Franchise project is the result
of the City’s plan to replace the old bridge with a new one. The City of Edmonton has directed
that EDTI’s distribution infrastructure relocations be completed for the new bridge alignment by
the end of 2015 to facilitate the removal of the old Walterdale Bridge.158 Originally, the City had
stated its preference that no utilities would be located on the new Walterdale bridge, but EDTI
advised the City that if it were not allowed to relocate its existing infrastructure to the new
bridge, the cost of running distribution across the river would be “far higher.”159 The City agreed
to allow EDTI to use the bridge for the relocation of its facilities, allowing EDTI to select the
least cost alternative.
180. As noted earlier in this section, EDTI completed the vast majority of the work associated
with the QEII and 41 Avenue Interchange Distribution System Relocations project and placed it
into service in 2013. However, EDTI was not able to complete the removal of a portion of its
aerial pole and line distribution infrastructure and associated landscape restoration work by the
end of 2013. EDTI now plans to complete the remaining work in 2014 at a forecast cost of $0.13
million.160
181. As also explained earlier in this section, the North LRT Distribution System Relocations
project was completed in 2011 and was included in the Third-party Driven Relocations program
as a negative K factor project, pursuant to the Commission’s direction in Decision 2013-435. As
such, there are no forecast capital additions associated with this project in 2014-2015. In his
evidence, Mr. Shymanski, for the UCA, indicated that he did not agree with EDTI’s proposed
treatment of the North LRT project.161 The Commission considered Mr. Shymanski’s concern in
Section 5 of this decision dealing with project grouping.
182. EDTI indicated that none of the capital projects included in the third party driven
relocations program could have been undertaken in the past as part of a prudent capital
maintenance and replacement program. This is because the need to relocate EDTI’s distribution
system arises as City infrastructure must be expanded, moved or otherwise modified. As such, by
156
Proceeding 3100, Exhibit 1, Appendix A-1-1, paragraphs 10-11. 157
Proceeding 3100, Exhibit 16, Appendix A-1-2, paragraphs 3-4. 158
Proceeding 3100, Exhibit 17, Appendix A-1-3, paragraphs 1-2. 159
Proceeding 3100, Exhibit 17, Appendix A-1-3, paragraph 15. 160
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 128. 161
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraphs 58-65.
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their nature, these projects are not associated with activities that could have been included in any
reasonable or prudent way in a capital maintenance program implemented in previous years.
183. In its business cases, EDTI explained that it takes a number of specific steps to minimize
project costs, including coordination with other projects, purchases of materials and hiring of
contractors based on competitive bids, limiting inventory variations in materials, and project
assessment to determine the minimum level of equipment required.162
Commission findings
184. In Decision 2013-435, the Commission determined that each of the projects comprising
the Third-party Driven Relocations program was required to maintain service reliability and
safety at adequate levels in 2013. Further, the Commission determined that the scope, level,
timing and forecast costs for each of the projects comprising this program were reasonable as
proposed for 2013. Accordingly, the Commission found that this program satisfied the project
assessment requirement of Criterion 1.163
185. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the Third-party Driven
Relocations program was not required in 2013.
186. Regarding the scope, level and timing of the Third-party Driven Relocations program
carried out in 2013, the Commission has reviewed EDTI’s aggregate 2013 actual capital
additions of $3.17 million associated with this program and finds that they are generally
consistent with the scope, level and timing of the work outlined in the business case for this
capital tracker and approved in Decision 2013-435. Where actual project costs significantly
differ from the approved forecast (as in the case of Southeast and West LRT Distribution System
Relocation project and the Franchise Agreement Driven Relocations and Conversions project),
the Commission accepts EDTI’s explanations that these differences were primarily driven by the
changes to the scope, level and timing of the work, reflecting the evolution and refinement of the
City of Edmonton’s infrastructure improvement plans. The Commission has also reviewed the
costs of the actual capital additions for each project comprising this capital tracker program in
light of the evidence supporting these costs, the associated procurement and construction
practices and the evidence explaining the differences between approved forecast and actual costs,
and finds the actual costs to be prudent.
187. EDTI requested to continue capital tracker treatment for the Third-party Driven
Relocations program in 2014 and 2015, including continuation of the four projects approved for
2013. As noted in Section 3, where a project or program is part of an ongoing multi-year
program, or if a project or program is of an annual recurring nature that has been previously
approved by the Commission for capital tracker treatment, in the absence of evidence that the
ongoing or recurring project or program is no longer required, the Commission will not
162
Proceeding 3100, Exhibit 17, Appendix A-1-3, paragraph 32. Proceeding 3100, Exhibit 16, Appendix A-1-2,
paragraph 29. Proceeding 3100, Exhibit 1, Appendix A-1-1, paragraph 100. Proceeding 3100, Exhibit 71,
Appendix H, paragraph 32. 163
Decision 2013-435, pages 176-178 and 186.
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undertake a reassessment of need under Criterion 1. However, the second part of the project
assessment under Criterion 1 is still required so that the Commission can be satisfied that the
scope, level and timing of each project are prudent, and the forecast costs of the project are
reasonable.
188. The Commission finds no evidence on the record of Proceeding 3100 to indicate that the
four continuing Third-party Driven Relocations projects are not required to continue in 2014 or
2015. In this regard, the Commission notes that during the hearing, Mr. Shymanski supported
capital tracker treatment for this project “because if we don't do those projects there will be a
deterioration of service.”164
189. In addition to the four projects continued from 2013, EDTI applied for capital tracker
treatment for the new Walterdale Bridge Replacement Distribution System Franchise Relocation
project. The Commission has reviewed the business case and engineering study for the
Walterdale Bridge Replacement Distribution System Franchise Relocation project and accepts
the evidence of EDTI that this project is required to satisfy EDTI’s franchise agreement with the
City of Edmonton and, accordingly, the engineering need for this project has been justified. In
addition, the Commission finds this project to be of a similar nature to other projects comprising
EDTI’s Third-party Driven Relocations program, previously approved by the Commission for
capital tracker treatment.
190. With respect to the scope, level and timing of this program for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for each
project comprising this program and finds the forecast scope, level and timing of the project for
2014 and 2015 to be reasonable. The Commission is satisfied that EDTI’s forecasts for the
Third-party Driven Relocations program are based on a discussion with the City of Edmonton
and its engineering consultants and EDTI’s ongoing review of design and scope changes and
related project updates provided by the City.
191. EDTI’s forecast capital additions associated with this program are $25.80 million in 2014
and $26.01 million in 2015. The Commission has reviewed the cost calculations provided in
Section 3.3 of the business cases, and acknowledges that in its business cases, EDTI identified
the steps that it will take to minimize the costs for the project and, accordingly, finds the costs
proposed by EDTI to be reasonable. The Commission has reviewed the information supporting
EDTI’s forecasts for each project comprising this program and finds the total annual cost
forecast to be reasonable.
192. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Third-party Driven Relocations
program are reasonable as proposed for 2014 and 2015. Accordingly, the Commission finds that
this program satisfies the project assessment requirement of Criterion 1 for 2014 and 2015.
7.2.2 IT-related projects
193. This program consists of three IT-related projects: Work Management System (WMS)
Upgrades project, Interval Meter Data Collection and Processing System Replacement (MDCPS)
164
Transcript, Volume 5, page 797, lines 11-14 (Mr. Shymanski).
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project, and Regulated Default Supply (RDS) project. The grouping of IT-related projects under
a single program was directed and approved by the Commission in Decision 2013-435.165
194. The purpose of the WMS upgrades project is to upgrade EDTI’s WMS, referred to as
“IVARA,” to a vendor-supported and Windows 7 compatible version, and to address certain
limitations present in EDTI’s IVARA system. The IVARA system enhancements life cycle
replacement project was expected to be completed in 2014.166
195. The MDCPS project consists of replacing EDTI’s current MDCPS with a new data
collection engine that will comply with pending revisions to Measurement Canada’s
requirements. Measurement Canada has announced that it intends to implement new
specifications for the installation and utilization of electricity meters and their use in establishing
“processed legal units of measurement.”167
196. The RDS project was approved in Decision 2006-054, and consisted of the development
of a meter data management, load settlement, distribution tariff billing and invoicing system to
enable EDTI to comply with the requirements of Section 9(1)(a) of the Regulated Default Supply
Regulation and the Commission’s AUC Rule 004: Alberta Tariff Billing Code Rules. This project
was included in the IT-related capital tracker program as a negative K factor project, pursuant to
the Commission’s direction in Decision 2013-435.168
197. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $2.23 million for 2013.169 EDTI’s actual 2013 capital additions for this
project were $0.41 million, a variance of negative $1.82 million.170 As a result, the IT-related
program was fully funded under the I-X mechanism in 2013. Therefore, consistent with the
Commission’s direction in paragraph 506 of Decision 2013-435, as part of the 2013 capital
tracker true-up, EDTI proposed to refund the entire portion of the K factor adjustment approved
by the Commission in Decision 2013-435 in respect of this project.171
198. EDTI explained that this decrease was primarily due to EDTI’s decision to delay the
MDCPS Replacement project, given the uncertainty surrounding the capital tracker mechanism
in 2013. EDTI further stated that although the project “was necessary and urgently required,
Measurement Canada’s delay in finalizing a timeline for this project enabled EDTI to delay the
project for a short period without jeopardizing EDTI’s ability to comply with Measurement
Canada’s requirements.”172 EDTI expected to complete this project in 2014.
199. In the 2014-2015 capital tracker forecast application, EDTI had originally requested to
continue capital tracker treatment for this project in 2014 and 2015. However, EDTI indicated in
response to AUC-EDTI-1 that, as a result of corrections made to the application, the IT-related
165
Decision 2013-435, paragraph 839. 166
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 152. 167
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 163-164. 168
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 173-174. 169
Decision 2013-435, Table 21 on page 174. 170
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 157-158. 171
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 160. 172
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 161.
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program no longer met the Commission’s first tier materiality threshold in 2014 or 2015. As
such, EDTI is no longer requesting capital tracker treatment for this program.173
Commission findings
200. The Commission accepts EDTI’s withdrawal of this program from capital tracker
treatment in EDTI’s 2013 capital tracker true-up and 2014-2015 capital tracker forecast
applications.
201. As a result of delaying the MDCPS project, the group of IT-related projects was fully
funded under the I-X mechanism in 2013, with the result that EDTI proposed to refund the entire
portion of the K factor adjustment approved by the Commission in Decision 2013-435 for this
program on a forecast basis. The Commission agrees that this proposal is consistent with its
determinations at paragraph 506 of Decision 2013-435. Capital tracker treatment for this
program is discontinued.
202. In order to receive capital tracker treatment for this program in subsequent PBR years,
the company will be required to reapply for capital tracker treatment, demonstrating that all three
capital tracker criteria have been met.
7.2.3 Distribution Contributions to Transmission Assets
203. This program is composed of contributions made by EDTI’s distribution function to its
transmission function for the construction of new transmission facilities, pursuant to the Alberta
Electric System Operator’s (AESO’s) customer contribution policies, as approved from time-to-
time by the Commission.174 This program is made up of four individual projects: Poundmaker
Contributions (East Industrial 2007-2008), Summerside Substation Contribution, Clover Bar
New Point of Delivery (POD) addition contribution, and East Industrial Contribution. The
grouping of distribution contributions to transmission assets projects under a single program was
directed and approved by the Commission in Decision 2013-435.175
204. The Poundmaker Contributions project was completed and is composed of EDTI’s
distribution function’s customer contribution to its transmission function in respect of a new
POD at EDTI’s Poundmaker transmission substation in south Edmonton.
205. As explained in Decision 2013-435, the Poundmaker Contributions project is an example
of EDTI’s “Category 3 projects” that require capital tracker treatment because the application of
the mid-year convention in the calculation of the company’s 2012 going-in year return and
depreciation is one of the factors that causes the shortfall in capital funding under the PBR
formula. As such, even though there were no capital additions forecast for the Poundmaker
Contributions project in 2013, the Commission afforded capital tracker treatment for this project
in 2013 because of the shortfall in capital funding under the PBR formula.176
206. The Poundmaker Contributions project was approved by the Commission in Decision
2012-272, with the customer contribution amount of $16.36 million based on the AESO’s
Customer Contribution Decision (CCD) issued May 26, 2010, and on the contribution policy in
173
Proceeding 3100, Exhibit 93.01, AUC-EDTI-1(a), page 9. 174
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 162-163. 175
Decision 2013-435, paragraph 840. 176
Decision 2013-435, paragraphs 928, 931 and 934.
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the AESO’s 2007 ISO tariff application. On August 14, 2012, the AESO issued a new CCD for
this project and revised the customer contribution amount to $14.17 million, which was
calculated using the contribution policy in the AESO’s 2010 ISO tariff application. EDTI’s 2012
actual Poundmaker customer contribution reflected the $14.17 million amount.
207. On June 6, 2013, EDTI received a third CCD from the AESO that reflected a further
revised customer contribution amount of $11.99 million, which was calculated using EDTI’s
actual costs to complete the new POD and the contribution policy in the AESO’s 2010 ISO tariff
application. As a result of this CCD, EDTI removed in the true-up proceeding $2.17 million from
its rate base, which was related to the Poundmaker customer contribution in 2013 and was
calculated as the difference between the updated contribution amount of $11.99 million and the
earlier estimate of $14.17 million. As a result, the total actual capital addition for this project
(i.e., the customer contribution) was $4.36 million less than the original amount approved in
Decision 2012-272.177 As shown in Table 1 in Section 4, based on actual capital additions, EDTI
calculated the 2013 actual K factor for this program to be $0.34 million, as compared to the
$0.64 million approved in Decision 2013-435.
208. With respect to the remaining three projects comprising this program, Summerside
Substation Contribution, Clover Bar POD Addition Contribution, and East Industrial
Contribution, EDTI explained that these projects were put into service and included in its
distribution function rate base prior to the onset of the PBR regime.178 As such, there were no
forecast capital additions associated with either of these projects in 2013. Therefore, EDTI did
not provide business cases or engineering studies for the distribution contributions to
transmission assets projects.
209. EDTI further explained that these projects were included in EDTI’s 2013 capital tracker
application as “negative K factor” trackers. In Decision 2013-435, the Commission directed that
these historical distribution to transmission contribution projects be grouped with the
Poundmaker Contributions project.179 Accordingly, EDTI included them in the 2013 capital
tracker true-up application for purposes of calculating the K factor true-up amount for the
contribution group of projects.
210. EDTI did not apply for capital tracker treatment for this program in 2014 or 2015.
Commission findings
211. In Decision 2013-435, the Commission determined that the distribution contributions to
transmission assets program was required to maintain service reliability and safety at adequate
levels in 2013. Further, the Commission determined that the scope, level, timing and forecast
costs for this program were reasonable as proposed for 2013. Accordingly, the Commission
found that this program satisfied the project assessment requirement of Criterion 1.180
212. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
177
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 165-172. 178
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 175, 181 and187. 179
Decision 2013-435, paragraph 840. 180
Decision 2013-435, paragraphs 934-935.
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adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the distribution contributions
to transmission assets program was not required in 2013.
213. Regarding the scope, level and timing of this program carried out in 2013, the
Commission observes that the Poundmaker contributions project is an example of EDTI’s
Category 3 projects. As explained in Decision 2013-435, capital additions were forecast to be $0
in 2013 because the capital additions requiring capital tracker treatment were made in 2012.181
214. EDTI explained that, based on the AESO CCD dated June 6, 2013, the amount of EDTI’s
contribution for this project was reassessed at $11.99 million, based on EDTI’s actual costs to
complete the new POD and the contribution policy in the AESO’s 2010 ISO tariff application.
As a result of this CCD, EDTI removed $2.17 million from its rate base related to the
Poundmaker Customer Contribution in 2013 and calculated as the difference between the
updated contribution amount of $11.99 million and the earlier estimate of $14.17 million from
the AESO’s CCD dated August 14, 2012. The effect of reducing the required Poundmaker
Contribution and reducing rate base amounts to a negative $2.17 million capital addition
adjustment.182 Because this variance is driven by the AESO CCD, the Commission finds the
actual capital additions of $11.99 million for this project, representing the contribution of EDTI’s
distribution function to its transmission, to be prudent.
215. The remaining three projects comprising this program, Summerside Substation
Contribution, Clover Bar POD Addition Contribution, and East Industrial Contribution, were put
into service and included in EDTI’s distribution function rate base prior to 2013.183 As such, there
were no forecast capital additions associated with any of these projects in 2013. There were no
changes to the contribution amounts associated with these projects. Therefore, there is no need to
re-assess these previously approved contribution amounts, included in EDTI’s going-in rate base,
for prudency.
216. As shown in Table 1 in Section 4, based on actual capital additions, EDTI calculated the
2013 actual K factor for this program to be $0.34 million, as compared to the $0.64 million
approved in Decision 2013-435. EDTI did not apply for capital tracker treatment for the
distribution contributions to transmission assets program in 2014 or 2015.
7.2.4 Life Cycle Replacement and Extension of Underground Distribution Cable
217. This ongoing life cycle replacement project consists of refurbishing and replacing aged
underground cables to maintain reliability.184 EDTI noted that this project was approved as a
capital tracker in Decision 2013-435.185 EDTI provided business cases and engineering studies
for the Life Cycle Replacement and Extension of Underground Distribution Cable project in
Appendix A-12 of the 2013 capital tracker true-up application and in Appendix A-3 of the
2014-2015 capital tracker forecast application.
181
Decision 2013-435, paragraph 931. 182
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 170. 183
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 175, 181 and187. 184
Proceeding 3100, Exhibit 20, Appendix A-3, paragraph 3. 185
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 178
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218. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner.186 Given these statutory responsibilities, EDTI is obligated to repair or
replace failed or damaged underground distribution cable in a timely manner to maintain the
safety and reliability of its system. EDTI further noted that cable failures are a leading cause of
outages on EDTI’s distribution system and have accounted for an average of 18 per cent of
EDTI’s customer hours of interruption from 2007-2013.187
219. EDTI applied in its 2013 capital tracker forecast application and again in the 2014-2015
capital tracker forecast application to replace, on average, approximately 16 km of cable and
refurbish an additional 25 km of cable each year. In the 2006 study appended to the project,
KEMA recommended that EDTI annually replace 25 km of 350 MCM or larger cable and inject
16 km of 1/0 or smaller cable.188 EDTI reversed the ratio to reduce the financial impact. In
response to Commission counsel questioning, Ms. Hull explained that EDTI originally replaced
15 to 17 km per year and has continued to hold at that amount because it is not seeing any
degradation in reliability, even though the KEMA report identifies the larger cable as the bigger
concern. When EDTI does see this degradation, it will start to replace more as necessary.
Ms. Hull further explained that the smaller cable which EDTI is refurbishing is the pre-1987
vintage and that, at this point, EDTI has injected most of those cables. As a result, EDTI will
start to reduce the size of the refurbishment program as the replacement program ramps up.189
220. In Decision 2013-435, the Commission approved forecast capital additions for this
project in 2013 in the amount of $10.20 million. EDTI’s actual capital additions for this project
were $3.21 million, a variance of negative $6.99 million.190 This variance was composed of two
components. In the 2013 capital tracker true-up application, EDTI explained that time domain
reflectometry (TDR) testing results showed that it would not be economic for it to inject cables
in the areas that had been identified for 2013. As a result, it decreased its capital expenditure by
$0.62 million when it only completed 0.6 km of cable injection compared to the 25 km that were
originally planned.191 The second component of the variance was a $6.37 million decrease in
capital expenditures due to a decision to defer 12.27 km of planned cable replacement work
because of uncertainty relating to the capital tracker mechanism.192 In 2013, EDTI completed the
engineering design for the replacement of 17 km and procured the associated equipment required
for the project.193 However, as a result of a decision to defer some cable replacement pending the
release of the capital tracker decision, EDTI was only able to complete 5 km of replacement.194
221. Regarding the prudence of its actual 2013 capital additions, EDTI explained its primary
focus is to replace those cable segments most prone to failure, as well as those segments that
impact the greatest number of customers when failure occurs, thereby reducing the risk of
deterioration of overall distribution system reliability.195 EDTI confirmed that “nothing occurred
186
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, Paragraph 183. 187
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 182. 188
Proceeding 3100, Exhibit 20, Appendix A-3, paragraph 18. 189
Transcript, Volume 2, page 343, line 23 to page 346 line 16 (Ms. Hull). 190
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 361,Ttable 3.1.14-1. 191
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 383. 192
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 383. 193
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 363. 194
Proceeding 3100, Exhibit 20, Appendix A-3, paragraph 5. 195
Proceeding 3216, Exhibit 27, Appendix A-12, paragraph 15.
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between the date of EDTI’s 2013 Tracker Application and the work completed in 2013 that
obviated the need for this project, or that would have materially impacted the conclusions
reached in EDTI’s analysis of alternatives.”196
222. Further, EDTI explained that expenditures that extend a service life are capitalized and
expenditures that are intended to preserve a service life are expensed to O&M. EDTI stated that
“the injection of underground distribution cables is intended to extend the service life of the
cable beyond its original life by approximately 20 years and, therefore, the cable injection costs
are appropriately capitalized.”197
223. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $14.05 million in 2014 and $14.50 million in 2015.198 As a
consequence of the delay in 2013, EDTI plans to replace 22 km per year in 2014 and 2015, for a
total of 49 km replaced over the three-year period, in order to return to an average of 16 km of
cable replacement per year for the period 2013-2015.199
224. In addition to this replacement, EDTI will refurbish approximately 25 km of cable per
year.200 EDTI stated that the majority of cables targeted for refurbishment and replacement was
installed between 1970 and 1977 and these cables are at, or very near, the end of their 40 year
design life.201 EDTI explained that refurbishing a cable involves injecting fluid into the cable to
rejuvenate the insulation and that this injection typically extends the service life by 20 years or
more.202
225. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because the need for
refurbishment or replacement arises when the condition of a cable deteriorates to the point where
there is a significant risk to the reliability of EDTI’s distribution system.203
Commission findings
226. In Decision 2013-435, the Commission determined that the Life Cycle Replacement and
Extension of Underground Distribution Cable project was required to maintain service reliability
and safety at adequate levels in 2013. Further, the Commission determined that the scope, level,
timing and forecast costs for this project were reasonable as proposed for 2013. Accordingly, the
Commission found that this project satisfied the project assessment requirement of Criterion 1.204
227. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. During the hearing,
Mr. Shymanski expressed his view that this project should be denied capital tracker treatment
196
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 360. 197
Proceeding 3216, Exhibit 54.01, CCA-EDTI-17(h). 198
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 180. 199
Proceeding 3100, Exhibit 20, Appendix A-3, paragraphs 6. 200
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 181. 201
Proceeding 3100, Exhibit 20, Appendix A-3, paragraph 8. 202
Proceeding 3100, Exhibit 20, Appendix A-3, paragraphs 10. 203
Proceeding 3100, Exhibit 80, application, paragraph 189. 204
Decision 2013-435, paragraphs 871-873.
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based on his statement that “there's been no demonstration that there's a deterioration in
service.”205 However, as discussed in Section 6, after EDTI clarified that it will complete all the
2013 deferred work by the end of 2014, with some 2014 work being displaced into 2015,206 Mr.
Shymanski indicated that his recommendations for this project “would be rendered moot.”207
228. In Section 6, the Commission determined it will not disqualify from capital tracker
treatment the five 2013 capital tracker projects delayed, in whole or in part, because of the
“substantial capital funding shortfall under the I-X mechanism and the uncertainty respecting the
capital tracker mechanism.” The Commission finds no evidence on the record of Proceeding
3216 to indicate that the Life Cycle Replacement and Extension of Underground Distribution
Cable project was not required in 2013.
229. EDTI’s 2013 actual capital additions of $3.21 million for the life cycle replacement and
extension of underground distribution cable project were $6.99 million lower than the
$10.20 million forecast approved in Decision 2013-435208 primarily because of EDTI’s decision
to delay planned cable replacement work because of uncertainty relating to the capital tracker
mechanism.209 The Commission stated in Section 6, that with respect to the portion of the five
projects completed in 2013, the Commission will consider the prudence of the actual 2013
capital additions in the 2013 capital tracker true-up application. The Commission has reviewed
the costs of the actual capital additions for this capital tracker project in light of the evidence
supporting these costs, the associated procurement and construction practices and the evidence
explaining the differences between approved forecast and actual costs, and finds the actual costs
to be prudent.
230. EDTI requested to continue capital tracker treatment for this project in 2014 and 2015. In
Section 6, the Commission indicated it will consider, for capital tracker treatment in 2014, the
portions of the five projects approved for capital tracker treatment in 2013 deferred from 2013
into 2014.The Commission will also consider the portions of the 2014 work deferred to 2015,
due to the “cascading effect” described by EDTI.210
231. As noted in Section 3, where a forecast program or project is part of a multi-year ongoing
program or project, or if the program or project is of an annual recurring nature, that has
previously been approved for capital tracker treatment, in the absence of evidence that the on-
going or recurring project or program is no longer required, the Commission will not undertake a
reassessment of need under Criterion 1. The Commission finds no evidence on the record of
Proceeding 3100 to indicate that the life cycle replacement and extension of underground
distribution cable project is not required to continue in 2014 or 2015.
232. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $14.05 million in
205
Transcript, Volume 5, page 796, lines 17-23 (Mr. Shymanski). 206
Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(d). 207
Transcript, Volume 5, page 750, lines 8-11 (Mr. Shymanski). 208
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 361,T table 3.1.14-1. 209
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 383. 210
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford).
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2014 and $14.50 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the evidence.
233. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Life Cycle Replacement and
Extension of Underground Distribution Cable project are reasonable as proposed for 2014 and
2015. Accordingly, the Commission finds that this project satisfies the project assessment
requirement of Criterion 1.
7.2.5 New 15-kV and 25-kV Circuit Additions
234. This ongoing project consists of constructing new distribution circuits required to
maintain the reliability of EDTI’s system and to ensure capacity to service customer growth in
EDTI’s service area. EDTI provided business cases and engineering studies for the New 15-kV
and 25-kV Circuit Additions project in Appendix A-2 of the 2013 capital tracker true-up
application and in Appendix A-4 of the 2014-2015 capital tracker application.
235. EDTI explained that this project was needed as the load grows in a region over time and
the existing circuits exceed their design loads. EDTI confirmed that new circuits are only
installed when it is no longer possible or practical to transfer loads among existing circuits within
a local area to keep circuit loads within their design limits.211 In evaluating the need for the new
circuits, EDTI follows the process outlined in the AESO Distribution Point of Delivery
Interconnection Process Guideline – Distribution Circuit Breaker Addition, Revision 0 (March
22, 2005).212
236. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI maintains that this project is
required to provide service to customers at adequate levels. Further, EDTI is obligated under the
terms of its franchise agreement with the City of Edmonton to provide service to sites within the
City of Edmonton.213 As such, EDTI is obligated to construct new distribution circuits, required
to maintain the reliability of its system as necessary to provide safe and reliable service to each
site in its service area.
237. In 2013, this project involved construction of three distribution circuits: 23C, 13SU, and
22 SU. Circuits 23C and 13SU were expected to be installed in 2013 and 2014, and circuit 22SU
had been expected to be completed in 2012. However, it was delayed and completed in 2013.214
According to EDTI, the 2013 forecast capital additions for the work included in the New 15-kV
and 25-kV Circuit Additions Project were based on management’s estimate of engineering,
materials and construction costs to complete each project, and the scope of work, having regard
for EDTI’s historical cost information for similar projects completed in previous years.215
211
Proceeding 3216, Exhibit 11, Appendix A-2, paragraphs 2-3. 212
Proceeding 3216, Exhibit 11, Appendix A-2, paragraphs 2-3. 213
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 197. 214
Proceeding 3216, Exhibit 11, Appendix A-2, paragraph 1, and Exhibit 1, 2013 true-up application,
paragraph 215. 215
Proceeding 3216, Exhibit 11, appendix A-2, paragraph 36.
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238. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $4.61 million. EDTI’s actual capital additions for this project were
$1.55 million, a variance of negative $3.06 million. In the 2013 capital tracker true-up
application, EDTI explained that the $3.06 million decrease in capital additions from 2013
approved to 2013 actual amounts, was primarily due to the delay in the commencement of the
13SU circuit, which resulted in a decrease of capital additions in the amount of $2.99 million.
EDTI further explained that in “2013, EDTI expected to install two new cubicles, replace an
existing cubicle and direct bury 6.3 km of 500 MCM aluminum XLPE cable. However, EDTI
was only able to install one new cubicle and direct bury approximately 1.0 km of 500 MCM
aluminum XLPE cable. EDTI intends to complete this project in 2014.”216
239. In an IR response to the Commission, EDTI explained that the delay in constructing the
13SU circuit was the result of “uncertainty surrounding the Capital Tracker mechanism in
2013.”217 Furthermore, EDTI indicated that the delay did not impact the company’s ability to
provide and maintain safe and reliable service.218 In response to an undertaking given by EDTI to
the UCA, regarding the status of the completion of the 2013 deferred work in 2014 and beyond,
EDTI explained that all civil work and the majority of other work on the project associated with
13SU circuit has been completed. EDTI noted that the project will be completed and placed into
service at the end of September, 2014.219
240. A further $0.42 million decrease related to the 23C circuit, which was expected to be
completed in 2013. This turned out to be infeasible when one cubicle could not be installed
because there were no cubicles of the correct configuration available in stock. EDTI noted that
the majority of the work associated with this circuit was completed in 2013, and EDTI expected
to complete the work in 2014. These decreases were partially offset by a $0.35 million increase
due to the completion of the 22SU circuit in 2013 instead of 2012.220
241. Regarding the prudence of its actual 2013 capital additions, EDTI confirmed that the
work performed in 2013, in respect of this project, related only to the construction of the three
distribution circuits, 23C, 13SU, and 22 SU. EDTI confirmed that “nothing occurred between the
date of EDTI’s 2013 Tracker Application and the work completed in 2013 that obviated the need
for this project, or that would have materially impacted the conclusions reached in EDTI’s
analysis of alternatives.”221
242. Specifically, EDTI explained that in 2013, the materials cost for the project was
37 per cent of the total capital additions. EDTI further explained that the conductors, cables,
poles, transformers, and switching cubicles, were purchased in a cost effective manner including
requests for proposals (RFP) and selecting the lowest cost providers that could meet EDTI’s
specifications. Furthermore, EDTI uses industry standards when selecting the materials required
for the new circuit additions.222 Construction costs accounted for 60 per cent of the total capital
additions for this project in 2013 and 65 per cent of the construction work was completed using
EDTI’s internal resources. The external contractors used to complete the remainder of the work
216
Proceeding 3100, Exhibit 21, appendix A-4, paragraph 83. 217
Proceeding 3100, Exhibit 93.01, AUC-EDTI-11(c). 218
Proceeding 3100, Exhibit 93.01, AUC-EDTI-11(d). 219
Proceeding 3216, Exhibit 118. 220
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 214-215. 221
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 193. 222
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 207-209.
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were obtained primarily using competitive bidding processes.223 In addition, EDTI, whenever
possible, coordinated the 2013 circuit additions with other projects and used engineering designs
to achieve compliance with standards at a minimum cost.224 In response to AUC-EDTI-7(a),
EDTI confirmed that its construction standards used for the engineering designs completed in
2013 were consistent with standard industry practices.225
243. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $4.46 million in 2014 and $8.43 million in 2015. Consistent
with past applications, EDTI based its 2014 and 2015 forecast capital expenditures on
management’s estimate of engineering, materials, construction costs to complete each project,
and the scope of work, having regard for EDTI’s historical cost information for similar projects
completed in previous years.226
244. In 2014, EDTI’s capital additions are composed of completing the work on the 13SU
circuit and the 23C circuit, which both began in 2013. In 2015, EDTI plans to construct the
23SU, 33PM, R19 and V25 circuits. EDTI explained that all the circuits are required to
accommodate load growth on its system and ensure that current circuits are not operating above
their design loads.227
Table 6. New 15-kV and 25-kV Circuit Additions forecast capital expenditures 2014-2015
Circuit 2014 forecast ($ million)
2015 forecast ($ million)
Circuit 13SU 4.23 -
Circuit 23C 0.23 -
Circuit 23SU - 0.51
Circuit 33PM - 5.82
Circuits R19 and V25 - 2.10
Total 4.46 8.43
245. In response to the Commission’s IR AUC-EDTI-11(g),228 and in subsequent undertakings
given by EDTI to the Commission, regarding the 23SU circuit, EDTI provided tables with the
actual historical peak load to date, as well as forecast annual peak loads in each of 2014 to 2017,
with and without installing the proposed 23SU circuit. Based on these tables, EDTI concluded
that the Summerside circuits would be forced to operate beyond their design loads if the
construction of circuit 23SU was delayed.229
246. EDTI provided alternatives for the designs of each circuit addition; however, EDTI
maintained that no alternatives are available for adding new circuits to the system. EDTI also
223
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 210-212. 224
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 213. 225
Proceeding 3216, Exhibit 53.01, AUC-EDTI-7(a). 226
Proceeding 3100, Exhibit 21, Appendix A-4, paragraph 42. 227
Proceeding 3100, Exhibit 21, appendix A-4, paragraphs 23-36. 228
Proceeding 3100, Exhibit 93.01, AUC-EDTI-11(g). 229
Proceeding 3100, Exhibit 124 and Exhibit 135, EDTI argument, paragraph 69.
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maintained that a prudent capital maintenance program could not have been undertaken in the
past for this project because this project constructs new distribution circuits.230
Commission findings
247. In Decision 2013-435, the Commission determined that the New 15-kV and 25-kV
Circuit Additions project was required to maintain service reliability and safety at adequate
levels in 2013. Further, the Commission determined that the scope, level, timing and forecast
costs for this project were reasonable as proposed for 2013. Accordingly, the Commission found
that this project satisfied the project assessment requirement of Criterion 1.231
248. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. In Section 6, the
Commission determined it will not disqualify from capital tracker treatment the five 2013 capital
tracker projects delayed, in whole or in part, because of the “substantial capital funding shortfall
under the I-X mechanism and the uncertainty respecting the capital tracker mechanism.” The
Commission finds no evidence on the record of Proceeding 3216 to indicate that the New 15-kV
and 25-kV Circuit Additions project was not required in 2013.
249. EDTI’s 2013 actual capital additions of $1.55 million for the New 15-kV and 25-kV
Circuit Additions project were $3.06 million lower than the $4.61 million forecast approved in
Decision 2013-435232 primarily because of EDTI’s decision to delay planned cable replacement
work because of uncertainty relating to the capital tracker mechanism.233 The Commission stated
in Section 6, with respect to the portion of the five projects completed in 2013, it will consider
the prudence of the actual 2013 capital additions in the 2013 capital tracker true-up application.
The Commission has reviewed the costs of the actual capital additions for this capital tracker
project in light of the evidence supporting these costs, the associated procurement and
construction practices and the evidence explaining the differences between approved forecast
and actual costs, and finds the actual costs to be prudent.
250. EDTI requested to continue capital tracker treatment for this project in 2014 and 2015. In
Section 6, the Commission indicated it will consider, for capital tracker treatment in 2014, the
portions of the five projects approved for capital tracker treatment in 2013 deferred from 2013
into 2014. The Commission will also consider the portions of the 2014 work deferred to 2015,
due to the “cascading effect” described by EDTI.234
251. As noted in Section 3, where a forecast program or project is part of a multi-year ongoing
program or project, or if the program or project is of an annual recurring nature, that has
previously been approved for capital tracker treatment, in the absence of evidence that the on-
going or recurring project or program is no longer required, the Commission will not undertake a
reassessment of need under Criterion 1. The Commission finds no evidence on the record of
Proceeding 3100 to indicate that the New 15-kV and 25-kV Circuit Additions project is not
230
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 205. 231
Decision 2013-435, paragraphs 877-879. 232
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 361, Table 3.1.14-1. 233
Proceeding 3100, Exhibit 93.01, AUC-EDTI-11(c). 234
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford).
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required to continue in 2014 or 2015. In this regard, the Commission notes that, during the
hearing, Mr. Shymanski supported capital tracker treatment for this project.235
252. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $4.46 million in
2014 and $8.43 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the methods
outlined in the business case.236
253. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the New 15-kV and 25-kV Circuit
Additions project are reasonable as proposed for 2014 and 2015. Accordingly, the Commission
finds that this project satisfies the project assessment requirement of Criterion 1.
7.2.6 New Underground Cable and Aerial Line Reconfigurations and Extensions to Meet
Customer Growth
254. This ongoing project consists of expansions and modifications to EDTI’s distribution
system to meet load growth and maintain reliability in EDTI’s service area.237 EDTI provided
business cases and engineering studies for the New Underground Cable and Aerial Line
Reconfigurations and Extensions to Meet Customer Growth project in Appendix A-8 of the 2013
capital tracker true-up application and in Appendix A-10 of the 2014-2015 capital tracker
application.
255. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI maintains that this project is
required to provide service to customers at adequate levels.238
256. EDTI explained that for forecast purposes, it identified the projects based on the best
available information at the time the forecast was prepared, including such information as the
City of Edmonton’s growth projections and new residential and industrial developments. This
project consists of both known and recurring projects. In some cases, EDTI was able to identify
specific reconfigurations and extensions that are required on its system at the time it prepared its
forecast. However, there are types of projects that consistently occur every year and, therefore,
EDTI was unable to identify their location at the time it prepared its forecast.239 The forecast
project costs were based on EDTI’s estimate of engineering, material and construction costs,
having regard to EDTI’s historical cost experience for similar projects completed in previous
years.240
235
Transcript, Volume 5, pages 796-797 (Mr. Shymanski). 236
Proceeding 3100, Exhibit 21, Appendix A-4, paragraph 42. 237
Proceeding 3216, Exhibit 23, appendix A-8, paragraph 1. 238
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 285. 239
Proceeding 3216, Exhibit 23, appendix A-8, paragraphs 2-3. 240
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 284- 297, and Exhibit 23, appendix A-8,
paragraph 159.
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257. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $8.08 million. EDTI’s actual capital additions for this project were
$6.70 million, a negative variance of $1.38 million. In the 2013 capital tracker true-up
application, EDTI explained that the $1.38 million decrease in capital additions in 2013 for this
project was primarily made up of a $1.31 million decrease reflecting deferred work of five sub-
projects that were carried over into 2014, due to uncertainty surrounding the capital tracker
mechanism in 2013; a $0.87 million decrease was associated with the Edmonton Centre and
Oxford Tower project, due to timing with the new Oxford Tower owner, who requested a
separate primary service from EDTI; a $0.18 million decrease was due to the customer
requesting EDTI to cancel the R17 & R25 primary service to the Empire Building project; and a
$0.10 million decrease related to the 452 Circuit Conversion project, as EDTI determined that it
could use single phase instead of two phase wire on portions of the 452 circuit.
258. The decreases were partially offset by the following increases: a $0.06 million increase
was primarily due to the more complex than expected directional drill across 87 Avenue and
changes to the original design alignment directed by Alberta Infrastructure, related to the J61 to
M35 Feeder Tie project; and a $1.05 million increase was due to completion spending and
additions to rate base through construction work in progress (CWIP) associated with the V15
Circuit & 290 S/S Feeder Changes project, CWIP associated with the L23 & L43 Circuit
Reconfigurations project, and CWIP associated with the V44 Backup to NAIT project.241
259. In an IR response to the Commission, EDTI indicated that in deferring the five projects in
the face of uncertainty surrounding capital tracker funding, there was “a risk of adverse effects
on EDTI’s ability to maintain safe and reliable service.”242 EDTI pointed to the examples of the
25L feeder extension project, where there was the possibility that EDTI would not be able to
provide service to its customers in two areas of Edmonton without overloading circuits, and the
N13 Radial Tie project, where EDTI experienced a failure that resulted in a 13-hour outage.
EDTI explained that 12 hours of this outage could have been prevented had EDTI completed the
project as originally planned.243
260. Regarding the prudence of its actual 2013 capital additions, EDTI provided the following
Table 7 to show the work performed in 2013 and the associated capital additions.
241
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 298-299. 242
Proceeding 3100, Exhibit 93.01, AUC-EDTI-12 (b). 243
Proceeding 3100, Exhibit 93.01, AUC-EDTI-12 (b).
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Table 7. 2013 actuals for new underground cable and aerial line reconfigurations and extensions to meet customer growth
Description 2013 capital additions
Known projects J62 Transfer to J84 0.29 J61 to M35 Feeder Tie 0.56
V15 Circuit & 290 S/S Feeder Changes 0.22
L23 & L43 Circuit Reconfigurations 0.55
V44 Backup to NAIT 0.28
Primary Service Reconfiguration for Edmonton Centre & Oxford Tower 0.58
Reoccurring projects
Removal of Redundant Aerial Lines – Poles 0.04
Removal of Redundant Aerial Lines – Lines 0.05
Aerial Line Reconfigurations – Poles 0.31
Aerial Line Reconfigurations – Lines 0.86
Aerial Line Reconfigurations- Communications– Poles 0.65
Aerial Line Reconfigurations- Communications– Lines 0.85
5kV Upgrades 0.04 Underground (URD) Cable Reconfigurations 1.42
Total 6.70
261. Specifically, EDTI explained that in 2013, the engineering components of the project
were completed using internal resources alongside seven external consultants whose rates were
compared to those of a 2012 RFP for engineering design work. EDTI stated that all engineering
designs completed were in accordance with their standards. The cables and conductors required
for this project were obtained through a 2011 RFP where EDTI selected the lowest bids that
could meet their requirements. For wood poles, EDTI uses a single supplier on a fixed contract,
which EDTI submits reduces the risk of price increases. Furthermore, EDTI primarily used
internal resources to complete the aerial construction work and 5-kV to 15-kV upgrades.
However, external contractors were required to supplement EDTI’s resources in order to
complete the underground cable reconfigurations. The contractors were obtained through a
competitive process. In addition, EDTI, whenever possible, coordinated the project work with
other projects and used engineering designs to achieve compliance with standards at a minimum
cost.244
262. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $9.54 million in 2014 and $8.33 million in 2015.
263. EDTI provided the capital additions forecast methodology for each of the 19 specific
projects proposed in 2014 and 2015.245 EDTI maintained that in 2014 and 2015 this project
consists of “known” projects as well as “recurring” projects, which it is unable to identify at the
time of forecast.246 The recurring projects are forecast based on historical and forecast load
growth trends and locations, anticipated changes in code requirements and EDTI’s experience
and judgement. The recurring project costs for 2014 and 2015 were forecast based on estimates
244
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 285- 297. 245
Proceeding 3100, Exhibit 21, Appendix A-4. 246
Proceeding 3100, Exhibit 21, Appendix A-4, paragraph 3.
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of the engineering, materials, and construction costs required, as well as the historical costs in
previous years.247
264. EDTI maintained that a prudent capital maintenance program could not have been
undertaken in the past for this project because this project undertakes reconfigurations and
extensions due to growth.248
Commission findings
265. In Decision 2013-435, the Commission determined that New Underground Cable and
Aerial Line Reconfigurations and Extensions to Meet Customer Growth project was required to
maintain service reliability and safety at adequate levels in 2013. Further, the Commission
determined that the scope, level, timing and forecast costs for this project were reasonable as
proposed for 2013. Accordingly, the Commission found that this project satisfied the project
assessment requirement of Criterion 1.249
266. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. In Section 6, the
Commission determined it will not disqualify from capital tracker treatment the five 2013 capital
tracker projects delayed, in whole or in part, because of the “substantial capital funding shortfall
under the I-X mechanism and the uncertainty respecting the capital tracker mechanism.” The
Commission finds no evidence on the record of Proceeding 3216 to indicate that the New
Underground Cable and Aerial Line Reconfigurations and Extensions to Meet Customer Growth
project was not required in 2013.
267. EDTI’s 2013 actual capital additions of $6.70 million for the New Underground Cable
and Aerial Line Reconfigurations and Extensions to Meet Customer Growth project were $1.38
million lower than the $8.08 million forecast approved in Decision 2013-435250 in part because of
EDTI’s decision to delay planned work because of uncertainty relating to the capital tracker
mechanism.251 The Commission stated in Section 6, that with respect to the portion of the five
projects completed in 2013, the Commission will consider the prudence of the actual 2013
capital additions in the 2013 capital tracker true-up application. The Commission has reviewed
the costs of the actual capital additions for this capital tracker project in light of the evidence
supporting these costs, the associated procurement and construction practices and the evidence
explaining the differences between approved forecast and actual costs, and finds the actual costs
to be prudent.
268. EDTI requested to continue capital tracker treatment for this project in 2014 and 2015. In
Section 6, the Commission indicated it will consider, for capital tracker treatment in 2014, the
portions of the five projects approved for capital tracker treatment in 2013 deferred from 2013
247
Proceeding 3100, Exhibit 21, appendix A-4, paragraph 228. 248
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 294. 249
Decision 2013-435, paragraphs 883-886. 250
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 361, Table 3.1.14-1 251
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 298.
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into 2014.The Commission will also consider the portions of the 2014 work deferred to 2015,
due to the “cascading effect” described by EDTI.252
269. As noted in Section 3, where a forecast program or project is part of a multi-year ongoing
program or project, or if the program or project is of an annual recurring nature, that has
previously been approved for capital tracker treatment, in the absence of evidence that the on-
going or recurring project or program is no longer required, the Commission will not undertake a
reassessment of need under Criterion 1. The Commission finds no evidence on the record of
Proceeding 3100 to indicate that the New Underground Cable and Aerial Line Reconfigurations
and Extensions to Meet Customer Growth project is not required to continue in 2014 or 2015. In
this regard, the Commission notes that during the hearing, Mr. Shymanski supported capital
tracker treatment for this project.253
270. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $9.54 million in
2014 and $8.33 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the methods
outlined in the business case.254
271. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the New Underground Cable and
Aerial Line Reconfigurations and Extensions to Meet Customer Growth project are reasonable as
proposed for 2014 and 2015. Accordingly, the Commission finds that this project satisfies the
project assessment requirement of Criterion 1.
7.2.7 Distribution Pole and Aerial Line Life Cycle Replacements
272. This ongoing project consists of the replacement of distribution poles, conductors and
associated assets and the conversion of 5-kV distribution circuits to 15 kV when a significant
number of distribution poles on a particular 5-kV circuit are being replaced.255 EDTI noted that
its staff use their professional judgment and experience to select poles and conductors for
replacement when they no longer meet safety, structural and/or clearance requirements.256 EDTI
noted that this project was approved as a capital tracker in Decision 2013-435.257 EDTI provided
business cases and engineering studies for the Distribution Pole and Aerial Line Life Cycle
Replacements project in Appendix A-4 of the 2013 capital tracker true-up application and in
Appendix A-6 of the 2014-2015 capital tracker forecast application.
273. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to complete pole
252
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford). 253
Transcript, Volume 5, page 797, lines 2-4 (Mr. Shymanski). 254
Proceeding 3100, Exhibit 21, Appendix A-4, paragraph 42. 255
Proceeding 3100, Exhibit 23, Appendix A-6, paragraph 3. 256
Proceeding 3100, Exhibit 23, Appendix A-6, paragraphs 4-5. 257
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 226.
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and aerial line life cycle replacements in a timely manner to maintain the safety and reliability of
its system.258
274. EDTI explained that poles, conductors and associated equipment are replaced when they
no longer meet safety, structural and/or clearance requirements.259 This program meets that need
by life cycle replacement and when a significant number of distribution poles on a particular 5-
kV circuit are being replaced, EDTI converts the distribution circuit to 15 kV.260 EDTI further
explained that in order to replace a pole, all existing attachments must be removed; therefore,
EDTI’s normal practice is to replace these attachments with new attachments.261 As such, once a
decision is made to replace a pole, the other assets on the pole are replaced as well.
275. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $5.60 million. EDTI’s actual capital additions for this project were
$1.44 million, a variance of negative $4.16 million.262 In the 2013 capital tracker true-up
application, EDTI explained that this variance was caused by uncertainty respecting the capital
tracker mechanism that resulted in projects being carried forward into 2014 and 2015 for
completion.263
276. According to Mr. Shymanski, $5.60 million of capital expenditures which were delayed
during 2013 are now proposed to be carried over as $1.44 million in 2014 and $2.35 million in
2015.264 He explained that delaying putting in facilities that were required to maintain adequate
levels of service in 2013 until 2015 suggests the project does not satisfy Criterion 1 and suggests
denying the $2.35 million that is proposed to be carried over into 2015.265
277. In response, EDTI explained that it used its inspection programs to identify and replace
the poles that were in a state of imminent failure, while allowing others to be considered for a
short-term delay. The result was 378 poles carried forward from 2013 to 2014 and, in turn, some
poles forecast for replacement in 2014 were delayed to 2015. As such, no poles were delayed by
two years from 2013 to 2015, as suggested by Mr. Shymanski.266
278. In its argument, EDTI noted that “temporarily deferring the work does not indicate that
EDTI has deviated from its typical replacement practices.”267 The work originally planned for
2013-2015 will all be completed by 2015.268
279. Regarding the prudence of its actual 2013 capital additions, EDTI confirmed that the
work performed in 2013 in respect of this project related only to the replacement of damaged or
deteriorated assets that were either causing an outage, posed an immediate safety hazard, or were
likely to cause an outage or pose a significant safety hazard in the near term. EDTI noted that
258
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 230. 259
Proceeding 3100, Exhibit 23, Appendix A-6, paragraph 4. 260
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 224. 261
Proceeding 3100, Exhibit 23, Appendix A-6, paragraph 44. 262
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 237, Table 3.1.6-1 263
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 241. 264
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraph 44. 265
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraph 47. 266
Proceeding 3100, Exhibit 107.01, EDTI rebuttal evidence, page 18. 267
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 90. 268
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 94.
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“the evidence that the work planned under this project must be done is uncontroverted. No issue
has been raised with the scope of that work (i.e., the length of line and number of poles).”269
280. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $4.63 million in 2014 and $5.48 million in 2015.270 The number
of poles forecast for replacement in 2014 and 2015 is based on current and historical inspection
results.271 EDTI noted that it uses an average unit pole cost to forecast its costs, which takes into
consideration the complete cost of pole replacements, transformer replacements and line
hardware replacements.272
281. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because need for replacement
arises when the condition of a pole deteriorates to the point where there is a significant risk to the
reliability of EDTI’s distribution system and public safety. Once the condition of a pole reaches
this point, it is uneconomical to undertake higher levels of regular or capital maintenance or
repair on the pole.273
Commission findings
282. In Decision 2013-435, the Commission determined that the Distribution Pole and Aerial
Line Life Cycle Replacement project was required to maintain service reliability and safety at
adequate levels in 2013. Further, the Commission determined that the scope, level, timing and
forecast costs for this program were reasonable as proposed for 2013. Accordingly, the
Commission found that this program satisfied the project assessment requirement of Criterion
1.274
283. With respect to the true-up of 2013 actual costs, as noted in Section 3, in the absence of
evidence on the record that the project was not required, the Commission will not reconsider the
need for approved capital tracker programs or projects in a true-up application.
284. In Section 6, the Commission determined it will not disqualify from capital tracker
treatment the five 2013 capital tracker projects delayed, in whole or in part, because of the
“substantial capital funding shortfall under the I-X mechanism and the uncertainty respecting the
capital tracker mechanism.” The Commission finds no evidence on the record of Proceeding
3216 to indicate that the Distribution Pole and Aerial Line Life Cycle Replacement project was
not required in 2013.
285. EDTI’s 2013 actual capital additions of $1.44 million for the Distribution Pole and Aerial
Line Life Cycle Replacements project was $4.16 million lower than the $5.60 million forecast
approved in Decision 2013-435275 primarily because of EDTI’s decision to delay planned
replacement work because of uncertainty relating to the capital tracker mechanism.276 The
Commission stated in Section 6, that with respect to the portion of the five projects completed in
269
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 93. 270
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, Paragraph 231. 271
Proceeding 3100, Exhibit 23, Appendix A-6, paragraph 43. 272
Proceeding 3100, Exhibit 23, Appendix A-6, paragraph 46. 273
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, Paragraph 237. 274
Decision 2013-435, paragraphs 890-893. 275
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 361, table 3.1.14-1. 276
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 241.
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2013, the Commission will consider the prudence of the actual 2013 capital additions in the 2013
capital tracker true-up application. The Commission has reviewed the costs of the actual capital
additions for this capital tracker project in light of the evidence supporting these costs, the
associated procurement and construction practices and the evidence explaining the differences
between approved forecast and actual costs, and finds the actual costs to be prudent.
286. EDTI has not requested capital tracker treatment for this project in 2014, because the
project does not meet the first tier of the materiality threshold for 2014. EDTI has requested
capital tracker treatment for 2015. In Section 6, the Commission indicated it will consider, for
capital tracker treatment in 2014, the portions of the five projects approved for capital tracker
treatment in 2013 deferred from 2013 into 2014.The Commission will also consider the portions
of the 2014 work deferred to 2015, due to the “cascading effect” described by EDTI.277
287. As noted in Section 3, where a forecast program or project is part of a multi-year ongoing
program or project, or if the program or project is of an annual recurring nature, that has
previously been approved for capital tracker treatment, in the absence of evidence that the on-
going or recurring project or program is no longer required, the Commission will not undertake a
reassessment of need under Criterion 1. During the hearing, Mr. Shymanski expressed his view
that this project should be denied capital tracker treatment.278 However, as discussed in Section 6,
after EDTI clarified that it will complete all the 2013 deferred work by the end of 2014, with
some 2014 work being displaced into 2015,279 Mr. Shymanski indicated that his
recommendations for this project “would be rendered moot.”280 The Commission finds no further
evidence on the record of Proceeding 3100 to indicate that the Distribution Pole and Aerial Line
Life Cycle Replacement project is not required to continue in 2014 or 2015.
288. With respect to the scope, level and timing of this project for 2015, the Commission has
reviewed the business case and the relevant portions of the record for this project and finds the
forecast scope, level and timing of the project for 2015 to be reasonable. EDTI’s forecast capital
additions associated with this project are $5.48 million in 2015. The Commission has reviewed
the information supporting EDTI’s forecasts and finds the total annual cost forecast to be
reasonable based on current and historical inspection results.
289. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Distribution Pole and Aerial Line
Life Cycle Replacement project are reasonable as proposed for 2015. Accordingly, the
Commission finds that this project satisfies the project assessment requirement of Criterion 1.
7.2.8 Aerial and Underground Distribution Transformers – New Services and Life
Cycle Replacement
290. This ongoing project consists of providing new aerial and underground distribution
transformers for distribution service. EDTI stated the transformer used is determined by the site
load characteristics and only the costs of the transformers are included in this project. The
installation costs associated with the transformer work are included in the specific capital project
277
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford). 278
Transcript, Volume 5, page 797, lines 5-6 (Mr. Shymanski). 279
Proceeding 3100, Exhibit 93.01, AUC-EDTI-6(d). 280
Transcript, Volume 5, page 750, lines 8-11 (Mr. Shymanski).
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for which the work is being done.281 EDTI provided a business case and engineering study for the
Aerial and Underground Distribution Transformers – New Services and Life Cycle Replacement
project in Appendix A-2 of the 2013 capital tracker true-up application, and Appendix A-7 of the
2014-2015 capital tracker application.
291. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner, and to provide and maintain service that is safe, adequate and proper.
Further, EDTI is obligated under the terms of its franchise agreement with the City of Edmonton
to provide service to sites within the City. As such, EDTI is obligated to install aerial and
underground distribution transformers on EDTI’s system as necessary to provide safe and
reliable service to each site in EDTI’s service area at adequate levels.282
292. EDTI noted that every service connection to a site on the distribution system requires a
transformer to step down the voltage of power coming from the system so that the power for a
particular site is correct. EDTI also stated that new transformers are needed to replace failed
transformers currently in the field or for new installations to serve customer growth.283
293. According to EDTI, the forecast of new transformers required in 2013, 2014 and 2015
was based on two factors: the number of transformers that EDTI would require in those years for
life cycle replacement and growth, and the types of transformers that would be required (aerial
versus underground).
294. Consistent with its past approach, EDTI forecast the number of transformers by type
required in 2013, 2014 and 2015 based on the following:
for 2013 the forecast was based on the historical trending of the actual number of
transformers installed over the 2009 to 2011 period, adjusted to reflect EDTI’s 2013
forecast of specific capital projects that will require transformers
for 2014 to 2015, the forecast was based on the historical trending of the actual number
of transformers used over the 2011 to 2013 period, adjusted to reflect EDTI’s 2014 and
2015 forecast of specific capital projects that will require transformers.284
295. To forecast the costs of this project, EDTI first forecast the number of new transformers
to be installed in 2013, 2014 and 2015 and then forecast the costs of the new transformers, based
on historical costs.285
296. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $4.76 million. EDTI’s actual capital additions for this project were
$5.19 million, a variance of $0.43 million. In the 2013 capital tracker true-up application, EDTI
explained that the $0.43 million increase in capital additions in 2013 for this project was
primarily due to a higher than forecast use of new underground transformers that resulted in a
281
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 242 to 245. 282
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 244. 283
Proceeding 3216, Exhibit 20, appendix A-5, paragraph 1. 284
Proceeding 3216, Exhibit 20, appendix A-5, paragraph 15. 285
Proceeding 3216, Exhibit 20, Appendix A-5, paragraphs 13-22, and Proceeding 3100, Exhibit 24,
Appendix A-7, paragraphs 14-21.
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$0.79 million increase, which was partially offset by a $0.39 million decrease reflecting a lower
than forecast unit cost per transformer. EDTI identified that it has installed 538286 transformers in
2013 as part of this project rather than the 506 transformers forecast for that year.287
297. Regarding the prudence of its actual 2013 capital additions, EDTI submitted that, when
possible, used transformers, rather than new ones, were used and inventory costs were minimized
by using standard transformers in limited sizes and types.288 EDTI also explained that its
transformer suppliers are the same ones used in previous years and for three types of
transformers, the cost has decreased as compared to previous years.289
298. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $5.08 million in 2014 and $5.18 million in 2015. The increase
in forecast capital additions from 2014 to 2015 is due to inflation.290 EDTI’s forecast capital
additions for aerial and underground distribution transformers are based on the approach
described above. EDTI forecast that it would install 544 transformers in both 2014 and 2015.291
299. During the hearing, EDTI explained that it would be using the same two transformer
suppliers as it had in the past and stated:
The primary reason that we're limited to suppliers is if you go back to when we did our
last RFP in 2006 and we tested the marketplace, at that time, we had experience with
suppliers around the quality of the product that they were providing. And that experience
manifests itself when the transformer is in service over a period of time. And most
frequently it relates to the quality of the exterior finishing. So products that either rust
prematurely or the specs don't allow readily -- us to readily replace certain parts on them.
And so if you look at the technical specs, yeah, there are differences, but the primary
difference is in the quality of the product that we actually put into service. And based on
our history at that time, we did not want to pursue purchasing from certain suppliers for
that reason.292
300. EDTI maintained that a prudent capital maintenance program could not have been
undertaken in the past for this project. This is because a portion of the project consists of
replacing transformers that have failed, need to be relocated due to City of Edmonton work, or
are in areas where the primary voltage is being converted. Furthermore, the remainder of the
project consists of transformers that are installed to provide service to new customers.293
Commission findings
301. In Decision 2013-435, the Commission determined that for 2013, the Aerial and
Underground Distribution Transformers – New Services and Life Cycle Replacement project
was required to maintain service reliability and safety at adequate levels. Further, the
Commission determined that the scope, level, timing and forecast costs for this project were
286
Proceeding 3216, Exhibit 53.01, AUC-EDTI-09, page 4. 287
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 248-249. 288
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 247. 289
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 247. 290
Proceeding 3100, Exhibit 24, appendix A-7, paragraph 43. 291
Proceeding 3100, Exhibit 24, appendix A-7, Table 3.2-3. 292
Transcript, Volume 3, pages 380-381 (Mr. Middleton). 293
Proceeding 3100, Exhibit 24, appendix A-7, paragraph 7.
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reasonable as proposed for 2013. Accordingly, the Commission found that this project satisfied
the project assessment requirement of Criterion 1.294
302. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the Aerial and Underground
Distribution Transformers – New Services and Life Cycle Replacement project was not required
in 2013.
303. With respect to the scope, level and timing of the Aerial and Underground Distribution
Transformers project carried out in 2013, the Commission has reviewed EDTI’s 2013 actual
capital additions of $5.19 million associated with this project and finds that the scope, level and
timing are generally consistent with the scope, level and timing outlined in the business case for
this capital tracker and approved in Decision 2013-435. The Commission has also reviewed the
costs of the actual capital additions for this capital tracker project in light of the evidence
supporting these costs, the associated procurement and construction practices and the evidence
explaining the differences between approved forecast and actual costs, and finds the actual costs
to be prudent.
304. EDTI requested capital tracker treatment for this project in 2014 and 2015. As noted in
Section 3, where a forecast program or project is part of a multi-year ongoing program or project,
or if the program or project is of an annual recurring nature, that has previously been approved
for capital tracker treatment, in the absence of evidence that the on-going or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1. The Commission finds no evidence on the record of Proceeding 3100 to indicate that
the Aerial and Underground Distribution Transformers project is not required to continue in
2014 or 2015. In this regard, the Commission notes that during the hearing, Mr. Shymanski
supported capital tracker treatment for this project.295
305. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $5.08 million in
2014 and $5.18 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the methods
outlined in the business case.296
306. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Aerial and Underground
Distribution Transformers project are reasonable as proposed for 2014 and 2015. Accordingly,
the Commission finds that this project satisfies the project assessment requirement of Criterion 1.
294
Decision 2013-435, paragraphs 895-897. 295
Transcript, Volume 5, page 797, lines 7-10 (Mr. Shymanski). 296
Proceeding 3100, Exhibit 21, Appendix A-4, paragraph 42.
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7.2.9 Capitalized Underground System Damage
307. This ongoing project consists of the replacement of underground distribution
infrastructure, such as switching cubicles, faulted underground cables, transformers and
manholes, that has been damaged or that has failed or are about to fail. EDTI maintained that this
project is necessary to maintain system reliability. EDTI provided business cases and
engineering studies for the Capitalized Underground System Damage project in Appendix A-6 of
the 2013 capital tracker true-up application and in Appendix A-8 of the 2014-2015 capital
tracker forecast application.
308. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to repair or replace
failed or damaged underground facilities in a timely manner to maintain the safety and reliability
of its system. Failure to replace such facilities can lead to power outages for customers, and can
create safety hazards for both EDTI’s personnel and the general public.
309. EDTI further explained the need for replacement is identified through its underground
inspection program and damage reports from other parties. The primary drivers behind the need
to replace failed or damaged underground distribution facilities, and the resulting capital
expenditures, include such causes as third party damage, weather events, vehicle collisions,
vandalism, wildlife contacts, and deterioration from environmental factors and aging.
310. According to EDTI, the volume of capitalized underground system damage replacements
is related to factors beyond its control and, therefore, varies from year to year. As such,
consistent with past GTAs, EDTI’s 2013 forecast capital expenditures for this project were based
on a normalized three-year average of 2009 to 2011 historical annual costs.
311. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $2.97 million. EDTI’s actual capital additions for this project were
$3.17 million, a variance of $0.20 million. In the 2013 capital tracker true-up application, EDTI
explained that the $0.20 million increase in capital additions from the approved 2013 forecast to
2013 actual amounts reflects the difference between the results of its normalized three-year
historical average forecasting methodology for this project and actual capital additions. In other
words, the underground system damage capital repair and replacement costs required in 2013
proved to be higher than reflected in the normalized three-year historical average.
312. Regarding the prudence of its actual 2013 capital additions, EDTI confirmed that the
work performed as part of this project in 2013 related only to the replacement of damaged or
deteriorated assets that were either causing an outage, posed an immediate safety hazard, or were
likely to cause an outage or pose a significant safety hazard in the near term. EDTI confirmed
that “nothing occurred between the date of EDTI’s 2013 Tracker Application and the work
completed in 2013 that obviated the need for this project, or that would have materially impacted
the conclusions reached in EDTI’s analysis of alternatives.”297
313. Specifically, EDTI identified that in 2013, it replaced or repaired 20 switching cubicles,
69 faulted underground cables, 137 transformers, and 23 manholes as part of this project. This
work represented approximately 88 per cent of the total capital additions related to this project in
297
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 252.
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2013. The remaining work involved replacing numerous vault skirts, hot elbows, pedestals and
powerbases.298 EDTI indicated that the costs of completing the project primarily included
material (25 per cent) and construction (75 per cent) costs. EDTI described the steps it took to
ensure that the work was completed in a cost effective manner.299
314. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $3.64 million in 2014 and $3.72 million in 2015. Consistent
with past applications, EDTI based its 2014 forecast capital expenditures for this project on a
normalized three-year average of 2011 to 2013 historical actual annual costs. EDTI provided
details of its normalized three-year average forecasting methodology for this project in response
to AUC-EDTI-17.300 The $0.08 million increase in capital additions from 2014 forecast to 2015
forecast is due to inflation.301
315. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program as a result of the need for repairs
arising as damage and system failures occur on EDTI’s system. As such, by their nature, capital
additions for this project are not associated with activities that could have been included in a
prudent capital maintenance program in the past.302 Mr. Elford, for EDTI, further explained that
the activities under this project are “all reactive repairs, either due to failures or third-party
damage.”303
Commission findings
316. In Decision 2013-435, the Commission determined that the Capitalized Underground
System Damage project was required to maintain service reliability and safety at adequate levels
in 2013. Further, the Commission determined that the scope, level, timing and forecast costs for
this project were reasonable as proposed for 2013. Accordingly, the Commission found that this
project satisfied the project assessment requirement of Criterion 1.304
317. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the Capitalized Underground
System Damage project was not required in 2013.
318. With respect to the scope, level and timing of the Capitalized Underground System
Damage project carried out in 2013, the Commission has reviewed EDTI’s 2013 actual capital
additions of $3.17 million associated with this project and finds that they are generally consistent
with the scope, level and timing of the work outlined in the business case for this capital tracker
and approved in Decision 2013-435. The Commission has also reviewed the costs of the actual
capital additions for this capital tracker project in light of the evidence supporting these costs, the
298
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 255-256. 299
Proceeding 3216, Exhibit 1, 2013 true-up application , paragraphs 257-258. 300
Proceeding 3100, Exhibit 93.01, AUC-EDTI-17. 301
Proceeding 3100, Exhibit 25, Appendix A-8, paragraph 28. 302
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 265. 303
Transcript, Volume 2, page 333, lines 10-11 (Mr. Elford). 304
Decision 2013-435, paragraphs 906-908.
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associated procurement and construction practices and the evidence explaining the differences
between approved forecast and actual costs, and finds the actual costs to be prudent.
319. EDTI requested capital tracker treatment for this project in 2014 and 2015. As noted in
Section 3, where a project or program is part of an ongoing multi-year program, or if a project or
program is of an annual recurring nature that has been previously approved by the Commission
for capital tracker treatment, in the absence of evidence that the ongoing or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1. The Commission finds no evidence on the record of Proceeding 3100 to indicate that
the Capitalized Underground System Damage project is not required to continue in 2014 or
2015. In this regard, the Commission notes that during the hearing, Mr. Shymanski supported
capital tracker treatment for this project.305
320. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $3.64 million in
2014 and $3.72 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the
normalized three-year average of 2011 to 2013 historical actual annual costs. The Commission
found EDTI’s normalized three-year average forecasting methodology to be reasonable in
Decision 2012-272.306
321. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Capitalized Underground System
Damage project are reasonable as proposed for 2014 and 2015. Accordingly, the Commission
finds that this project satisfies the project assessment requirement of Criterion 1.
7.2.10 Vehicles – Growth and Life Cycle Replacements
322. EDTI explained in its application that this project consists of the purchase of new
distribution vehicles and fleet equipment required for growth, the replacement of existing
distribution vehicles and fleet equipment beyond their service lives.307 EDTI noted that this
project was approved as a capital tracker in Decision 2013-435.308 EDTI provided business cases
and engineering studies for the Vehicles – Growth and Life Cycle Replacements project in
Appendix A-7 of the 2013 capital tracker true-up application and in Appendix A-9 of the 2014-
2015 capital tracker forecast application.
323. EDTI explained that it relies on its distribution fleet of vehicles and related equipment to
build, operate, maintain and repair its distribution system. As a result, failure to replace vehicles
at the end of their useful lives will result in EDTI failing to meet the requirements of EDTI’s safe
work policies and, ultimately, failing to meet its obligations under sections 105 and 127 of the
305
Transcript, Volume 5, page 797, lines 11-14 (Mr. Shymanski). 306
Decision 2012-272, paragraphs 232-233. 307
Proceeding 3216, Exhibit 1, paragraph 264. 308
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 272.
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Electric Utilities Act to operate and maintain its distribution system in a safe and reliable manner,
and to provide and maintain service that is safe, adequate and proper.309
324. In 2013, this project consisted of the purchase of four new distribution function vehicles
and related fleet equipment, the replacement of fourteen existing vehicles and fleet equipment
that were at the end of their useful lives, and the replacement of two single reel trailers prior to
the end of their service lives due to damage.310
325. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $2.90 million. EDTI’s actual capital additions for this project were
$1.36 million, a variance of negative $1.54 million.311 In the 2013 capital tracker true-up
application, EDTI explained that this variance was composed of the following factors:
A carry forward of $1.64 million in vehicles into 2014. EDTI is currently forecasting that
it will cost $1.52 million to bring these vehicles into service in 2014.
the replacement of two vans was transferred to the transmission division, lowering
program costs by $0.32 million
lower than anticipated costs for new trailers lowering the program costs by $0.09 million
the decision not to replace a minivan as it will no longer be required, lowering the
program costs by $0.03 million
lower than anticipated costs for an underground cube van, lowering the program costs by
$0.01 million
a carry forward of a crane truck and 14’ truck originally planned for 2012 into 2013,
increasing program costs by $0.33 million and $0.16 million, respectively
higher than anticipated costs for the fault location van, increasing the program costs by
$0.04 million
higher than anticipated costs for the crew tool crib trailer, increasing the program costs by
$0.02 million312
326. As discussed in Section 6, EDTI confirmed its expectation that all of the 2013 deferred
work will be completed by the end of 2014, with the exception of the cube van vehicle as part of
this project. EDTI delayed the purchase of one 12’ cube van and two backhoes from 2013 to
2014 due to capital tracker uncertainty. EDTI provided the following update on the status of
those three vehicles:
To date, the chassis for the Cube Van has been ordered and will be delivered prior to the
end of 2014. However, EDTI anticipates that the completion of the construction of the
body for the Cube Van will carry into 2015 based on current delivery times from
fabricators. As a result, $0.04 million for the chassis will be in CWIP at the end of 2014,
with approximately $0.11 million of costs anticipated to be incurred to complete the body
in 2015 resulting in a 2015 capital addition of $0.15 million for this 2013 replacement
vehicle in 2015. In the interim, EDTI continues to lease a substitute vehicle as described
in AUC-EDTI-18 (ID 3100, Exhibit 93.01).
309
Proceeding 3100, Exhibit 26, Appendix A-9, paragraphs 23. 310
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 264. 311
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 266, Table 3.1.9-1 312
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 273-274.
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For the 2 Backhoe units, EDTI is currently completing specifications for the units and
will order and receive the units in Q4 of 2014. One of the existing units remains in
service and the other unit has been taken out of service and replaced with a rental unit.313
327. In regards to the $1.64 million carry-forward of vehicles, Mr. Elford explained that
approximately a million dollars of the carry-forward was due to a manufacturer delay and the
late delivery of two hydro-vacs. These vehicles were planned for 2013, but did not arrive until
early 2014.314 This delay in spending was not due to a discretionary management decision
because of the uncertainty surrounding the capital tracker mechanism.
328. Regarding the prudence of its actual 2013 capital additions, EDTI noted that these
distribution fleet additions were required to support the increasing construction and operating
work demands of EDTI’s distribution system, which continues to grow in response to growth in
the population of the City of Edmonton.315 EDTI confirmed that “nothing occurred between the
date of EDTI’s 2013 Tracker Application and the work completed in 2013 that obviated the need
for this project, or that would have materially impacted the conclusions reached in EDTI’s
analysis of alternatives.”316
329. With respect to the prudence of vehicle purchase costs, in response to AUC-EDTI-11,
EDTI described the purchasing process used to acquire the 25-ton crane truck in 2013. EDTI
explained that the vehicle chassis was purchased through the City of Edmonton’s vehicle volume
purchasing contract. EDTI procured the vehicle body and crane assembly requirements through a
competitive request for quotations (RFQ) process using the Alberta Purchasing Connection, an
electronic purchasing tool administered by the province of Alberta that enables public and
private sector users to manage, advertise, distribute, and download public purchasing
opportunities for goods, services, and construction in Alberta. Proposals were received from
three vendors. EDTI selected the vendor with the lowest quoted price.317
330. In general, regarding the pricing of vehicles in EDTI’s fleet, Mr. Middleton explained
that EDTI would typically issue an RFP for light vehicles. However, EDTI has typically found
that the suppliers who win the bids are also the suppliers with the City of Edmonton contracts.
As a result, EDTI will purchase the vehicles through the City of Edmonton contract to attain the
City pricing, which is lower because of the purchasing power of the City. In the case of heavy
vehicles, EDTI purchases through the City of Edmonton because of the City’s purchasing power
and its heavy equipment expertise. In addition to the beneficial pricing, EDTI also gains access
to the City’s expertise in terms of outfitting those vehicles at negotiated market prices.318
331. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $4.27 million in 2014 and $2.60 million in 2015.319 Consistent
with past applications, EDTI splits the total project cost into two categories: additions to EDTI’s
fleet, and life cycle replacement of vehicles. In 2014, EDTI proposed to purchase one new
313
Exhibit 118, Table UT-3, line 4. 314
Transcript, Volume 2, page 281 line 17 to page 282 line 6 (Mr. Elford). 315
Proceeding 3216, Exhibit 22, Appendix A-7, paragraph 18. 316
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 264. 317
Proceeding 3216, Exhibit 53.01, AUC-EDTI-11. 318
Transcript, Volume 2, page 390, line 12 to page 394, line 22 (Mr. Middleton). 319
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 273.
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vehicle; a one-ton cube van. EDTI did not propose to add any new vehicles in 2015.320 The
remaining expenditures on this project are for the life cycle replacement of vehicles.
332. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because the replacement of
these particular vehicles and fleet equipment that will reach the end of their useful lives in 2014
and 2015 is not an activity that could have been completed in previous years.321
Commission findings
333. In Decision 2013-435, the Commission determined that the Vehicles – Growth and Life
Cycle Replacements project was required to maintain service reliability and safety at adequate
levels in 2013. Further, the Commission determined that the scope, level, timing and forecast
costs for this project were reasonable as proposed for 2013. Accordingly, the Commission found
that this project satisfied the project assessment requirement of Criterion 1.322
334. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. In Section 6, the
Commission determined it will not disqualify from capital tracker treatment the five 2013 capital
tracker projects delayed, in whole or in part, because of the “substantial capital funding shortfall
under the I-X mechanism and the uncertainty respecting the capital tracker mechanism.” The
Commission finds no evidence on the record of Proceeding 3216 to indicate that the Vehicles –
Growth and Life Cycle Replacements project was not required in 2013.
335. Regarding vehicle pricing, EDTI’s purchasing prices are either determined on a
competitive basis through an PRP/RFQ process or are bought through the City of Edmonton
contract to attain the City’s pricing, which is lower because of the purchasing power of the City.
Accordingly, the Commission finds that EDTI’s purchasing prices for its vehicles are likely to be
reflective of market prices and, therefore, are reasonable.
336. EDTI’s 2013 actual capital additions of $1.36 million for the Vehicles – Growth and Life
Cycle Replacement project were $1.54 million lower than the $2.90 million forecast approved in
Decision 2013-435323 primarily due to EDTI’s decision to delay replacement of vehicles because
of uncertainty relating to the capital tracker mechanism.324 The Commission stated in Section 6
that with respect to the portion of the five projects completed in 2013, the Commission will
consider the prudence of the actual 2013 capital additions in the 2013 capital tracker true-up
application. The Commission has reviewed the costs of the actual capital additions for this
capital tracker project in light of the evidence supporting these costs, the associated procurement
and construction practices and the evidence explaining the differences between approved
forecast and actual costs, and finds the actual costs to be prudent.
320
Proceeding 3100, Exhibit 26, Appendix A-9, paragraphs 8-10. 321
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 280. 322
Decision 2013-435, paragraphs 912-915. 323
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 361, Table 3.1.14-1. 324
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 272.
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337. EDTI requested capital tracker treatment for this project in 2014 and 2015. In Section 6,
the Commission stated it will consider, for capital tracker treatment in 2014, the portions of the
five projects approved for capital tracker treatment in 2013 deferred from 2013 into 2014.The
Commission will also consider the portions of the 2014 work deferred to 2015, due to the
“cascading effect” described by EDTI.325
338. As noted in Section 3, where a forecasted program or project is part of a multi-year
ongoing program or project, or if the program or project is of an annual recurring nature, that has
previously been approved for capital tracker treatment, in the absence of evidence that the on-
going or recurring project or program is no longer required, the Commission will not undertake a
reassessment of need under Criterion 1. During the hearing, Mr. Shymanski expressed his view
that this project should be denied capital tracker treatment.326 However, Mr. Shymanski did not
provide any support for his position. The Commission finds no further evidence on the record of
Proceeding 3100 to indicate that the vehicles and fleet equipment purchases project is not
required to continue in 2014 or 2015.
339. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $4.27 million in
2014 and $2.60 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the list of
specific vehicles to be replaced as set out in Appendix A-7 of the 2013 capital tracker true-up
application and in Appendix A-9 of the 2014-2015 capital tracker forecast application and given
that EDTI’s purchasing prices of its vehicles are likely to be reflective of market prices, as
discussed earlier in this section.
340. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Vehicles – Growth and Life Cycle
Replacements project are reasonable as proposed for 2014 and 2015. Accordingly, the
Commission finds that this project satisfies the project assessment requirement of Criterion 1.
7.2.11 New Underground and Aerial Service Connections for Commercial, Industrial,
Multi-family and Miscellaneous Customers
341. This ongoing growth project consists of the engineering and installation of distribution
facilities to connect new industrial, commercial, multi-family, unmetered secondary and rural
customers to EDTI’s distribution system, and to increase capacity and upgrade existing service
connections when requested by these types of customers.327 EDTI provided a business case and
engineering study for this project in Appendix A-3 of the 2013 capital tracker true-up
application, and in Appendix A-5 of the 2014-2015 capital tracker forecast application.
342. EDTI indicated that service connections are installed in accordance with its Customer
Connection Guide, and the choice of aerial versus underground services is determined on a site-
by-site basis. The appropriate service type is dictated by City of Edmonton bylaws, policies and
325
Transcript, Volume 1, page 165, lines 15-22 (Mr. Elford). 326
Transcript, Volume 5, page 797, lines 14-15 (Mr. Shymanski). 327
Proceeding 3216, Exhibit 12, Appendix A-3, paragraph 1.
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land use planning requirements, the customer’s requirements and the site specific conditions, and
any other applicable regulations, standards or codes.328
343. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner, and to provide and maintain service that is safe, adequate and proper.
Further, EDTI is obligated, under the terms of its franchise agreement with the City of
Edmonton, to provide service to sites within the City. Accordingly, the purpose of this project is
to ensure that customers in EDTI’s service area are provided with safe and reliable service
connections that are of sufficient capacity to meet their load requirements.329
344. EDTI further commented on the need for this project as follows:
To summarize, this project is not subject to management discretion. It is required to
enable EDTI to meet its obligations to provide distribution service to sites within EDTI’s
service area. If EDTI does not install appropriate service connections at each site in its
service area, EDTI will fail to comply with its obligations under sections 105 and 127 of
the Electric Utilities Act and Franchise Agreement with the City of Edmonton. The
purpose of the project, by its nature, cannot be accomplished through an O&M solution,
nor can EDTI meet its obligations to provide service without providing service
connections for each site. Further, this project could not have been undertaken in the past
as part of a prudent capital maintenance and replacement program. Providing service
connections to new customer sites, by its nature, is not an activity that could have been
included in such a program in the past.330
345. EDTI explained that capital expenditures for this project are primarily driven by the
number and type of customer service connections installed in a given year. EDTI observed that
the average cost per connection increased over the 2010 to 2013 period and expected that the
trend will continue in 2014 and 2015, largely due to the following key factors: an increase in the
capacity, size and number of services for industrial customers, an increase in the number of big
box store complexes developed in EDTI’s service area, and an increase in the size and
complexity of service connections in the downtown core of Edmonton.
346. The forecast for this project for 2013 was developed based on EDTI’s forecast number of
service connections and on EDTI’s cost experience with the types and volumes of service
connections in the past, including the upward trend in cost per service connection for both aerial
and underground services. To forecast the number of service connections, EDTI relied on a
three-year annual average of the number of customer services over 2009 to 2011, consistent with
the approach used in its 2012 GTA.
347. In Decision 2013-435, the Commission approved 2013 forecast capital additions for this
project in the amount of $8.73 million.331 EDTI’s actual capital additions for this project were
$10.00 million, for a variance of $1.27 million.332 EDTI explained that the $1.27 million increase
in capital additions in 2013 was primarily related to a higher than forecast volume of customer
service connections being installed in 2013. Specifically, EDTI indicated that it was required to
328
Proceeding 3216, Exhibit 12, Appendix A-3, paragraph 4. 329
Proceeding 3216, Exhibit 12, Appendix A-3, paragraphs 22-23. 330
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 219. 331
Decision 2013-435, paragraphs 988-989. 332
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 219-220.
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install 584 customer service connections in 2013, rather than 473 customer service connections
forecast for that year. Also, included in EDTI’s 2013 capital additions was $1.09 million added
through CWIP for customer service work that was started in 2012 and completed in 2013.333
348. Regarding the prudence of its actual 2013 capital additions, EDTI indicated the costs
included in this project consisted of engineering (25 per cent), material (24 per cent) and
construction (51 per cent) costs. EDTI described the steps it took to ensure that the work was
completed in a cost effective manner.334 EDTI confirmed that “nothing occurred between the date
of EDTI’s 2013 Tracker Application and the work completed in 2013 that obviated the need for
this project, or that would have materially impacted the conclusions reached in EDTI’s analysis
of alternatives.”335
349. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $9.00 million in 2014 and $9.41 million in 2015.336 EDTI based
its 2014 forecast capital expenditures for this project on a normalized three-year average of the
total actual costs included in this project category from 2011 to 2013.337 EDTI provided details of
its normalized three-year average forecasting methodology for this project in response to AUC-
EDTI-19.338 The $0.41 million increase in capital additions from 2014 forecast to 2015 forecast is
primarily due to inflation.339
350. EDTI explained that the use of the normalized three-year average allows the forecast to
reflect the trend of increasing cost per service connection in the 2014 and 2015 forecast capital
additions for this project. As a further check, EDTI compared its forecast average costs per
service connection with its historical average costs per service connection and concluded that the
forecast costs per underground and aerial service connection are consistent with the three-year
historical average costs per underground and aerial service connection.340
Commission findings
351. In Decision 2013-435, the Commission determined that EDTI’s New Underground and
Aerial Service Connections for Commercial, Industrial, Multi-family and Miscellaneous
Customers project was required to maintain service reliability and safety at adequate levels in
2013. Further, the Commission determined that the scope, level, timing and forecast costs for this
project were reasonable as proposed for 2013. Accordingly, the Commission found that this
project satisfied the project assessment requirement of Criterion 1.341
352. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
333
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 221, 235. 334
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 222-232. 335
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 218. 336
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 214. 337
Proceeding 3216, Exhibit 12, Appendix A-3, paragraphs 28-31, Proceeding 3100, Exhibit 22, appendix A-5,
paragraphs 28-31. 338
Proceeding 3100, Exhibit 93.01, AUC-EDTI-19. 339
Proceeding 3100, Exhibit 22, Appendix A-5, paragraph 50. 340
Proceeding 3100, Exhibit 22, Appendix A-5, paragraphs 33-36. 341
Decision 2013-435, paragraphs 917-919.
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finds no evidence on the record of Proceeding 3216 to indicate that the New Underground and
Aerial Service Connections for Commercial, Industrial, Multi-family and Miscellaneous
Customers project was not required in 2013.
353. With respect to the scope, level and timing of the New Underground and Aerial Service
Connections for Commercial, Industrial, Multi-family and Miscellaneous Customers project
carried out in 2013, the Commission has reviewed EDTI’s 2013 actual capital additions of $10.0
million associated with this project and finds that they are generally consistent with the scope,
level and timing of the work outlined in the business case for this capital tracker and approved in
Decision 2013-435. The Commission has also reviewed the costs of the actual capital additions
for this capital tracker project in light of the evidence supporting these costs, the associated
procurement and construction practices and the evidence explaining the differences between
approved forecast and actual costs, and finds the actual costs to be prudent.
354. EDTI requested capital tracker treatment for this project in 2014 and 2015. As noted in
Section 3, where a project or program is part of an ongoing multi-year program, or if a project or
program is of an annual recurring nature that has been previously approved by the Commission
for capital tracker treatment, in the absence of evidence that the ongoing or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1. The Commission finds no evidence on the record of Proceeding 3100 to indicate that
the New Underground and Aerial Service Connections for Commercial, Industrial, Multi-family
and Miscellaneous Customers project is not required to continue in 2014 or 2015. In this regard,
the Commission notes that during the hearing, Mr. Shymanski supported capital tracker
treatment for this project.342
355. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $9.0 million in
2014 and $9.41 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the
normalized three-year average of 2011 to 2013 historical actual annual costs. The Commission
found EDTI’s normalized three-year average forecasting methodology to be reasonable in
Decision 2012-272.343 The Commission also finds the forecast costs to be reasonable when
compared to the actual costs in prior years.344
356. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the capitalized underground system
damage project are reasonable as proposed for 2014 and 2015. Accordingly, the Commission
finds that this project satisfies the project assessment requirement of Criterion 1.
7.2.12 Underground Residential Distribution (URD) Servicing – Rebates, Acceptance
Inspections & Terminations
357. This ongoing project consists of development rebates, acceptance inspections,
terminations, and distribution work performed by EDTI with respect to URD servicing. EDTI
342
Transcript, Volume 5, page 797, lines 2-4 (Mr. Shymanski). 343
Decision 2012-272, paragraphs 232-233. 344
Proceeding 3100, Exhibit 22, Appendix A-5, Table 3.2-2 on page 9.
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provided business cases and engineering studies for the URD servicing project in Appendix A-9
of the 2013 capital tracker true-up application and in Appendix A-11 of the 2014-2015 capital
tracker forecast application.
358. EDTI explained that development rebates are paid when developers build underground
primary and secondary distribution infrastructure as part of new residential lot developments
within EDTI’s service area. URD infrastructure consists of primary and secondary distribution
cables, transformers and switch cubicles. Acceptance inspections occur when a developer has
installed URD infrastructure on a new lot and EDTI inspects the physical installation and assets,
as well as the developer’s engineering design, for compliance with the City of Edmonton
Servicing Standards Manual.345 The project includes instances where EDTI ties-in, energizes, and
terminates the URD facilities. Also included in this project is URD work done by EDTI, which
includes modifications, extensions, load balancing, and ties between developments on the
existing underground distribution system; and the cost of equipment and other assets including
cables, transformers, and switching cubicles.
359. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI maintains that this project is
required to provide service to customers at adequate levels. EDTI stated that it is also obligated
to provide the distribution infrastructure necessary to connect new customer sites to EDTI’s
system within the City of Edmonton under its Franchise Agreement.346
360. EDTI characterized the drivers of this project as the requirement to connect new
customers due to growth and requests by external developers for service.347 EDTI further
explained that the need for URD servicing is not subject to management discretion and given that
these are service connections to new customers, the project could not have been undertaken in
the past.
361. According to EDTI, the volume of URD servicing work is related to factors beyond its
control and, therefore, varies from year to year. As such, consistent with past GTAs, EDTI’s
2013 forecast number of lots requiring service was based on a three-year average of the 2009-
2011 actual annual lots serviced, where EDTI paid contributions. To forecast the capital
expenditures for the URD rebates portion of this project, EDTI multiplied the forecast number of
lots by $2,530, the rebate amount per lot that was approved by the Commission in Decision
2013-435.348 The URD inspection and termination expenditures were forecast using management
judgment and the 2009-2011 average cost per lot to complete this type of work. The capital
expenditures relating to URD work to be completed by EDTI were forecast based on
management judgement and the 2009-2011 average cost per lot to complete this type of work.
362. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $12.13 million. EDTI’s actual capital additions for this project were
$19.53 million, a variance of $7.40 million. In the 2013 capital tracker true-up application, EDTI
explained that the $7.40 million increase in capital additions from the approved 2013 forecast to
345
Proceeding 3216, Exhibit 24, appendix A-9, paragraph 10. 346
Proceeding 3216, Exhibit 24, appendix A-9, paragraph 13. 347
Transcript, Volume 3, pages 438-439 ( Mr. Sorenson). 348
Decision 2013-435, paragraph 923.
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2013 actual amounts reflects a higher number of actual lots serviced in 2013. EDTI had forecast
3,716 lots to which a rebate to developers would be provided, whereas the actual number of lots
rebated was 5,816.
363. Regarding the prudence of its actual 2013 capital additions, EDTI confirmed that the
work performed in 2013 in respect of this project related only to rebates paid to developers,
acceptance inspections of URD infrastructure, terminating and tying-in URD infrastructure to the
distribution system and URD work done by EDTI. EDTI confirmed that “nothing occurred
between the date of EDTI’s 2013 Tracker Application and the work completed in 2013 that
obviated the need for this project, or that would have materially impacted the conclusions
reached in EDTI’s analysis of alternatives.”349
364. The URD rebate of $2,530 per lot service remained unchanged from EDTI’s 2013
forecast capital tracker application. EDTI explained that 82 per cent of the 2013 actual capital
additions were associated with the rebates paid to developers. EDTI described the steps it took to
ensure that the work associated with each component of this project was completed in a cost
effective manner.350
365. With respect to acceptance inspections, which account for the remaining 18 per cent of
costs for this project, EDTI indicated it used both internal engineers and external consultants to
complete the work. External consultants are used when EDTI’s internal staff does not have the
required expertise. In 2013, EDTI used a single external engineering consultant whose rates were
consistent with a 2012 RFP for engineering design work. EDTI also explained inspections are
only done when the developer has issued notice of the work being completed. For the
terminations and tie-ins, EDTI uses internal staff and the required work is carried out only after
EDTI’s engineers approve the installation. The cables, transformers and switching cubicles used
in the URD project were all purchased through RFP processes. In 2011, a cable provider was
selected as the lowest cost provider who could meet the necessary requirements and was signed
to a five-year contract. A switching cubicle provider was chosen in 2007 as the lowest cost
provider for the majority of cubicles used. EDTI noted that for a number of cubicle types, the
costs have decreased between 2007 and 2013.351
366. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $17.72 million in 2014 and $18.10 million in 2015. Consistent
with past applications, EDTI based its 2014 and 2015 forecast number of lots requiring service
on the historical average of actual lots serviced from 2011 to 2013. The rebate amount per lot
was determined by taking the 2013 rebate amount per lot of $2,530 and escalating it by I-X for
2014 and 2015. EDTI’s 2014 rebate amount is $2,570 per lot and the 2015 rebate amount is
$2,610 per lot.352 EDTI indicated it escalated the rebate amounts by I-X in accordance with
Decision 2012-237.353 The forecast expenditures for URD inspections and terminations, as well
as URD work completed by EDTI, were determined using the respective normalized three-year
349
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 301. 350
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 304-325. 351
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 304-325. 352
Proceeding 3100, Exhibit 48, appendix A-11, paragraph 5. 353
Decision 2012-237, paragraph 848.
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average of actual costs from 2011-2013. The $0.38 million increase in capital additions from
2014 forecast to 2015 forecast is due to inflation.354
367. During the hearing, EDTI’s witness, Mr. Sorenson, indicated that for 2014 EDTI is
expecting to be over the original forecast of $17.72 million by $3.7 million at the end of the
year.355
368. EDTI indicated that this project cannot be deferred and no alternatives are available for
EDTI to meet its obligations to provide service. EDTI also maintained that a prudent capital
maintenance project could not have been undertaken in the past for this project because this
project provides service to new residential customers.356
Commission findings
369. In Decision 2013-435, the Commission determined that in 2013, the Underground
Residential Distribution Servicing project was required to maintain service reliability and safety
at adequate levels. Further, the Commission determined that for 2013, the scope, level, timing
and forecast costs for this project were reasonable as proposed. Accordingly, the Commission
found that this project satisfied the project assessment requirement of Criterion 1.357
370. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the URD project was not
required in 2013.
371. With respect to the scope and timing of the URD project carried out in 2013, the
Commission has reviewed EDTI’s 2013 actual capital additions of $19.53 million associated
with this project and finds that the scope and timing are generally consistent with the scope and
timing outlined in the business case for this capital tracker and approved in Decision 2013-435.
372. With respect to the level of the URD project in 2013 and the resulting project costs of
$19.53 million, the Commission does not consider them to be consistent with the level outlined
in the business case for this capital tracker and approved in Decision 2013-435. Consistent with
its past practices, EDTI uses a three-year historical average approach to forecast capital additions
for this project. During the hearing, Mr. Elford confirmed that EDTI had relied on the three-year
average to forecast the expenditures on this project under cost of service regulation as well, prior
to advent of PBR.358
373. The Commission is of the view that this approach is reasonable given the extra
complexity and resources that would be required to forecast using another methodology and
would not necessarily be justified, as it is unlikely the results would provide a significantly more
accurate forecast of the capital additions for this project in the long run. The three-year historical
354
Proceeding 3100, Exhibit 48, Appendix A-11, paragraph 36. 355
Transcript, Volume 2, page 254, lines 5-7 (Mr. Sorenson). 356
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 310-311. 357
Decision 2013-435, paragraphs 921-923. 358
Transcript, Volume 2, page 253, lines 7-11 (Mr. Elford).
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average methodology provides a reasonable forecast of the level of the project; however, given
the numerous factors that govern the actual level of URD installations or associated work, it is
recognized that there may be instances where the historical average methodology under or over
estimates the level of the project for a given year.
374. The Commission recognizes that the 2013 forecast provided using the three-year
historical average methodology under-forecast the capital additions for this project by
$7.4 million. The Commission is cognizant of the fact that capital additions under this project are
not within the control of EDTI and that the work must be completed as requested by new
customers. As such, although the level of the URD project in 2013 is not consistent with the
level approved in Decision 2013-435, the Commission finds that the actual level of capital
additions is prudent based on the actual number of lots connected.
375. The Commission has also reviewed the costs of the actual capital additions for this
capital tracker project in light of the evidence supporting these costs, the associated procurement
and construction practices and the evidence explaining the differences between approved
forecast and actual costs, and finds the actual costs to be prudent.
376. EDTI requested capital tracker treatment for this project in 2014 and 2015. As noted in
Section 3, where a forecast program or project is part of a multi-year ongoing program or project,
or if the program or project is of an annual recurring nature, that has previously been approved
for capital tracker treatment, in the absence of evidence that the on-going or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1. The Commission finds no evidence on the record of Proceeding 3100 to indicate that
the URD project is not required to continue in 2014 or 2015. In this regard, the Commission
notes that during the hearing, Mr. Shymanski supported capital tracker treatment for this
project.359
377. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are $17.72 million in
2014 and $18.10 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on the methods
outlined in the business case.360
378. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the URD project are reasonable as
proposed for 2014 and 2015. Accordingly, the Commission finds that this project satisfies the
project assessment requirement of Criterion 1.
7.2.13 Capital Tools and Instrument Purchases
379. This ongoing project consists of refurbishing, replacing and upgrading EDTI’s
distribution function tools and instruments that are required by EDTI personnel for their ongoing
safe construction, operation, inspection, maintenance and repair of EDTI’s distribution aerial and
359
Transcript, Volume 5, page 797, lines 19-21 (Mr. Shymanski). 360
Proceeding 3100, Exhibit 48, appendix A-11, paragraphs 19-21.
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underground facilities.361 The majority of expenditures for this project are related to life cycle
replacement and a small portion of this project is necessary to meet new requirements based on
new testing standards specified for distribution equipment or for performance enhancement
purposes and allow EDTI field staff to complete their work in a safer or more efficient manner.362
EDTI explained that it capitalizes the costs associated with these projects consistent with its
Capitalization Policy and Property Unit Catalogue.363 EDTI noted that this project was approved
as a capital tracker in Decision 2013-435.364 EDTI provided business cases and engineering
studies for the Capital Tools and Instrument Purchases project in Appendix A-10 of the 2013
capital tracker true-up application and in Appendix A-12 of the 2014-2015 capital tracker
forecast application.
380. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to inspect, test, and
maintain in good order all installed electrical equipment.
381. In Decision 2013-435, the Commission approved forecast capital additions for this
project in the amount of $1.36 million. EDTI’s actual capital additions for this project were
$0.98 million, a variance of negative $0.38 million.365 In the 2013 capital tracker true-up
application, EDTI explained that the fault locating and cable testing equipment was originally
planned to be placed in service for 2013; however, EDTI was able to place this equipment into
service by the end of 2012 resulting in 2013 costs being $0.29 million lower than forecast.
EDTI’s decision to engage a specialized contractor to carry out the condition testing and
engineering analysis of its underground cable sections obviated the need to purchase a cable test
set resulting in a $0.05 million decrease in costs. EDTI’s decision not to retrofit the components
in one of its meter shop test consoles resulted in a $0.05 million decrease in costs. EDTI
determined that the test console needs to be replaced and it will do so in 2015. These decreases
were partially offset by a $0.01 million increase relating to small increases in a number of capital
tool purchase categories.366
382. Regarding the prudence of its actual 2013 capital additions, EDTI confirmed that
“nothing occurred between the date of EDTI’s 2013 Tracker Application and the work
completed in 2013 that obviated the need for this project, or that would have materially impacted
the conclusions reached in EDTI’s analysis of alternatives.”367
383. In his evidence, Mr. Shymanski, for the UCA, indicated the following with respect to
EDTI’s Capital Tools and Instrument Purchases project and the Replacement of Faulted PILC
Cables project:
I have examined a number of EDTI’s proposed CT projects and have determined that at
least two of them, while slightly above the Tier 1 materiality, should not qualify for CT
status and thus K Factor calculation because EDTI’s forecasts are optimistic. A more
361
Proceeding 3216, Exhibit 1, Paragraph 329; Proceeding 3100, Exhibit 49, paragraph 1. 362
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 315, page 104 363
Proceeding 3100, Exhibit 49, paragraph 7. 364
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 317. 365
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 332, Table 3.1.12-1. 366
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 337-338. 367
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 331.
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reasonable forecast, based on EDTI’s track record for that project in 2013, would result in
a slightly lower forecast capital addition that would not allow it to qualify for CT status
and thus K Factor inclusion.368
384. The first part of Mr. Shymanski’s recommendation, that this project should not qualify
for capital tracker treatment because it is “slightly above the Tier 1 materiality,” is dealt with in
Section 10 on Criterion 3 assessment. Regarding the second part of Mr. Shymanski’s
recommendation, that EDTI’s forecasts are optimistic, Mr. Shymanski acknowledged during the
hearing that, when looking at the actual historical expenditures from 2008 to 2013,369 EDTI does
not seem to have a consistent history of over-forecasting on capital tool and instrument
purchases.370
Table 8. Variance between forecasts and actuals on capital tool and instrument purchases 2008-2013 ($ million)371
2008 D
2008 A
2009 A
2009 A
2010 D
2010 A
2011 D
2011A 2012 D
2012 A
2013 D
2013 A
Capital Additions
0.47 0.57 0.62 0.44 0.96 1.19 0.63 0.86 1.17 1.12 1.36 0.98
Variance 0.10 (0.17) 0.23 0.23 (0.05) (0.38)
385. However, Mr. Shymanski maintained that the actual historical expenditures on this
project prior to PBR and associated variances between the actual and forecast numbers should
carry less weight when informing the Commission’s judgement than the 2013 variance:
Q. Why […] should we reduce the 2014 forecast based solely on the 2013 variance?
A. MR. SHYMANSKI: I would say in my view, that was the first -- well, is the first year
of the PBR, the capital tracker, and from my perspective that was the most relevant.
Q. And why is that?
A. MR. SHYMANSKI: It's a new type of regulation, PBR versus cost of service.
Q. But isn't capital trackers based on cost-of-service regulation?
A. MR. SHYMANSKI: The calculations in part are, but there's a more rigorous
requirement under PBR capital tracker to provide business case, to provide explanations
that didn't exist to that extent under cost of service.
Q. So in your view, then, basically what's gone before PBR should not be relevant in
determining whether the forecasts under PBR are relevant for capital tracker purposes?
A. MR. SHYMANSKI: It would have less weight. I wouldn't say it's irrelevant, but less
weight.372
386. Mr. Shymanski further explained that the 2013 forecast would have resulted in a capital
tracker; however, the actual spending is an amount that falls below the materiality threshold. In
this regard, Mr. Shymanski argued that because the 2014 forecast is “just so close to the
materiality limit, that it's likely they would do the same thing in the year 2014.”373
368
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraph 74. 369
Proceeding 3100, Exhibit 49, Appendix A-12, paragraph 49. 370
Transcript, Volume 5, page 805 line 23 to page 806 line 2. (Mr. Shymanski). 371
Proceeding 3100, Exhibit 49, Appendix A-12, paragraph 49, Table 5.0-1. 372
Transcript, Volume 5, page 806, lines 3-23 (Mr. Shymanski). 373
Transcript, Volume 5, page 807, lines 14-20 (Mr. Shymanski).
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387. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $0.76 million in 2014 and $0.87 million in 2015.374 Consistent
with past applications, EDTI indicated there are no changes in the scope of this project, and
referred again to its previous approval as a capital tracker in Decision 2013-435. In 2014, EDTI
plans to add new tools for growth vehicles, replace one of its portable fault locating test units,
complete the replacement of its atmospheric test equipment, which has reached the end of its
useful life and must be replaced for safety reasons, and equip all of its aerial linemen with arc
flash rated fall arrest harnesses.375 In 2015, EDTI plans to add one additional infrared camera for
use by an inspection crew carrying out thermal inspections and replace one meter test console.376
388. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because the replacement of
the particular tools and instruments that will reach the end of their useful lives in 2014 and 2015
is not an activity that could have been completed in previous years.377
Commission findings
389. In Decision 2013-435, the Commission determined that the Capital Tool and Instrument
Purchases project was required to maintain service reliability and safety at adequate levels in
2013. Further, the Commission determined that the scope, level, timing and forecast costs for this
project were reasonable as proposed for 2013. Accordingly, the Commission found that this
project satisfied the project assessment requirement of Criterion 1.378
390. With respect to the true-up of 2013 actual costs, as noted in Section 3, in the absence of
evidence on the record that the project was not required, the Commission will not reconsider the
need for approved capital tracker programs or projects in a true-up application. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the Capital Tool and
Instrument Purchases project was not required in 2013.
391. With respect to the scope, level and timing of the Capital Tools and Instrument Purchases
project carried out in 2013, the Commission has reviewed EDTI’s 2013 actual capital additions
of $0.98 million associated with this project and finds that they are generally consistent with the
scope, level and timing of the work outlined in the business case for this capital tracker and
approved in Decision 2013-435. The Commission has also reviewed the costs of the actual
capital additions for this capital tracker project in light of the evidence supporting these costs, the
associated procurement and construction practices and the evidence explaining the differences
between approved forecast and actual costs, and finds the actual costs to be prudent.
392. EDTI requested capital tracker treatment for this project in 2014 and 2015. As noted in
Section 3, where a forecast program or project is part of a multi-year ongoing program or project,
or if the program or project is of an annual recurring nature, that has previously been approved
for capital tracker treatment, in the absence of evidence that the on-going or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1.
374
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 318. 375
Proceeding 3100, Exhibit 49, Appendix A-12, paragraphs 20, 24, 30 and 33. 376
Proceeding 3100, Exhibit 49, Appendix A-12, paragraphs 10 and 19. 377
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 225. 378
Decision 2013-435, paragraphs 925-927.
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393. During the hearing, Mr. Shymanski expressed his view that this project should be denied
capital tracker treatment379 for the reasons set out earlier in this section. The Commission finds
no further evidence on the record of Proceeding 3100 to indicate that the Capital Tool and
Instrument Purchases project is not required to continue in 2014 or 2015.
394. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission does not agree with Mr. Shymanski’s view that the 2013 variance should take
priority over the preceding five years when considering the validity of the 2014-2015 forecasts.
Although 2013 was the first year of the PBR regime, the treatment of capital expenditure
forecasts for capital tracker projects has generally remained the same as under the cost of service
regulation, albeit with more defined filing requirements to support the reasonableness forecast, as
set out in Section 10.2 of Decision 2013-435. As the Commission observed in that decision,
“[a]lthough the intent of the PBR plan was to break the link between revenues and costs, capital
trackers would be regulated on a cost-of-service basis, thereby linking revenues and costs for
these expenditures.”380
395. During the hearing, Mr. Shymanski acknowledged that when looking at the actual
historical expenditures from 2008 to 2013,381 EDTI does not seem to have a consistent history of
over-forecasting on capital tool and instrument purchases.382 The Commission agrees. As shown
in Table 8 above, over the 2008 to 2013 period, EDTI’s forecasts exceeded actual expenditures
in some years and were less than actuals in other years, with an overall variance netting to
approximately zero over this period. Therefore, the Commission does not agree with Mr.
Shymanski’s conclusion that “EDTI’s forecasts are optimistic” and does not accept his
recommendation to adjust downwards EDTI’s forecast capital additions on the capital tools and
instrument purchases project.383 In the event that EDTI’s actual capital additions on this project
are less than forecast, any necessary adjustments to the K factor amount recovered from EDTI’s
customers on a forecast basis will be made at the time of the true-up application.
396. EDTI’s forecast capital additions associated with this project are $0.76 million in 2014
and $0.87 million in 2015. The Commission has reviewed the business case and the relevant
portions of the record for this project and finds the forecast scope, level and timing of the project
for 2014 and 2015 to be prudent.
397. The Commission finds the total annual cost forecast to be reasonable based on the
specific activities that EDTI forecast for this project contained in Appendix A-10 of the 2013
capital tracker true-up application and in Appendix A-12 of the 2014-2015 capital tracker
forecast application. These activities include adding new tools for growth vehicles, replacing one
of its portable fault locating test units, completing the replacement of its atmospheric test
equipment, which has reached the end of its useful life and must be replaced for safety reasons,
and equipping all of its aerial linemen with arc flash rated fall arrest harnesses.384 In 2015, EDTI
379
Transcript, Volume 5, page 797, lines 22-23 (Mr. Shymanski). 380
Decision 2013-435, paragraph 116. 381
Proceeding 3100, Exhibit 49, Appendix A-12, paragraph 49. 382
Transcript, Volume 5, page 805 line 23 to page 806 line 2. (Mr. Shymanski). 383
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraph 74. 384
Proceeding 3100, Exhibit 49, Appendix A-12, paragraphs 20, 24, 30 and 33.
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plans to add one additional infrared camera for use by an inspection crew carrying out thermal
inspections and replace one meter test console.385
398. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Capital Tool and Instrument
Purchases project are reasonable as proposed for 2014 and 2015. Accordingly, the Commission
finds that this project satisfies the project assessment requirement of Criterion 1.
7.2.14 Poundmaker Feeders
399. The Poundmaker Feeders project involves the construction of four feeders from EDTI’s
new point of delivery at its Poundmaker substation located in west Edmonton. EDTI explained
that this project was necessary to maintain system reliability and provide the capacity to
accommodate customer growth in the area. Since this project was initially expected to be
completed in 2012, EDTI provided a copy of the Poundmaker Feeders project business case from
its 2012 GTA in Appendix A-11 of the 2013 capital tracker true-up application and in
Appendix C of the 2014-2015 capital tracker forecast application.
400. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI explained that the work
completed under the Poundmaker Feeders project was necessary to maintain the safety and
reliability of its system. Construction of the new feeders was necessary to meet the capacity
needs related to the load growth on its system.
401. As explained in Decision 2013-435, the Poundmaker Feeders project is an example of
EDTI’s “Category 3” projects that require capital tracker treatment because of the application of
the mid-year convention. The mid-year convention calculation of the company’s going-in year
return and depreciation is one of the factors that may cause a shortfall in capital funding under
the PBR formula. As such, even though there were no capital additions forecast for the
Poundmaker Feeders project in 2013, the Commission afforded capital tracker treatment for this
project because of the shortfall in capital funding under the PBR formula.386
402. EDTI planned to complete all of the work associated with this project in 2012. However,
in 2011, EDTI was able to complete and put into service some aerial line reconfiguration work
that was required for this project resulting in capital additions of $0.15 million. This aerial work
was completed and put into service early to accommodate the installation of a new pipeline
through the Transportation Utility Corridor that required the relocation of EDTI facilities
associated with the Poundmaker Feeder project.387
403. EDTI indicated it completed the vast majority of the work in 2012, with capital additions
of $11.09 million, and was able to put this project into service in that year. In an IR, the
Commission asked EDTI why its 2013 capital tracker forecast application did not include
updated 2012 capital additions amounts for the Poundmaker Feeders project. EDTI responded
that it did not have sufficient time or resources to provide the updated information between the
385
Proceeding 3100, Exhibit 49, Appendix A-12, paragraphs 10 and 19. 386
Decision 2013-435, paragraph 932. 387
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 335.
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time Decision 2012-237 was released and the time its 2013 capital tracker applications were
due.388
404. Due to abnormally cold weather in October 2012, EDTI could not complete all of the
required site restoration work and the permanent site access road by year end. EDTI completed
this remaining work in 2013 at a cost of $0.14 million. In addition, EDTI noted it was not able to
complete a small amount of the aerial work associated with this project in 2012 as initially
expected. This work was completed in 2013 at a cost of $0.01 million. Further, in 2013 EDTI
discovered that it had included an incorrect amount in rate base for certain cable assets related to
the project in 2012. The amount included was $0.08 million lower than the correct amount, and
EDTI corrected this error in 2013.389 EDTI’s actual capital additions for this project in 2013
totalled $0.23 million.
405. Overall, EDTI indicated that the total actual capital additions associated with the
Poundmaker Feeders project were $11.47 million. This actual cost is $4.24 million higher than
the forecast amount of $7.23 million approved in EDTI’s 2012 GTA, Decision 2012-272. EDTI
explained that this increase was primarily driven by higher than forecast costs for the
construction of the ductline component of the project resulting from poorer than expected soil
conditions in the area where the ductline was constructed. In the 2013 capital tracker true-up
application, EDTI outlined the specific factors that contributed to the increase in actual costs.390
During the hearing, Ms. Hull, for EDTI, provided further engineering insight on how poor soil
conditions contributed to a higher than forecast cost of the Poundmaker Feeders project.391
Combined, the increase in costs related to poor soil conditions totalled $1.0 million.
406. An additional $1.72 million increase was due to higher than expected costs related to
civil contractors. EDTI indicated it competitively procured contracted services for the ductline
construction and horizontal directional drilling required for the project. EDTI further stated that
market conditions in 2012 resulted in higher pricing to complete this work than forecast. EDTI’s
original forecast for this work was prepared in early 2011 when the market for civil construction
contracts was more favorable.392 In response to the CCA’s request, EDTI demonstrated that,
given the specialized and sporadic nature of the type of civil construction work required for the
Poundmaker Feeders project that led to the increased costs, such as construction of long length
distribution feeder duct lines, including horizontal directional drilling sections, there is no merit
in it developing these skills and acquiring the specialized equipment in-house.393
407. Several other factors resulted in increased costs for this project. One such factor was that
the ductline feeder capacity increased from six to eight feeders. The ductline configuration was
changed from a nine-way (six feeders total) to a 12-way (eight feeders total) to allow for two
additional feeders to be routed south from the substation to support projected growth in West and
Southwest Edmonton. EDTI indicated that the 2012 capital additions associated with the
increased capacity for future growth were $0.23 million. EDTI further elaborated on this issue:
388
Proceeding 3216, Exhibit 53.01, AUC-EDTI-12. 389
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 342. 390
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 356. 391
Transcript, Volume 3, pages 463-464 and pages 468-469 (Ms. Hull). 392
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 357. 393
Proceeding 3216, Exhibit 54.01, CCA-EDTI-13(d).
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This additional capacity will allow EDTI to respond to changing load growth patterns
more efficiently and in a more timely manner, by reducing the construction requirements,
cost and time required to energize new distribution circuits from the Poundmaker
Substation (currently expected to be required in or about late 2015 based on EDTI’s
System Planning forecasts. There is limited unencumbered land within the 240kV
transmission line right of way where the feeders originate and EDTI is typically unable to
secure alignments from The City of Edmonton, for installation within City Road Right of
Way and Alberta Infrastructure, for installation within the TUC for these future
additional feeders until they must be installed. Additionally, as the project developed
EDTI concluded that the construction of a single 12 way ductline and access road could
be achieved at a significantly lower incremental cost than constructing a second ductline
for the two additional feeders in the future, in particular when the extra measures required
to address the poor soil conditions were considered. The cost to add the additional duct
space at this time was estimated to be approximately $180 per metre, or 83% cheaper
than if EDTI had to design and construct an additional ductline in the future. As a result
EDTI determined that the incremental cost of $0.23 million for increasing the capacity of
the duct bank was prudent.394
408. In response to a Commission IR, EDTI indicated that the full capacity of the ductline
would not be in use until 2025.395 During the hearing, Mr. Elford, for EDTI, further commented
on EDTI’s decision to expand the ductline feeder capacity:
And in this case, looking at the information in front of them and the fact that the
incremental cost was only $230,000, substantially less than what it would be if we had to
go back and build it ten years later, we determined that not to deviate from the alternative
we recommended, but to expand the scope a little bit in the interests of good planning.396
[…]
It's no different than when we build a new feeder in the conversation I had with Mr.
McNulty this morning. As feeders go in at a proper size and the capacity is not
immediately used up, customers connect to that feeder over time, and it rebalances the
load to allow us to run our system. If we constantly just built to exactly what was needed,
we would constantly be building in small pieces at a far higher cost. And so that's why
we are saying this is just some excess capacity in a duct line that will be used in the
future, and it will be far cheaper. And that's the prudent decision to make. If we're told
not to do that, we'll be coming back with future projects at a far higher cost, for example,
in this case.397
409. An additional factor leading to a $0.38 million increase in project costs resulted from a
design change of a project component involving intercepting two existing West Edmonton
substation feeders and re-routing them to the Poundmaker substation via the ductline. In the 2013
capital tracker true-up application, EDTI explained that these design changes resulted from
consultation with Alberta Infrastructure, where EDTI was required to ensure the installations
would not interfere with the proposed long term plan for expansion of Anthony Henday Drive in
394
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 357. 395
Proceeding 3100, Exhibit 53.01, AUC-EDTI-13(a) and (b). 396
Transcript, Volume 3, page 451, lines 12-18 (Mr. Elford). 397
Transcript, Volume 3, page 453, lines 12-23 (Mr. Elford).
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this area.398 During the hearing, Ms. Hull provided further engineering insight on the scope
changes related to this component of the Poundmaker Feeders project.399
410. During the hearing, Ms. Hull also clarified that the actual design of the constructed
Poundmaker feeders project, that includes the larger ductline feeder capacity and changes to the
two existing feeders, was not “Alternative 2” from the 2012 business case for this project that
EDTI had rejected as being too risky in its 2012 GTA.400
411. Finally, EDTI pointed out that the 2012 approved forecast capital additions amounts for
this project reflected the 2012 compliance filing amount rather than the originally filed 2012
forecast amount. EDTI indicated that the 2012 decision amount was $0.91 million lower than the
forecast for this project included in EDTI’s 2012 application.
412. Because the Poundmaker Feeders project was completed and put into service in 2013,
there are no capital additions associated with this project in either 2014 or 2015. In the 2014-
2015 capital tracker forecast application, EDTI indicated that it applied for capital tracker
treatment for this project because in 2014 and 2015, the revenue provided under the I-X
mechanism is not sufficient to recover the entire revenue requirement associated with the prudent
capital expenditures for this project.
413. EDTI maintained that this project is required to provide utility service at adequate levels.
EDTI further submitted that this capital project could not have been undertaken in the past as
part of a prudent capital maintenance and replacement program. Constructing new feeders as
required to meet load growth on EDTI’s system is not an activity that could have been included
in a prudent capital maintenance program in the past.401
Commission findings
414. The Poundmaker Feeders project was approved by the Commission in Decision 2012-
272. In Decision 2013-435, the Commission determined that this project was required to
maintain service reliability and safety at adequate levels in 2013. Further, the Commission
determined that the scope, level, timing and forecast costs for this project were reasonable as
proposed for 2013. Accordingly, the Commission found that this project satisfied the project
assessment requirement of Criterion 1.402
415. With respect to the true-up of 2013 actual costs, as noted in Section 3, if there is no
evidence on the record of the true-up proceeding demonstrating that a project is not required,
then there is no need to demonstrate that a project is needed in order to provide utility service at
adequate levels, which constitutes the assessment of need under Criterion 1. The Commission
finds no evidence on the record of Proceeding 3216 to indicate that the Poundmaker Feeders
project was not required in 2013.
416. Regarding the scope, level and timing of this project carried out in 2013, the Commission
observes that the Poundmaker Feeders project is an example of EDTI’s Category 3 projects. As
398
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 357. 399
Transcript, Volume 3, pages 463-464 and pages 467-468 (Ms. Hull). 400
Transcript, Volume 4, pages 558-559 (Ms. Hull). 401
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 341. 402
Decision 2013-435, paragraph 935.
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explained in Decision 2013-435, capital additions were forecast to be $0 in 2013 because the
capital additions requiring capital tracker treatment were expected to be made in 2012.403
However, EDTI indicated that while the majority of this project was completed and put into
service in 2012, some small capital additions were also made in 2011 and in 2013.404
417. The total actual capital addition for this project was $11.47 million, which is $4.24
million higher than the forecast amount of $7.23 million approved in Decision 2012-272, with
respect to EDTI’s 2012 GTA. Because the 2011 and 2012 actual capital additions for the project
should be used in the determination of the revenue requirement component of the accounting test
for 2013 and subsequent years, for purposes of the K factor calculations,405 the Commission
needs to assess the prudency of EDTI’s total capital additions of $11.47 million for this project,
spanning the years 2011, 2012 and 2013.
418. EDTI explained that the majority of the $4.24 million increase was primarily made up of
higher than forecast costs associated with the construction of the ductline component of the
project. In this regard, the Commission accepts EDTI’s explanations,406 supplemented with Ms.
Hull’s oral testimony,407 on how poor soil conditions resulted in significant design modifications
being made to ensure the structural integrity of the ductline, leading to the actual construction
costs being $1.0 million higher than forecast.
419. The Commission also accepts EDTI’s explanation that construction complexities related
to the Poundmaker site, such as poor soil conditions, more difficult construction site access, and
special site safety requirements associated with carrying out ductline construction directly
underneath energized transmission lines, resulted in actual costs related to civil contractors being
$1.72 million higher than forecast. The Commission agrees with EDTI’s explanations that,
because of the specialized and sporadic nature of the type of civil construction work required for
the Poundmaker Feeders project that led to the increased costs, such as construction of long
length distribution feeder duct lines, including horizontal directional drilling sections, developing
these skills and acquiring the specialized equipment in-house is likely to be more expensive than
using available external contractors that complete this work on a regular basis and have the
necessary equipment.408 Because EDTI had competitively procured contracted services for the
ductline construction and horizontal directional drilling required for the project, the resulting
contractor costs are likely to be reflective of the market rate at the time and, therefore, are
reasonable.
420. For similar reasons, the Commission finds EDTI’s 2013 actual capital additions for this
project to be reasonable. EDTI indicated that it issued an RFP that included the site restoration,
civil works and road construction work required to complete this project in 2013. EDTI chose the
contractor with the lowest bid that could meet the project schedule and who had significant
experience completing similar work.409
403
Decision 2013-435, paragraph 932. 404
Proceeding 3216, Exhibit 1, 2013 true-up application, Table 3.1.13-3 on page 111. 405
Proceeding 2131, Exhibit 284.01, paragraphs 13-14. AUC letter in response to the ATCO companies request for
clarification on matters related to Decision 2013-435, December 23, 2013. 406
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 356. 407
Transcript, Volume 3, pages 463-464 and pages 468-469 (Ms. Hull). 408
Proceeding 3216, Exhibit 54.01, CCA-EDTI-13(d). 409
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 350.
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421. Another component that led to a $0.23 million increase in actual project costs was
EDTI’s decision to increase the ductline feeder capacity from six to eight feeders. EDTI
explained this decision was guided by two considerations:
MR. ELFORD: So there's two factors. The first, of course, is cost. It's substantially
cheaper to add the incremental capacity of that duct line while you're building it, because
you only have to open up roadways and excavate and all these things one time instead of
coming back later to do it again. So the incremental costs of adding it is cheaper.
The other thing with duct lines is there's not always a lot of space in these right-of-ways.
And so when you get -- when you build in these areas, getting that space and having it
there is far better than if you have to come back later and try and build another duct line
adjacent to what you have only to realize there's no space left in the alignment and
suddenly you're going blocks over and around to get to the destination that you ultimately
wanted to get to.410
422. The Commission accepts this explanation. EDTI estimated the cost to add the additional
duct space to be approximately 83 per cent less than if EDTI had to design and construct an
additional ductline in the future.411 Further, during the hearing, Ms. Hull confirmed that there are
no increased operations and maintenance costs associated with installing a 12-way rather than
nine-way ductline.412 Mr. Elford indicated that the ductline itself is presently being used to
provide utility service413 and that the average service life for a ductline for depreciation purposes
is 50 years, allowing it to serve future customers as load grows in the area.414
423. In light of these considerations and given that the resulting incremental costs of $0.23
million represent approximately two per cent of the total project cost, the Commission finds
EDTI’s decision to increase the capacity of the duct bank to be prudent and the resulting cost to
be reasonable.
424. An additional factor leading to a $0.38 million increase in project costs resulted from a
design change of a project component involving intercepting two existing West Edmonton
substation feeders and re-routing them to the Poundmaker substation via the ductline. As EDTI
explained, these design changes resulted from consultation with Alberta Infrastructure, where
EDTI was required to ensure the installations would not interfere with the proposed long term
plan for expansion of Anthony Henday Drive in this area.415 The Commission finds the design
modification for this component of the project and the resulting cost to be reasonable.
425. For the reasons above, the Commission finds that the actual scope, level and timing of the
work in 2011-2013 for the Poundmaker Feeders project is prudent. The Commission has also
reviewed the costs of the actual capital additions for this capital tracker project in light of the
evidence supporting these costs, the associated procurement and construction practices and the
evidence explaining the differences between approved forecast and actual costs, and finds the
actual costs in each of 2011, 2012 and 2013 to be prudent.
410
Transcript, Volume 3, page 442, lines 9-23 (Mr. Elford). 411
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 357. 412
Transcript, Volume 3, page 452, lines 5-6 (Ms. Hull). 413
Transcript, Volume 3, page 451, lines 21-22 (Mr. Elford). 414
Transcript, Volume 3, page 454, lines 3-10 (Mr. Elford). 415
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 357 and Transcript, Volume 3, pages 463-464
and pages 467-468 (Ms. Hull).
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426. EDTI requested capital tracker treatment for this project in 2014 and 2015. As noted in
Section 3, where a project or program is part of an ongoing multi-year program, or if a project or
program is of an annual recurring nature that has been previously approved by the Commission
for capital tracker treatment, in the absence of evidence that the ongoing or recurring project or
program is no longer required, the Commission will not undertake a reassessment of need under
Criterion 1. The Commission finds no evidence on the record of Proceeding 3100 to indicate that
the Poundmaker Feeders project is not required to maintain service reliability and safety at
adequate levels. In this regard, the Commission notes that during the hearing, Mr. Shymanski
supported capital tracker treatment for this project.416
427. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission observes that the Poundmaker feeders project is an example of EDTI’s
“Category 3” projects. As such, capital additions were forecast to be $0 in 2014 and 2015
because the capital additions requiring capital tracker treatment were made in 2011-2013.
428. Category 3 projects would receive capital tracker treatment when the revenue provided
under the I-X mechanism is not sufficient to recover the entire revenue requirement associated
with the prudent capital expenditures for this project. EDTI’s calculated revenue shortfall for the
Poundmaker Feeders project in 2014 and 2015 is based on the 2011-2013 actual capital additions
for this project, which the Commission found to be prudent earlier in this section. Accordingly,
the Commission finds that this project satisfies the project assessment requirement of Criterion 1.
7.3 New capital trackers
429. This section deals with EDTI’s projects or programs that have not been previously
approved for capital tracker treatment. For such projects, the Commission determined that, as
part of project assessment, the applicant must demonstrate that a project proposed for capital
tracker treatment is (i) required to provide utility service at adequate levels and, if so, (ii) the
scope, level and timing of the project are prudent, and the forecast or actual costs of the project
are reasonable.417
7.3.1 OMS/DMS Life Cycle Replacement
430. This ongoing project consists of replacing the entirety of EDTI’s obsolete systems and
technology used in its Control Operations Centre.418 EDTI explained that its staff currently uses
an obsolete outage tracking system and “mimic board.” EDTI submitted that a new industry-
standard electronic Outage Management System (OMS) and Distribution Management System
(DMS) are necessary to ensure that it is able to operate its systems in a safe, reliable and efficient
manner. EDTI added that “the capital expenditures associated with this project are required to
prevent deterioration in service quality and safety, and service quality and safety cannot be
maintained by continuing with O&M and capital spending levels that are not substantially
different from historic levels.”419
431. EDTI noted that this project was included in its 2013 capital tracker forecast application
as a zero K factor and the scope has not changed since that time.420 EDTI provided a business
416
Transcript, Volume 5, page 797, lines 24-25 (Mr. Shymanski). 417
Decision 2013-435, paragraph 278. 418
Proceeding 3100, Exhibit 50, Appendix A-13, paragraph 1. 419
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 357. 420
Proceeding 3100, Exhibit 50, Appendix A-13, paragraph 2.
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case and an engineering study for the OMS/DMS Life Cycle Replacement project in
Appendix A-13 of the 2014-2015 capital tracker forecast application.
432. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner.421 EDTI maintained that this project is required for EDTI to meet its
obligations to provide safe and reliable service.
433. EDTI further explained that the need for replacement of its OMS/DMS is driven by the
existing system becoming obsolete and reaching the end of its useful life.422 EDTI added that not
proceeding with this project would result in a risk of data loss, a decrease in efficiency and safety
in managing its electrical network, and the inability to maintain current system reliability as the
network and system complexity grow.423
434. In the 2014-2015 capital tracker forecast application, EDTI is only seeking capital tracker
treatment for 2015 and has forecast capital additions associated with this project of $9.09 million
in 2015. The OMS/DMS Life Cycle Replacement project began in 2011. However, 2015 is the
first year for which there are capital additions. The total forecast capital additions for this project
are $12.1 million. EDTI explained that the remaining $3.01 million in capital additions for this
project will be incurred in 2016.
435. EDTI’s total forecast capital additions for this project were based on a 2012 RFP, where
EDTI chose three vendors that met its functional, technical, cost, and experience requirements.
EDTI then chose a single vendor after reviewing similar systems the vendor had installed and
considering all the relevant technical and cost factors. In analysing the costs, EDTI examined the
total cost of ownership, including implementation, software purchase and ongoing
maintenance.424
436. When EDTI brought the OMS/DMS project forward as a “zero K factor” capital tracker
in its 2013 forecast application, the project’s total forecast capital additions were $10.22 million.
The increase in forecast capital additions between the 2013 forecast application of $10.22 million
and forecast capital additions in the 2014-2015 capital tracker forecast application of $12.1
million is due to changes required by EDTI to update its data maintenance business processes so
they are compatible with its new OMS/DMS system.425 The forecast capital additions required to
complete these changes are $1.90 million.426 EDTI outlined the steps it has taken, or will take, to
minimize project costs.427
437. The 2015 forecast capital additions for this project represent the portion of total forecast
capital expenditures being added to rate base in 2015. This $9.09 million in forecast capital
additions for 2015 reflects actual annual capital expenditures of $0.09 million in 2011,
$0.65 million in 2012, $0.09 million in 2013, and forecast annual capital expenditures of
421
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 348. 422
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 360. 423
Proceeding 3100, Exhibit 50, Appendix A-13, paragraph 20. 424
Proceeding 3100, Exhibit 50, Appendix A-13, paragraph 9. 425
Proceeding 3100, Exhibit 50, Appendix A-13, paragraphs 12-13. 426
Proceeding 3100, Exhibit 50, Appendix A-13, Table 3.2-1. 427
Proceeding 3100, Exhibit 50, Appendix A-13, paragraph 30.
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$5.31 million in 2014 and $2.95 million in 2015.428 Capital expenditures in the years 2015 have
not been reflected in EDTI’s rate base prior to 2015 because the capital was not yet required for
the provision of utility service and was recorded as construction work in progress (CWIP).
438. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because the project is
replacing an old technology that is obsolete and the “evolving technology” was not previously
available.429
439. In an IR response to the Commission, EDTI explained the term “evolving technology”
and why it was not previously available:
The evolving technology that makes this project possible is the development and
availability of commercial, industry proven OMS/DMS software systems that fully
integrate with EDTI’s existing GIS [Geographic Information System] and SCADA
[supervisory control and data acquisition] systems. The OMS/DMS system will allow for
complete system visibility across EDTI’s service area and will automate EDTI’s
switching order creation process. As well, it will automate much of EDTI’s existing
manually driven emergency preparedness and response systems and provide information
to support more efficient crew dispatch. This system will serve as a scalable foundation
for intelligent device (automated switch) management in the future.430
440. During the hearing, Mr. Elford further discussed the timing of the OMS/DMS project
with Commission counsel:
Q. Can you advise when this evolving technology became available?
A. MR. ELFORD: Not specifically. These systems have evolved over time, and part of it
is we are now a place where the technology is -- it's fairly mature. We have the necessary
GIS system in place now that will allow us implement a system like this, and the current
systems we were using are well past the end of their lives. This is the right time to do it,
and the technology is available in the market to purchase a vendor-supplied system.
There's are always been vendor-supplied systems. This is the right time for us to do it.
Q. So if I can just clarify, sir. The reason for moving to this technology now, is the right
time for EDTI, or was it in fact available earlier to you?
A. MR. ELFORD: Different versions would have been available to us earlier. So OMS
systems have been around for a number of years, but systems like the OMS/DMS that
will integrate with our GIS, which we had to get in place prior to making this
implementation to give us what we needed. I've just -- sort of the integrated systems have
only come out in the last several years at a mature level.431
Commission findings
441. EDTI requested capital tracker treatment for the OMS/DMS project in 2015. EDTI did
apply for capital tracker treatment for this project in 2013 as a zero K factor, given there were no
capital additions in 2013 associated with this project. In Decision 2013-435, the Commission
found the following with respect to EDTI’s zero K factor projects:
428
Proceeding 3100, Exhibit 50, Appendix A-13, Table 3.1-2. 429
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 358. 430
Proceeding 3100, Exhibit 93.01, AUC-EDTI-22(c). 431
Transcript, Volume 3, pages 472-475 (Mr. Elford).
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Accordingly, EPCOR’s proposed zero K factors are denied. However, the Commission is
making no ruling on EPCOR’s business cases associated with zero K factors. EPCOR is
not precluded from applying for capital tracker treatment for these projects in the year
when the capital additions are expected to occur.
442. The Commission has reviewed the business case and engineering study provided by
EDTI and the evidence on the record of Proceeding 3100 with respect to EDTI’s OMS/DMS life
and finds that the information provided by EDTI supports a finding that the project is required
during the 2015 forecast period to maintain service reliability and safety at adequate levels.
443. With respect to the scope, level and timing of this project for 2015, the Commission has
reviewed the business case and the relevant portions of the record for this project and finds the
forecast scope, level and timing of the project for 2015 to be reasonable. EDTI’s forecast capital
additions associated with this project are $9.09 million in 2015. The Commission has reviewed
the information supporting EDTI’s forecasts and finds the total annual cost forecast to be
reasonable on the basis of the forecast methodology described in the business case for this
project.432
444. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the OMS/DMS project are reasonable
as proposed for 2014 and 2015. Accordingly, the Commission finds that this project satisfies the
project assessment requirement of Criterion 1.
7.3.2 Capitalized Aerial System Damage
445. This ongoing project consists of repairs to EDTI’s aerial distribution facilities that have
been damaged or that have failed or are about to fail.433 EDTI explained that this project is
required to maintain the safety and reliability of its distribution system. EDTI pointed out that
this project was previously approved in Decision 2010-505434 and Decision 2012-272 dealing
with its 2010-2011 and 2012 GTAs, respectively.435 EDTI provided a business case and an
engineering study for the Capitalized Aerial System Damage project in Appendix A-14 of the
2014-2015 capital tracker forecast application.
446. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI as the
owner of an electric distribution system is obligated to operate and maintain its system in a safe
and reliable manner.436 Given these statutory responsibilities, EDTI is obligated to repair or
replace failed or damaged aerial facilities in a timely manner to maintain the safety and
reliability of its system. Failure to replace such facilities can lead to power outages for
customers, and can create safety hazards for both EDTI’s personnel and the general public.
447. EDTI further explained that the need for replacement is identified through its
underground inspection program and damage reports from other parties. The primary drivers
behind the need to replace failed or damaged aerial distribution facilities and the resulting capital
432
Proceeding 3100, Exhibit 50, Appendix A-13, paragraphs 5-13 and 25-27. 433
Proceeding 3100, Exhibit 51, Appendix A-14, paragraph 1. 434
Decision 2010-505: EPCOR Distribution & Transmission Inc., 2010-2011 Phase I Distribution Tariff,
2010-2011 Transmission Facility Owner Tariff, Application No. 1605759, Proceeding ID. 437, October 28,
2010. 435
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 364. 436
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 365.
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expenditures include such causes as weather-related forces, vehicle collisions, vandalism,
wildlife contacts, and deterioration caused by aging.437
448. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $1.41 million in 2014 and $1.50 million in 2015. According to
EDTI, the volume of capitalized aerial system damage replacements is related to factors beyond
its control and, therefore, varies from year to year.438 As such, EDTI’s 2014 and 2015 forecast
capital expenditures for this project were based on a normalized three-year average (2011-2013)
of historical actual annual costs.439
449. EDTI provided details of its normalized three-year average forecasting methodology for
this project in response to AUC-EDTI-23.440 The $0.09 million increase in capital additions from
2014 forecast to 2015 forecast is due to expected inflation of the project’s cost components, as
reflected in the 2011 to 2013 normalized average method used to develop the forecast.441
450. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because the need for repair
arises as damage and system failures occur on EDTI’s system. As such, by their nature, capital
additions for this project are not associated with activities that could have been included in a
prudent capital maintenance program in the past.442
Commission findings
451. EDTI requested capital tracker treatment for the Capitalized Aerial System Damage
project for 2014 and 2015. EDTI did not apply for capital tracker treatment for this project in
2013. However, EDTI continued with this activity in that year.443 Further, the project was
previously approved by the Commission in Decision 2010-505 and Decision 2012-272, dealing
with EDTI’s 2010-2011 and 2012 GTAs, respectively.
452. The Commission has reviewed the business case and engineering study provided by
EDTI and the evidence on the record of Proceeding 3100 with respect to EDTI’s Capitalized
Aerial System Damage project and finds that the information provided by EDTI supports a
finding that the project is required during the 2014-2015 forecast period to maintain service
reliability and safety at adequate levels. In this regard, the Commission notes that during the
hearing, Mr. Shymanski supported capital tracker treatment for this project “because it’s related
to damage.”444
453. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 are
reasonable. EDTI’s forecast capital additions associated with this project are $1.41 million in
2014 and $1.50 million in 2015. The Commission found EDTI’s normalized three-year average
437
Proceeding 3100, Exhibit 51, Appendix A-14, paragraph 3. 438
Proceeding 3100, Exhibit 51, Appendix A-14, paragraph 4. 439
Proceeding 3100, Exhibit 51, Appendix A-14, paragraph 11. 440
Proceeding 3100, Exhibit 93.01, AUC-EDTI-23. 441
Proceeding 3100, Exhibit 51, Appendix A-14, paragraph 24. 442
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 372. 443
Proceeding 3100, Exhibit 51, Appendix A-14, Table 6.0-1 on page 5. 444
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forecasting methodology to be reasonable in Decision 2012-272.445 The Commission has
reviewed the information supporting EDTI’s forecasts and finds the total annual cost forecast for
this project to be reasonable based on the normalized three-year average of 2011 to 2013
historical actual annual costs.
454. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Capitalized Aerial System Damage
project are reasonable as proposed for 2014 and 2015. Accordingly, the Commission finds that
this project satisfies the project assessment requirement of Criterion 1.
7.3.3 Underground Industrial Distribution (UID) Servicing – Rebates, Acceptance
Inspections & Terminations
455. This ongoing project consists of building new underground 15- and 25-kV primary
cables, switching cubicles, and ancillary equipment in order to connect new industrial lots in
EDTI’s service area to the distribution system. Also included in the UID Servicing project is
work to carry out modifications to correct for double lugging, which EDTI explains consists of
“switching cubicles with two terminations of feeder cables connected to one set of switches.”446
Double lugging configurations no longer meet EDTI’s standards for reliability levels and safe
work practices and, accordingly, EDTI is modifying these configurations. Work to correct
double lugging is carried out by EDTI, when possible, alongside new UID construction.447
456. EDTI submitted that this project is necessary to connect new industrial customers to its
distribution system. EDTI noted that this project was previously approved in Decision
2008125,448 Decision 2010-505, and Decision 2012-272 dealing with its 2007-2009, 2010-2011,
and 2012 GTAs, respectively.449 EDTI provided business cases and engineering studies for the
UID Servicing project in Appendix A-13 of the 2013 capital tracker true-up application and in
Appendix A-15 of the 2014-2015 capital tracker forecast application.
457. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to provide and maintain safe, adequate, and
proper service. Furthermore, under its franchise agreement with the City of Edmonton (City),
EDTI is obligated to provide service to sites within the City. Given these statutory
responsibilities, EDTI is obligated to carry out UID servicing within its service area to facilitate
the supply of electricity to new industrial customers.450
458. The work done on UID servicing is shared between EDTI and the land developer. The
land developer prepares the design for the UID infrastructure, according to EDTI and City of
Edmonton standards, and completes the installation work, while EDTI performs design
oversight, site inspections, and the installation of switching cubicles to connect new subdivisions
445
Decision 2012-272, paragraphs 232-233 446
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 379. 447
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 379. 448
Decision 2008-125: EPCOR Distribution & Transmission Inc., 2007-2009 Distribution Tariff, 2007-2009
Transmission Facility Owners Tariff, Code of Conduct Exemption, Application No. 1558686, Proceeding
ID. 14, December 3, 2008. 449
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 401. 450
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 380-381.
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to the distribution system. EDTI submitted that design alternatives are put forth, when possible,
to ensure a cost effective design choice.451
459. A rebate is paid by EDTI to the land developer based on 80 per cent of the cost of the
installed underground system. The costs for the cables, switching cubicles, cable terminations,
road crossings and trenching used to calculate the rebate are prepared and published by EDTI
annually. The remaining 20 per cent of the UID servicing cost is the developer’s contribution.452
460. This project was not included in EDTI’s 2013 capital tracker application because it did
not meet the materiality threshold. EDTI did, however, state that UID Servicing projects have
previously been approved by the Commission in decisions prior to the implementation of capital
trackers.453 The 2013 forecast costs for the UID Servicing project were based on a three-year
historical average of the number of hectares of UID Servicing completed from 2010 to 2012 and
EDTI’s historical UID project costs and current year cost estimates for engineering, materials,
testing, and commissioning.454
461. EDTI did not apply for capital tracker treatment for the UID Servicing project in 2013 on
a forecast basis. However, in the 2013 capital tracker true-up application, EDTI applied for
capital tracker treatment for this project based on 2013 actual capital additions of $1.40 million.
EDTI explained that the revenue requirement associated with these 2013 capital additions is not
fully funded under the I-X mechanism and passes the materiality threshold. The 2013 forecast
capital additions associated with the UID Servicing project were $1.59 million.455 EDTI
explained the decrease in capital additions from forecast to actuals was the result of fewer
hectares of land being serviced and the installation of fewer switching cubicles and cables.456
462. In an IR response to the Commission, EDTI explained that the UID Servicing project
now exceeds the materiality threshold for capital trackers, despite the fact that actual capital
additions are lower than forecast, as a result of the 2012 total capital additions of $2.65 million
being higher than the $1.47 million approved in Decision 2012-272. EDTI further explained that
the 2012 actual capital additions were $1.18 million higher than forecast due to a higher than
forecasted number of hectares being serviced. In 2012, 56 hectares were forecast to be serviced,
as compared to the 112 hectares that were actually serviced.457 In an IR response to the
Commission, EDTI explained that the large number of hectares serviced in 2012 was driven by
three UID developments whose average size was 27 hectares.458
463. Regarding the prudence of its actual 2013 capital additions, EDTI explained that the
80 per cent rebate of developers’ costs is based on 80 per cent of the costs EDTI would have
incurred had it completed the work itself, not the developers’ actual cost of completing the
451
Proceeding 3100, Exhibit 52, Appendix A-15, paragraphs 5-7. 452
Proceeding 3100, Exhibit 52, Appendix A-15, paragraphs 8-9. 453
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 378. 454
Proceeding 3216, Exhibit 28, Appendix A-13, paragraphs 16-18. 455
Proceeding 3216, Exhibit 28, Appendix A-13, Table 5.0. 456
Proceeding 3216, Exhibit 28, Appendix A-13, paragraph 31. 457
Proceeding 3216, Exhibit 53.01, AUC-EDTI-3(b). 458
Proceeding 3100, Exhibit 93, AUC-EDTI-24(c).
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work.459 EDTI submitted that this treatment for the UID rebates aids in controlling costs and was
approved in Decision 2012-272.460
464. With respect to acceptance inspections, EDTI uses both internal engineers and external
consultants to complete the work. External consultants are used when EDTI’s internal staff does
not have the required expertise. In 2013, EDTI used a single external engineering consultant
whose rates were consistent with a 2012 RFP for engineering design work. EDTI also explained
that inspections are only done when the developer has issued notice of the work being
completed. For the terminations and tie-ins, EDTI uses internal staff and the required work is
carried out only after EDTI’s engineers have approved the installation. The cables, transformers
and switching cubicles used in the UID servicing project were all purchased through RFP
processes. In 2011, a cable provider was selected as the lowest cost provider who could meet the
necessary requirements and was signed to a five-year contract. The switching cubicle provider
was chosen in 2007 as the lowest cost provider for the majority of cubicles used. EDTI noted that
for a number of cubicle types, the costs have decreased between 2007 and 2013.461
465. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $1.30 million in 2014 and $1.33 million in 2015. Consistent
with past applications, EDTI based its 2014 forecast capital expenditures for this project on a
three-year historical average of the number of hectares of UID servicing from 2011 to 2013, in
addition to EDTI’s historical UID project costs and current year cost estimates for engineering,
materials, testing, and commissioning.462 The $0.03 million increase in capital additions from
2014 forecast to 2015 forecast is primarily due to inflation.463
466. At the time of its IR responses to the Commission, EDTI indicated that in 2014 it had
already serviced 57 hectares of land under the UID Servicing project, and was expecting to
service more than 100 hectares throughout 2014.464
467. EDTI explained that there are no feasible alternatives to either the installation of UID
service connections or the correction of double lugging configurations and that the project cannot
be deferred and still allow EDTI to meet its obligations to provide service.465 EDTI also
maintained that a prudent capital maintenance program could not have been undertaken in the
past for this project because the purpose of this this project is to provide service to new industrial
customers.466
Commission findings
468. EDTI requested capital tracker treatment for the UID Servicing project in 2014 and 2015.
EDTI did not apply for capital tracker treatment for this project in its 2013 forecast application.
However, EDTI continued with this activity for that year and is now applying for capital tracker
treatment in 2013 in its true-up application based on the actual capital additions. The project was
459
Proceeding 3100, Exhibit 135.01, EDTI argument, paragraph 164. 460
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 415. 461
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 416-433. 462
Proceeding 3100, Exhibit 52, Appendix A-15, paragraphs 17-19. 463
Proceeding 3100, Exhibit 52, Appendix A-15, paragraph 34. 464
Proceeding 3100, Exhibit 93, AUC-EDTI-24(c). 465
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 381. 466
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 386-387.
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previously approved by the Commission in Decision 2010-505 and Decision 2012-272, dealing
with EDTI’s 2010-2011 and 2012 GTAs, respectively.
469. The Commission has reviewed the business case and engineering study provided by
EDTI and the evidence on the record of Proceeding 3216 with respect to EDTI’s UID Servicing
project and finds that the information provided by EDTI supports a finding that the project was
required to maintain service reliability and safety at adequate levels during 2013, while
connecting new industrial customers to its distribution system.
470. With respect to EDTI’s request for capital tracker treatment for 2013 based on 2013
actual capital additions, the Commission has reviewed the scope, level, and timing of the UID
Servicing project carried out in 2013 and the 2013 actual capital additions of $1.40 million.
Further, the Commission has reviewed the costs of the actual capital additions for this proposed
capital tracker project in light of the evidence supporting these costs, the associated procurement
and construction practices and the evidence explaining the difference between forecast and actual
costs. The Commission finds the actual costs for this project in 2013 to be prudent.
471. EDTI also requested capital tracker treatment for this project in 2014 and 2015. The
Commission finds no evidence on the record of Proceeding 3100 to indicate that the UID
Servicing project is not required for 2014 or 2015. With respect to the scope, level, and timing of
this project for 2014 and 2015, the Commission has reviewed the business case and the relevant
portions of the record for this project and finds the forecast scope, level, and timing of the project
for 2014 and 2015 to be reasonable. EDTI’s forecast capital additions associated with this project
are $1.30 million in 2014 and $1.33 million in 2015. The Commission has reviewed the
information supporting EDTI’s forecasts and finds the total annual forecast to be reasonable
based on the forecast methodology outlined in its business case.467
472. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for EDTI’s UID servicing project are
reasonable as proposed for 2014 and 2015. Accordingly, the Commission finds that this project
satisfies the project assessment requirement of Criterion 1.
7.3.4 Replacement of Faulted Distribution PILC Cables
473. This project is a new proposed capital tracker, as it did not previously meet the
materiality threshold for purposes of previous capital tracker applications. However, EDTI noted
that the project has been previously approved in Decision 2008-125, Decision 2010-505 and
Decision 2012-272.468 EDTI provided business cases and engineering studies for the
Replacement of Faulted Distribution Paper Insulated Led Covered (PILC) Cable project in
Appendix A-16 of the 2014-2015 capital tracker forecast application.
474. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to repair failed
PILC cable in a timely manner to maintain the safety and reliability of its system.469
467
Proceeding 3100, Exhibit 52, Appendix A-15, paragraphs 17-19. 468
Proceeding 3100, Exhibit 80, paragraph 393. 469
Proceeding 3100, Exhibit 53, Appendix A-16, paragraph 11.
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475. EDTI explained in its application that this project consists of the replacement of faulted
distribution PILC cable and cable accessories as cable faults occur.470 EDTI confirmed that its
practices for the replacement of faulted distribution PILC cable in this project are consistent with
standard industry practice, as demonstrated through participation in the Centre for Energy
Advancement through Technical Innovation (CEATI) International Inc., Distribution Assets Life
Cycle Management (DALCM) interest group and discussions with other participating utility
members.471
476. In his evidence, Mr. Shymanski for the UCA indicated the following with respect to
EDTI’s Capital Tools and Instrument Purchases project and the Replacement of Faulted
Distribution PILC Cables project:
I have examined a number of EDTI’s proposed CT projects and have determined that at
least two of them, while slightly above the Tier 1 materiality, should not qualify for CT
status and thus K Factor calculation because EDTI’s forecasts are optimistic. A more
reasonable forecast, based on EDTI’s track record for that project in 2013, would result in
a slightly lower forecast capital addition that would not allow it to qualify for CT status
and thus K Factor inclusion.472
477. The Commission addresses the first part of Mr. Shymanski’s recommendation, that these
projects should not qualify for capital tracker treatment because they are “slightly above the
Tier 1 materiality,” in Section 10 dealing with the Criterion 3 assessment.
478. With respect to forecasting, Mr. Shymanski maintained that the actual historical
expenditures on this project prior to PBR and associated variances between the actual and
forecast numbers should carry less weight when informing the Commission’s judgment than the
2013 variance:
Q. Why [… ] should we reduce the 2014 forecast based solely on the 2013 variance?
A. MR. SHYMANSKI: I would say in my view, that was the first -- well, is the first year
of the PBR, the capital tracker, and from my perspective that was the most relevant.
Q. And why is that?
A. MR. SHYMANSKI: It's a new type of regulation, PBR versus cost of service.
Q. But isn't capital trackers based on cost-of-service regulation?
A. MR. SHYMANSKI: The calculations in part are, but there's a more rigorous
requirement under PBR capital tracker to provide business case, to provide explanations
that didn't exist to that extent under cost of service.
Q. So in your view, then, basically what's gone before PBR should not be relevant in
determining whether the forecasts under PBR are relevant for capital tracker purposes?
A. MR. SHYMANSKI: It would have less weight. I wouldn't say it's irrelevant, but less
weight.473
479. Mr. Shymanski explained that “where you don't have previous capital tracker experience,
you need to look at the prior years to give you some guidance.”474 In the case of the Replacement
of Faulted Distribution PILC Cables project, EDTI did not apply for capital tracker treatment in
470
Proceeding 3100, Exhibit 80, paragraph 392. 471
Proceeding 3100, Exhibit 93.01, AUC-EDTI-10(a). 472
Proceeding 3100, Exhibit 97.02, UCA evidence of Mr. Shymanski, paragraph 74. 473
Transcript, Volume 5, page 806, lines 3-23 (Mr. Shymanski). 474
Transcript, Volume 5, page 812, lines 10-13 (Mr. Shymanski).
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2013 on a forecast basis. Looking at 2008 through 2012, Mr. Shymanski noted that all the
numbers are close to zero in variance, but a variance as small as $40,000 will put this project
below the materiality threshold.475
Table 9. Variance between forecasts and actuals on Replacement of Faulted Distribution PILC Cables 2008-2013 ($ million)476
2008 D
2008 A
2009 A
2009 A
2010 D
2010 A
2011 D
2011 A
2012 D
2012 A
2013 D
2013 A
Capital Additions
0.48 0.33 0.52 0.58 0.29 0.31 0.31 1.30 0.41 0.71 - 0.88
Variance (0.15) 0.06 0.02 0.99 0.30 -
Note: EDTI did not apply for capital tracker treatment of this project in 2013 on a forecast basis. As such, there is no available decision value or variance for 2013.
480. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $0.98 million in 2014 and $1.01 million in 2015.477 Consistent
with past applications, EDTI based its 2014 forecast number of failures for this project on a
three-year historical average.478 EDTI explained that the forecast capital expenditures are based
on the forecast number of failures multiplied by the average cost of replacements and adjusted
for inflation.479
481. EDTI provided details of its three-year historical average forecasting methodology for
this project in response to AUC-EDTI-25. The number of PILC cable failures can vary
significantly from year to year, generally due to non-predictable deterioration in the cable
insulation systems and the lead sheath of the PILC cable, and uncontrollable environmental
conditions such as moisture and temperature. To account for the effects of the year-over-year
fluctuations, the forecast is based on the three-year historical average of failures multiplied by
the three-year average cost of replacement, adjusted for inflation.480
482. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program as the need for this project arises as
cable failures occur on EDTI’s existing PILC cable system.481
Commission findings
483. EDTI requested capital tracker treatment for the Replacement of Faulted Distribution
PILC Cables project in 2014 and 2015. EDTI did not apply for capital tracker treatment for this
project in 2013. However, EDTI continued with this activity in that year. Further, the project was
previously approved by the Commission in Decision 2008-125, Decision 2010-505 and
Decision 2012-272.
475
Transcript, Volume 5, page 809, lines 7-9 (Mr. Shymanski). 476
Proceeding 3100, Exhibit 49, Appendix A-12, paragraph 49, Table 5.0-1. 477
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 394. 478
Proceeding 3100, Exhibit 26, Appendix A-9, paragraph 15. 479
Proceeding 3100, Exhibit 26, Appendix A-9, paragraph 16. 480
Proceeding 3100, Exhibit 93.01, AUC-EDTI-25. 481
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 400.
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484. The Commission has reviewed the business case and engineering study provided by
EDTI and the evidence on the record of Proceeding 3100 with respect to EDTI’s Replacement of
Faulted Distribution PILC Cables project and finds that the information provided by EDTI
supports a finding that the project is required during the 2014-2015 forecast period to maintain
service reliability and safety at adequate levels.
485. Mr. Shymanski expressed his view that this project should be denied capital tracker
treatment482 for the reasons discussed earlier in this section. The Commission finds no further
evidence on the record of Proceeding 3100 to indicate that the Replacement of Faulted
Distribution PILC Cable project is not required to continue in 2014 or 2015.
486. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission does not agree with Mr. Shymanski’s view that the 2013 variance should take
priority over the preceding five years when considering the validity of the 2014 and 2015
forecasts. Although 2013 was the first year of the PBR regime, the treatment of capital
expenditure forecasts for capital tracker projects has generally remained the same as under cost
of service regulation, albeit with more defined filing requirements to support the reasonableness
of the forecast, as set out in Section 10.2 of Decision 2013-435. As the Commission observed in
that decision, “[a]lthough the intent of the PBR plan was to break the link between revenues and
costs, capital trackers would be regulated on a cost-of-service basis, thereby linking revenues and
costs for these expenditures.”483
487. As Table 9 shows, for the period 2008 to 2012, EDTI’s actual capital additions on this
project exceeded the forecasts in three years out of four. Given this history of under-forecasting,
the Commission does not agree with Mr. Shymanski’s concern that EDTI’s forecasts on this
project are optimistic. Further, in the event that EDTI’s actual capital additions on this project
are less than forecast, any necessary adjustments to the K factor amount will be made at the time
of the true-up application.
488. EDTI’s forecast capital additions associated with this project are $0.98 million in 2014
and $1.01 million in 2015. The Commission has reviewed the information supporting EDTI’s
forecasts and finds the total annual cost forecast to be reasonable based on the three-year
historical average.
489. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Replacement of Faulted
Distribution PILC Cables project are reasonable as proposed for 2014 and 2015. Accordingly,
the Commission finds that this project satisfies the project assessment requirement of Criterion 1.
7.3.5 Neighbourhood Renewal program
490. This ongoing program is a continuation of a number of life cycle replacement projects
that contemplate the replacement of a large portion of the electric distribution infrastructure
within identified aging neighbourhoods. This is the first time this program is proposed for capital
tracker treatment. EDTI explained that the program did not previously meet the materiality
threshold for inclusion as a capital tracker.484 EDTI pointed out that this program was approved
482
Transcript, Volume 5, page 798, line 10 (Mr. Shymanski). 483
Decision 2013-435, paragraph 116. 484
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 436.
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in the past in Decision 2010-505 and Decision 2012-272, dealing with its 2010-2011 and
2012 GTAs, respectively.485 EDTI provided business cases and engineering studies for the
neighbourhood renewal program in Appendix A-17 of the 2014-2015 capital tracker forecast
application.
491. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to repair or replace
failed or damaged facilities on its distribution system in a timely manner to maintain the safety
and reliability of its system.
492. EDTI explained in its application that this program consists of rebuilding aging EDTI
distribution facilities in specific neighbourhoods to maintain the reliability of its system and to
protect the public and EDTI workers. Neighbourhoods are reviewed on a case-by-case basis to
determine the scope of work required.
493. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this program to be $0.28 million in 2014 and $2.29 million in 2015.486 EDTI
explained that costs are forecast based on EDTI’s experience in completing similar work of this
type in the past.487 The 2014 forecast included completing work related to its Landsdowne
neighbourhood renewal project, which originally began in 2012.488 Continued scope refinements
allowed EDTI to replace less than what was originally planned for. The remaining work to be
completed in 2014 consists of replacing one cubicle, five padmount transformers with associated
bases and three km of cable.489 This work was originally planned to be completed in 2013, but
EDTI postponed the work in light of the uncertainty related to the approval of its 2013 capital
tracker forecast application.490 “Based upon the asset degradation level of the equipment,
including the level of rust, condition of the deteriorating concrete bases, condition of the locks
and hinges, et cetera,” EDTI decided to delay the replacement of one 200 amp live-front cubicle,
five Type PS live-front padmount transformers with associated concrete bases, and three km of
aged #2 copper primary cable and #4/0 aluminum secondary cable because it expected that it
could delay this work for a short period of time without significantly increasing the risk of
adverse effects on its ability to maintain safe and reliable service.
494. In 2014 and 2015, EDTI explained that it will also complete the initial phases of a
six-year Duggan neighbourhood renewal project. In early 2012, EDTI reviewed the condition of
the underground distribution assets in the Duggan neighbourhood and concluded that it was
“necessary and prudent” to complete a rehabilitation of EDTI facilities in the area. EDTI will
begin the engineering design in 2014.491
495. The 2014 and 2015 program estimates were developed based on the scope of work and
the cost experience from the Lansdowne project. As life cycle replacements are broadly required
485
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 406. 486
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 410. 487
Proceeding 3100, Exhibit 54, Appendix A-17, paragraph 27. 488
Proceeding 3216, Exhibit 1, paragraph 437. 489
Proceeding 3100, Exhibit 54, Appendix A-17, paragraph 7. 490
Proceeding 3100, Exhibit 93.01, AUC-EDTI-26(d). 491
Proceeding 3100, Exhibit 54, Appendix A-17, paragraph 12.
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across entire neighborhoods, EDTI has identified significant benefits associated with the
concurrent replacement of assets.492
496. EDTI indicated that it cannot maintain the service quality and safety of EDTI’s system by
continuing with O&M and capital spending levels that are not substantially different from
historic levels and that the capital expenditures associated with this program are required to
prevent increasing numbers of power failures and avoid deterioration in service quality and
safety.493
497. EDTI explained that prior to 2010, it replaced facilities intermittently and infrequently for
reasons unrelated to the long-term life expectancy of assets. Now EDTI is faced with a
substantial portion of the facilities serving a number of older neighborhoods that are at or past
their anticipated design lives, and are beginning to fail or reach the point of imminent failure.494
Commission findings
498. EDTI requested capital tracker treatment for the Neighbourhood Renewal program in
2014 and 2015. EDTI did not apply for capital tracker treatment for this program in 2013.
However, EDTI continued with this activity in that year.495 Further, the program was previously
approved by the Commission in Decision 2010-505 and Decision 2012-272.
499. The Commission has reviewed the business case and engineering study provided by
EDTI and the evidence on the record of Proceeding 3100 with respect to EDTI’s Neighbourhood
Renewal program and finds that the information provided by EDTI supports a finding that the
program is required during the 2014-2015 forecast period to maintain service reliability and
safety at adequate levels. In this regard, the Commission notes that during the hearing,
Mr. Shymanski supported capital tracker treatment for this program.496
500. With respect to the scope, level and timing of this program for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
program and finds the forecast scope, level and timing of the program for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this program are $0.28 million in
2014 and $2.29 million in 2015. The Commission has reviewed the information supporting
EDTI’s forecasts and finds the total annual cost forecast to be reasonable based on forecasts
derived from EDTI’s experience in completing similar work of this type in the past.
501. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Neighbourhood Renewal program
are reasonable as proposed for 2014 and 2015. Accordingly, the Commission finds that this
program satisfies the project assessment requirement of Criterion 1.
492
Proceeding 3100, Exhibit 54, Appendix A-17, paragraph 15. 493
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 416. 494
Proceeding 3126, Exhibit 53.01, AUC-EDTI-16(b). 495
Proceeding 3100, Exhibit 51, Appendix A-14, Table 6.0-1 on page 5. 496
Transcript, Volume 5, page 798, lines 19-20 (Mr. Shymanski).
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7.3.6 Customer Revenue Metering – Growth & Life Cycle Replacements
502. This ongoing project consists of installing revenue meters at new sites and replacing
meters at existing sites that are no longer compliant with Measurement Canada requirements.497
503. EDTI explained that this project is required to ensure that each site in EDTI’s service
area has an accurate, functional meter that meets the requirements of the Electricity and Gas
Inspection Act and Regulations.498 EDTI noted that this project was not applied for in its 2013
capital tracker forecast application because it did not meet the materiality threshold at that time.
However, EDTI is now applying for capital tracker treatment in the 2013 true-up application.
EDTI pointed out that this project was approved in past Commission Decision 2008-125,
Decision 2010-505 and Decision 2012-272 dealing with its 2007-2009, 2010-2011 and 2012
GTAs, respectively.499 EDTI provided a business case and an engineering study for the Customer
Revenue Metering – Growth & Life Cycle Replacements project in Appendix A-15 of the 2013
capital tracker true-up application and Appendix A-18 of the 2014-2015 capital tracker forecast
application.
504. EDTI explained that from 1988 until 2011, Measurement Canada specification LMB-EG-
04 governed compliance sample testing. In 2011, Measurement Canada introduced a new
compliance specification, S-S-06, which became effective for electronic meters in that year.
Effective in 2014, Measurement Canada specification S-S-06 applies to all electricity meters,
including the older-technology electro-mechanical meters which make up the bulk of EDTI’s
meter population. EDTI submitted that because of the Measurement Canada specification S-S-06
and Bill C-14, the Fairness at the Pumps Act, it expects to replace significantly more meters than
historical levels beginning in 2014. EDTI explained that the Measurement Canada specification
S-S-06 and Bill C-14 increased the number of sample meters pulled for testing, reduced the time
that meters can be left in service for a particular meter group that passed testing, and introduced
financial penalties and sanctions for failed meter groups.500
505. EDTI also stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as
the owner of an electric distribution system, is obligated to operate and maintain its system in a
safe and reliable manner, and to provide and maintain service that is safe, adequate and proper.
Further, EDTI is obligated to provide service to sites within the City of Edmonton under the
terms of its franchise agreement with the City of Edmonton. EDTI further explained that meters
must be installed at sites to provide distribution service and that failure to do so would mean
EDTI is not compliant with these obligations.501
506. Specifically, under Measurement Canada specification S-S-06, EDTI is now required to
test 80 meters for meter lots of up to 500 meters, whereas previously it was required to test only
28 meters. EDTI explained that when a meter is removed for testing, it must be replaced at the
site with a meter from its inventory. EDTI also explained that the new specification resulted in a
larger number of sampling lots due to more stringent grouping criteria, the effect of which is that
EDTI must test more meter lots and replace a greater number of meters. Measurement Canada
specification S-S-06 also contains more stringent evaluating criteria for testing sample meters,
497
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 433. 498
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 420. 499
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 422. 500
Proceeding 3100, Exhibit 51, Appendix A-18, paragraph 2. 501
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 476.
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which EDTI submitted can result in a meter lot that would have previously passed a test now
failing the compliance testing. By way of example, EDTI stated that in 2012, in a sample of 55
meters, two meters found to have an error greater than 2.9 per cent would have resulted in that
meter lot receiving a two year seal extension where it could remain in use before requiring
another sample test. Under Measurement Canada specification S-S-06, that lot would have failed
and would need to be replaced with new meters.502
507. Bill C-14, the Fairness at the Pumps Act, came into force on August 1, 2014. EDTI
explained the Fairness at the Pumps Act introduces financial penalties for inaccurate measuring
devices and allows Measurement Canada to impose penalties based on a number of factors,
including assessing the likelihood that meters fail testing under Measurement Canada
specification S-S-06. EDTI stated that:
As a result, prior to deciding to sample test a meter lot in a given year, EDTI must now
carefully assess whether the lot should, in fact, be sample tested, or should instead be (1)
replaced based on the likelihood that it will fail sample testing and EDTI will be exposed
to the above-mentioned consequences or (2) individually tested (which would require
replacing all of the meters for testing purposes in any event). This increased risk will
result in EDTI being forced to replace a higher number of meters than under the prior
regulatory scheme.503
508. In the 2013 capital tracker true-up application, EDTI applied for capital tracker treatment
for the Customer Revenue Metering – Growth & Life Cycle Replacements project based on 2013
actual capital additions of $4.63 million. EDTI’s 2013 forecast capital additions associated with
this project were $2.15 million. This forecast was not approved by the Commission, as EDTI did
not apply for the capital tracker treatment of this project on a forecast basis in 2013. The variance
between 2013 forecast capital additions and actual capital additions is an increase of
$2.48 million.
509. EDTI explained that the variance was due in part to a $0.95 million increase resulting
from EDTI capitalizing inspection expenses related to new service installations, which EDTI
submitted is “in accordance with the capitalization of such expenses by other electric distribution
utilities in Alberta.”504 EDTI further explained that these inspection costs had been previously
charged to operating accounts. However, new City of Edmonton invoicing practices have made it
possible for EDTI to directly attribute the inspections costs associated with installing meters at
new service locations.505 Further contributing to the variance between 2013 actuals and the
forecast capital additions is $0.74 million increase due to the installation of an additional 1,784
single-phase meters, 1,120 network meters, and 33 new commercial meters, resulting from
stronger than forecast economic growth in Edmonton. EDTI also explained that there was a
$0.78 million increase resulting from the replacement of an additional 3,823 meters, of which
3,615 meters had to be replaced given an unanticipated failure in compliance sample test
results.506
502
Proceeding 3100, Exhibit 51, Appendix A-18, paragraph 11. 503
Proceeding 3100, Exhibit 51, Appendix A-18, paragraph 11. 504
Proceeding 3216, Exhibit 33, Appendix A-15, paragraph 32. 505
Proceeding 3216, Exhibit 33, Appendix A-15, paragraph 32. 506
Proceeding 3216, Exhibit 53.01, AUC-EDTI-18(b).
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510. In 2013, EDTI replaced a total of 8,159 meters at a cost of $1.28 million and installed a
total of 8,804 new meters due to growth at a cost of $2.40 million. The remainder of EDTI’s total
2013 actual capital additions is made up of $0.95 million for the capitalization of inspections.507
EDTI explained that the supplier of its meters was originally designated through a request for
quotations (RFQ) in 2009 for two years, which was later extended until the end of 2014, given
that the supplier has Measurement Canada approved meters and could supply them at a lower
cost than other competitors.508
511. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $4.79 million in 2014 and $4.19 million in 2015.509 EDTI’s
2014 and 2015 forecast capital expenditures for this project were based on the forecast number
of meters to be installed multiplied by the forecast installation cost per meter , which includes the
engineering, labour, materials, and vehicle costs associated with the installation. In 2014, EDTI
forecast the installation of 6,400 new single-phase meters, 6,030 single-phase meter
replacements, 2,100 new network meters, 3,953 network meter replacements, 482 new
commercial meters, and 1,882 commercial meter replacements. In 2015, EDTI forecast the
installation of 6,500 new single-phase meters, 360 single-phase meter replacements, 2,140 new
network meters, 40 network meter replacements, 482 new commercial meters, and 2,363
commercial meter replacements.
512. EDTI explained that its 2015 forecasts assume approval of the AMI project.510 In 2014,
the forecast total capital additions for the Customer Revenue Metering – Growth & Life Cycle
Replacements project are $4.79 million, regardless of whether the AMI project is approved. In
2015, however, if the AMI project is approved, the forecast capital additions for customer
revenue metering are $4.19 million. If the AMI project is not approved, EDTI forecast the 2015
capital additions to be $5.85 million.511
513. The difference arises because, if the AMI project is approved, EDTI will be able to apply
for dispensation from the new Measurement Canada specification S-S-06, given that it would be
replacing existing meters that would otherwise require testing, with new meters as part of the
AMI project. Approval of the AMI project would result in the number of meters that require
testing, as part of the Customer Revenue Metering– Growth & Life Cycle Replacements project,
to be limited to meters that are tested individually and not as part of a larger group, or are
damaged and suspected of failure. If the AMI project is not approved, more meters will require
replacement as a result of sample testing under Measurement Canada specification S-S-06,
which will result in a higher cost.512
514. EDTI provided a further description of its 2014 and 2015 forecast methodology for the
Customer Revenue Metering – Growth & Life Cycle Replacements project in the business case
for this project.513 EDTI indicated that this capital project is not subject to management
507
Proceeding 3216, Exhibit 53.01, AUC-EDTI-18(c). 508
Proceeding 3216, Exhibit 33, Appendix A-15, section 3.4. 509
Proceeding 3100, Exhibit 93.01, AUC-EDTI-1(a). 510
Proceeding 3100, Exhibit 55, Appendix A-18, Table 3.2-1. 511
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 423 and Proceeding 3100, Exhibit
93.01, AUC-EDTI-1(a). 512
Proceeding 3100, Exhibit 55, Appendix A-18, paragraphs 15 and 16. 513
Proceeding 3100, Exhibit 55, Appendix A-18, paragraphs 21-25.
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discretion, cannot be deferred, and is required to be undertaken so that EDTI is in compliance
with Measurement Canada’s requirements.514
Commission findings
515. EDTI requested capital tracker treatment for the Customer Revenue Metering – Growth
& Life Cycle Replacements project in 2014 and 2015. EDTI did not apply for capital tracker
treatment for this project in its 2013 forecast application. However, EDTI continued with this
activity for that year and is now applying for capital tracker treatment in 2013 in its true-up
application based on the actual capital additions. Further, the project was previously approved by
the Commission in Decision 2008-125, Decision 2010-505 and Decision 2012-272, dealing with
EDTI’s 2007-2009, 2010-2011 and 2012 GTAs, respectively.
516. With respect to EDTI’s request in the 2013 capital tracker true-up application for capital
tracker treatment in 2013 for this project on an actual basis, the Commission has reviewed the
business case and engineering study provided by EDTI and the evidence on the record of
Proceeding 3216 and finds that the information provided by EDTI supports a finding that the
project was required in 2013 to maintain service reliability and safety at adequate levels. In this
regard, the Commission notes that during the hearing, Mr. Shymanski supported capital tracker
treatment for this project “because it’s a growth component project.”515
517. The Commission has reviewed the scope, level, and timing of the Customer Revenue
Metering – Growth & Life Cycle Replacements project carried out in 2013 and finds the scope,
level and timing of the work carried out in 2013 to be prudent. Further, the Commission has
reviewed the costs of the actual capital additions for this proposed capital tracker project in light
of the evidence supporting these costs, the associated procurement and construction practices and
the evidence explaining the difference between forecast and actual costs for the 2008 to 2013
period, and finds the actual costs of capital additions of $4.63 million to be prudent.
Accordingly, the Commission finds that this project satisfies the project assessment requirement
of Criterion 1 for 2013.
518. EDTI also requested capital tracker treatment for this project in 2014 and 2015. The
Commission has reviewed the business case and engineering study provided by EDTI and the
evidence on the record and finds that the information provided by EDTI supports a finding that
the project is required during the 2014-2015 period to maintain service reliability and safety at
adequate levels.
519. With respect to the scope, level, and timing of this project for 2014, the Commission has
reviewed the business case and the relevant portions of the record for this project and finds the
forecast scope, level, and timing of the project for 2014 to be reasonable. EDTI’s forecast capital
additions associated with this project are $4.79 million in 2014. The Commission has reviewed
the information supporting EDTI’s forecasts and finds the total annual forecast to be reasonable
based on the forecast number of new meters and meter replacements to be installed in 2014, as
outlined its forecast methodology.516
514
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 432. 515
Transcript, Volume 5, page 799, lines 15 to 18 (Mr. Shymanski). 516
Proceeding 3100, Exhibit 55, Appendix A-18, paragraphs 21-26.
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520. EDTI explained that, unlike in 2014, the forecast scope, level, and timing of the
Customer Revenue Metering – Growth & Life Cycle Replacements project, and the resulting
capital additions in 2015 are dependent on whether EDTI proceeds with the AMI project.517
Specifically, EDTI indicated that, because of the new Measurement Canada specification S-S-06,
if the AMI project is implemented, the forecast capital additions for the Customer Revenue
Metering – Growth & Life Cycle Replacements project are $4.19 million. If the AMI project is
not implemented, EDTI forecast the 2015 capital additions to be $5.85 million.518
521. As set out in Section 11.2, the Commission is making no determination in this decision as
to whether the AMI project qualifies for capital tracker treatment on a forecast basis. The
Commission also states that any requests associated with the customer revenue metering function
as part of a Y, Z or K factor application must be considered in light of its finding that based on
the evidence in the present proceedings, the AMI project represents the least cost alternative for
performing the customer revenue metering function for EDTI.
522. Given EDTI’s evidence that if the AMI project was implemented, the forecast capital
additions for the Customer Revenue Metering – Growth & Life Cycle Replacements project are
$4.19 million for 2015, the Commission is only prepared to approve on a forecast basis, EDTI’s
lower forecast of the 2015 capital additions of $4.19 million associated with this project.
523. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the EDTI’s Customer Revenue
Metering – Growth & Life Cycle Replacements project, as approved by the Commission, are
reasonable as proposed for 2014 and 2015. Accordingly, the Commission finds that this project
satisfies the project assessment requirement of Criterion 1 for 2014 and 2015.
7.3.7 Life Cycle Replacement of Network Transformers
524. This ongoing project consists of replacing aging network transformers installed in
sidewalk vaults on EDTI’s downtown Edmonton secondary network system. EDTI is requesting
capital tracker treatment for this project in 2015. EDTI did not request capital tracker treatment
of this continuing project in 2013 or 2014.
525. EDTI pointed out that this project was previously approved in Decision 2010-505 and
Decision 2012-272 dealing with its 2010-2011 and 2012 GTAs, respectively.519 EDTI provided
a business and engineering study for the network transformer life cycle replacement project in
Appendix A-20 in the 2014-2015 capital tracker forecast application.
526. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner.520 Given these statutory responsibilities, EDTI is obligated to repair or
replace failed or damaged aerial facilities in a timely manner to maintain the safety and
reliability of its system.
517
Proceeding 3100, Exhibit 55, Appendix A-18, Table 3.2-1. 518
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 423, and Exhibit 93.01, AUC-EDTI-
1(a). 519
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 448. 520
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 450.
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527. EDTI further explained that the need for replacement arises when the condition of the
transformer deteriorates to the point where there is a significant risk of the transformer failing.521
The primary drivers of this project are reducing public safety hazards, mitigating the possible
rupture of a tank and release of transformer oil into the environment, and minimizing the
increased potential for prolonged customer outages.522
528. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $0.99 million in 2014 and $3.96 million in 2015. EDTI is only
requesting capital tracker treatment for 2015 because in 2014 the project does not meet the first
tier materiality threshold. In 2015, EDTI is forecasting to replace 10 network transformers at an
average installed unit cost of $0.40 million.523 When asked in an information request whether
EDTI would have been able to replace a more uniform number of transformers in each of 2014
and 2015, rather than the proposed three in 2014 and 10 in 2015, EDTI responded that it did not
forecast having the internal resources to complete more than three replacements in 2014 and that
it was unaware of any contractors that could complete this work.524
529. During the hearing, EDTI explained that the internal resources required to install its
network transformers are split between this project and the LRT relocation projects:
Q. Here EDTI indicated that it would not have the resources in '14 to replace more than
three transformers, but it would have sufficient resources to replace ten in '15. Can you
explain this when you're annually replacing four to six transformers?
A. MS. HULL: Mr. McNulty, it's due to our bottom-up budgeting and our resource
loading. We have significant resources pointed towards the LRT relocations, which are
also working within the network system, and there will be some network transformers
that will be taken care of as part of that project that are being relocated. So due to the
resource loading of those constrained resources, which, more specifically, are network
trades resources, that's why there's three in 2014 and ten in 2015.
…
This project is three transformers, and the forecast for LRT is six transformers in 2014.
For 2015, this project is ten transformers and one transformer for the LRT project in
2015.
Q. So a total of nine in '14 and 11 in '15; is that right?
A. MS. HULL: Yes, for a total of 20 across both projects.525
530. EDTI also indicated that, if it replaced six transformers in 2014 and seven in 2015 as part
of this project, the 2014 K factor amount for this project would still not reach the materiality
threshold and the 2015 K factor amount would still reach the materiality threshold.526
521
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 457. 522
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 456. 523
Proceeding 3100, Exhibit 61, Appendix A-20, Table 3.2-1. 524
Proceeding 3100, Exhibit 93.01, AUC-EDTI-34(c). 525
Transcript, Volume 3, pages 405-406 (Ms. Hull). 526
Transcript, Volume 3, page 407-408 (Ms. Hull).
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531. The average cost per installed unit in 2013 was $0.06 million, and EDTI explained that
the increase from 2013 to 2015 was because different and new types of equipment need to be
installed to comply with the Institute of Electrical and Electronics Engineers (IEEE) guidelines:
EDTI will replace the existing oil switch network transformers and their live
front protectors with a vacuum switch elbow type transformer that has a remote
monitoring device and a dead front protector. The existing transformers have high
voltage oil switches mounted on them, whereas the new transformers will have an elbow
connection and are connected to a vacuum switch by an XLPE cable. In addition a remote
monitoring control panel will be installed above ground outside the vault to allow
operation of the vacuum switch from a safe location. This approach is consistent with the
IEEE C57.108 Guideline for the Protection of Network Transformers.527
532. In an IR response to the Commission, EDTI confirmed that IEEE guidelines C57.104 and
C37.108 are industry standards for the replacement practices of network transformers. When
asked whether the changes in equipment and additional equipment required were driven by IEEE
guidelines, EDTI responded that:
Replacing existing oil switch network transformers with vacuum switch elbow type
network transformers is consistent with IEEE C37.108. However, the use of a dead front
protector, the addition of a remote monitoring device and the secondary disconnect
switch are not discussed in IEEE C37.108 or IEEE C57.104.528
533. EDTI explained that the consequence of not adopting the changes consistent with IEEE
Guidelines is there would be a safety risk associated with completing protector maintenance in
EDTI’s vaults.529
534. EDTI submitted that this capital project could not have been undertaken as part of a
prudent capital maintenance and replacement program. This is because while EDTI does regular
inspections and maintenance, the need for replacement arises when the condition of the
transformer deteriorates to the point where there is a significant risk of failure. EDTI also
explained that it may be uneconomical to complete more maintenance and repair on these
transformers as compared to replacing them.530
Commission findings
535. EDTI requested capital tracker treatment for the Life Cycle Replacement of Network
Transformers project in 2015. EDTI did not apply for capital tracker treatment for this
continuing project in 2013 because it failed to meet the materiality threshold in that
application.531 EDTI is continuing this project in 2014. However, it did not meet the first tier
capital tracker materiality threshold in 2014.
536. The project was previously approved by the Commission in Decision 2010-505 and
Decision 2012-272, dealing with EDTI’s 2010-2011 and 2012 GTAs, respectively. The
Commission has reviewed the business case and engineering study provided by EDTI and the
527
Proceeding 3100, Exhibit 61, Appendix A-20, paragraph 7. 528
Proceeding 3100, Exhibit 93.01, AUC-EDTI-34(b). 529
Proceeding 3100, Exhibit 93.01, AUC-EDTI-34(b). 530
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 457. 531
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 448.
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evidence on the record of Proceeding 3100 with respect to EDTI’s Life Cycle Replacement of
Network Transformers project and finds that the information provided by EDTI supports a
finding that the project is required to maintain service reliability and safety at adequate levels
during 2015. During the hearing, Mr. Shymanski expressed his view that this project should be
denied capital tracker treatment.532 However, Mr. Shymanski did not provide any support for his
position. The Commission finds no further evidence on the record of Proceeding 3100 to indicate
that the Life Cycle Replacement of Network Transformers project is not required in 2015.
537. With respect to the scope, level and timing of this project for 2015, the Commission has
reviewed the business case and the relevant portions of record for this project. The Commission
observes that when the total number of network transformers installed between the Life Cycle
Replacement of Network Transformers project and the LRT Relocations project is considered,
the level and timing of the Life Cycle Replacement of Network Transformers project is similar
for 2014 and 2015. The Commission further notes EDTI’s explanation that if it replaced six
transformers in 2014 and seven in 2015 as part of this project, there would be no effect on the
2014 and 2015 K factor results with respect to satisfying the materiality threshold.533 The
Commission finds the forecast scope, level and timing of the project for 2015 to be prudent.
EDTI’s forecast capital additions associated with this project is $3.96 million in 2015. The
Commission has reviewed the information supporting EDTI’s forecast and notes EDTI’s
explanation that the forecast average cost increase from 2013 to 2015 is based on the forecast
cost for the different and new types of equipment needed to meet Institute of Electrical and
Electronics Engineers (IEEE) guidelines. The Commission finds the total annual cost forecast to
be reasonable.
538. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Life Cycle Replacement of
Network Transformers project are reasonable as proposed for 2015. Accordingly, the
Commission finds that this project satisfies the project assessment requirement of Criterion 1.
7.3.8 Street Light Service Connections and Security Lighting Addition and Capital
Replacement
539. EDTI explained that this project is a new proposed capital tracker because it did not
previously meet the materiality threshold for purposes of capital tracker applications. However,
EDTI noted that the project has been previously approved in Decision 2008-125, Decision
2010 505 and Decision 2012-272.534 EDTI provided business cases and engineering studies for
the Street Light Service Connections and Security Lighting Additions and Capital Replacements
project in Appendix A-21 of the 2014-2015 capital tracker forecast application.
540. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to install necessary
service connections at each site and repair or replace failed assets that are required to supply
electricity to sites in EDTI’s service area.535
532
Transcript, Volume 5, pages 798-799 (Mr. Shymanski). 533
Transcript, Volume 3, pages 407-408 (Ms. Hull). 534
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 464. 535
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 470.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 115
541. EDTI explained in its application that this project consists of ensuring that EDTI’s street
lighting, signal and security lighting customers were provided with adequate, safe and reliable
service connections. Costs included in completing capitalized repairs or additions to EDTI-
owned security lighting systems are also included in this capital tracker.536
542. In its argument, EDTI noted that “neither the UCA nor CCA sought any additional
information with respect to this project in the information request process and neither filed any
written evidence suggesting that this project was inappropriate for capital tracker treatment.”537
543. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $0.68 million in 2014 and $0.69 million in 2015.538 EDTI
explained that the forecast is based on the normalized three-year average of the actual costs
associated with this project from 2011 to 2013 and that the primary costs included in the 2014
and 2015 forecast for this project are costs associated with engineering, construction and the
preparation of as-built drawings of new unmetered service connections or replacement assets.539
544. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program.540 In response to AUC-EDTI-35,
EDTI confirmed that all operation and maintenance costs associated with the lighting project
have been removed from the calculation of the forecast capital tracker amount for this project.541
Commission findings
545. EDTI requested capital tracker treatment for the Street Light Service Connections and
Security Lighting Addition and Capital Replacement project in 2015. EDTI did not apply for
capital tracker treatment for this project in 2013. However, EDTI continued with this activity in
that year.542 EDTI continued this project in 2014. However, it did not meet the first tier capital
tracker materiality threshold for 2014.
546. The project has been previously approved by the Commission in Decision 2008-125,
Decision 2010-505 and Decision 2012-272. The Commission has reviewed the business case and
engineering study provided by EDTI and the evidence on the record of Proceeding 3100 with
respect to EDTI’s Street Light Service Connections and Security Lighting Addition and Capital
Replacement project and finds that the information provided by EDTI supports a finding that the
project is required during the 2014 and 2015 forecast period to maintain service reliability and
safety at adequate levels.
547. The Commission notes that during the hearing, Mr. Shymanski expressed his view that
this project should be denied capital tracker treatment “because it’s a lifecycle replacement.”543
The Commission finds no further evidence on the record of Proceeding 3100 to indicate that the
Street Light Service Connection and Security Lighting Addition and Capital Replacement project
is not required to continue in 2014 or 2015.
536
Proceeding 3216, Exhibit 1, paragraph 462. 537
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 261. 538
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 465. 539
Proceeding 3100, Exhibit 63, Appendix A-21, paragraphs 4 and 14. 540
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 470. 541
Proceeding 3100, Exhibit 93.01, AUC-EDTI-35. 542
Proceeding 3100, Exhibit 51, Appendix A-14, Table 6.0-1 on page 5. 543
Transcript, Volume 5, page 799, lines 1-2 (Mr. Shymanski).
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116 • Decision 3100-D01-2015 (January 25, 2015)
548. With respect to the scope, level and timing of this project for 2014 and 2015, the
Commission has reviewed the business case and the relevant portions of the record for this
project and finds the forecast scope, level and timing of the project for 2014 and 2015 to be
reasonable. EDTI’s forecast capital additions associated with this project are 0.68 million in
2014 and $0.69 million in 2015. The Commission found EDTI’s normalized three-year average
methodology to be reasonable in Decision 2012-272.544 The Commission has reviewed the
information supporting EDTI’s forecasts and finds the total annual cost forecast to be reasonable
based on the normalized three-year average of the actual costs associated with this project from
2011 to 2013.
549. Given the above, the Commission finds that the information provided by EDTI supports a
finding that the scope, level, timing and forecast costs for the Street Light Service Connections
and Security Lighting Addition and Capital Replacement project are reasonable as proposed for
2014 and 2015. Accordingly, the Commission finds that this project satisfies the project
assessment requirement of Criterion 1.
7.3.9 Life Cycle Replacement of PILC Cable Systems
550. This project is a new proposed capital tracker for 2015 related to the life cycle
replacement of underground PILC cable systems on EDTI’s system that have reached the end of
their useful lives. EDTI noted that the Commission reviewed the project as part of the 2013
capital tracker application and found that the project satisfied Criterion 1.545 The project did not,
however, meet the first tier capital tracker materiality threshold.546 The project also fails to meet
the materiality threshold in 2014.
551. EDTI stated that under sections 105 and 127 of the Electric Utilities Act, EDTI, as the
owner of an electric distribution system, is obligated to operate and maintain its system in a safe
and reliable manner. Given these statutory responsibilities, EDTI is obligated to repair or replace
failed or damaged PILC cables in a timely manner to maintain the safety and reliability of its
system.547
552. EDTI explained in its application that this project and capital tracker consists of the life
cycle replacement of PILC cable systems on EDTI’s system that have reached the end of their
useful lives.548 EDTI provided business cases and engineering studies for the Life Cycle
Replacement of PILC Cable Systems project in Appendix A-16-1 of the 2014-2015 capital
tracker forecast application.
553. This project was initiated following EDTI’s review of the significant increase it
experienced in 2011 in the number of customer hours of interruption due to PILC cable system
failures.549 Selection of cables for replacement is based on EDTI’s selection of its worst
performing PILC cables based on cable condition assessments, including cable insulation voltage
withstand testing.550
544
Decision 2012-272, paragraphs 232-233. 545
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 479. 546
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 479. 547
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 478. 548
Proceeding 3100, Exhibit 64, Appendix A-22, paragraph 1. 549
Proceeding 3100, Exhibit 64, Appendix A-22, paragraph 8. 550
Proceeding 3100, Exhibit 64, Appendix A-22, paragraph 6.
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Decision 3100-D01-2015 (January 25, 2015) • 117
554. Mr. Elford supported the need for this new capital program by pointing out the increase
in the failure rate:
We’ve seen -- this year we've seen the highest level of PILC cable failures we’ve seen in
recent history. Pointing to the fact that yes, we were right, we need to do something about
those cables. And we’re doing it as a result, but those are the sorts of things we see. And
so that validates that if we -- here's a segment we said we’d replace and it’s failed.551
555. At the time of the 2013 capital tracker application, EDTI proposed to replace 20 km of
PILC cable between 2013 and 2017. EDTI noted that its assessment of need has not changed and
it still plans to replace 20 km of cable before 2017.552
556. In the 2014-2015 capital tracker forecast application, EDTI forecast capital additions
associated with this project to be $0.42 million in 2014 and $1.70 million in 2015.553 EDTI
explained that 1.6 km, 6.1 km, and 12.3 km of PILC cables are planned for replacement in 2014,
2015, and 2016-2017, respectively, to reach a total of 20 km of PILC cable by 2017.554 Over the
long term, EDTI anticipates that this proactive life cycle replacement program will result in
fewer failures of PILC cables, which EDTI expects will result in lower capital expenditures in
the replacement of faulted distribution PILC cables.555
557. EDTI provided details of its forecasting methodology for this project in response to
AUC-EDTI-25. The Life Cycle Replacement of PILC Cable Systems is a proactive project that
replaces aging PILC cables with poor performance. EDTI forecasts the quantum of customer
hours of interruption with respect to the quantum of PILC cable proposed for replacement each
year, consistent with the method KEMA used to forecast the quantities of XLPE underground
cable.556
558. EDTI indicated that this capital project could not have been undertaken in the past as part
of a prudent capital maintenance and replacement program. This is because once the insulation
of the PILC cable has deteriorated, there is no amount of maintenance that can be carried out to
restore the condition of the insulation.557
Commission findings
559. EDTI requested capital tracker treatment for the Life Cycle Replacement of PILC Cable
Systems project in 2015. This project was reviewed in Decision 2013-435 and found to satisfy
capital tracker Criterion 1.558 However, it did not meet the first tier capital tracker materiality
threshold.559 EDTI continued this project in 2014. However, it did not meet the first tier capital
tracker materiality threshold in 2014.
551
Transcript, Volume 2, page 302, lines 2-8 (Mr. Elford). 552
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 266. 553
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 480. 554
Proceeding 3100, Exhibit 64, Appendix A-22, paragraph 37. 555
Proceeding 3100, Exhibit 64, Appendix A-22, paragraph 38. 556
Proceeding 3100, Exhibit 93.01, AUC-EDTI-25. 557
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 487. 558
Decision 2013-435, paragraphs 867-868. 559
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 479.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
118 • Decision 3100-D01-2015 (January 25, 2015)
560. In Decision 2013-435, the Commission determined that the Life Cycle Replacement of
PILC Cable Systems project was required to maintain service reliability and safety at adequate
levels in 2013. Further, the Commission determined that the scope, level, timing and forecast
costs for this project were reasonable as proposed for 2013. The Commission has reviewed the
business case and engineering study provided by EDTI and the evidence on the record of
Proceeding 3100 with respect to EDTI’s Life Cycle Replacement of PILC Cable Systems project
and finds that the information provided by EDTI supports a finding that the project is required in
2015 to maintain service reliability and safety at adequate levels.
561. The Commission notes that during the hearing, Mr. Shymanski expressed his view that
this project should be denied capital tracker treatment.560 However, Mr. Shymanski did not
provide any support for his position. The Commission finds no further evidence on the record of
Proceeding 3100 to indicate that the life cycle replacement of PILC cable systems project is not
required in 2015.
562. With respect to the scope, level and timing of this project for 2015, the Commission has
reviewed the business case and the relevant portions of the record for this project and finds the
forecast scope, level and timing of the project for 2015 to be reasonable. EDTI’s forecast capital
additions associated with this project are $1.70 million in 2015. The Commission has reviewed
the information supporting EDTI’s forecast and finds the total annual cost forecast to be
reasonable based on the evidence provided.
563. Given the above, the Commission finds that the information provided by EDTI supports
a finding that the scope, level, timing and forecast costs for the Life Cycle Replacement of PILC
Cable Systems project are reasonable as proposed for 2015. Accordingly, the Commission finds
that this project satisfies the project assessment requirement of Criterion 1.
8 Accounting test under Criterion 1 – the project must be outside of the normal
course of the company’s ongoing operations and Commission conclusion on
Criterion 1
8.1 EDTI’s accounting test model
564. As explained in Decision 2013-435, the purpose of the accounting test is to determine
whether a project or program (depending on the approved level of grouping) proposed for capital
tracker treatment is outside the normal course of the company’s ongoing operations. This is
achieved by demonstrating that the associated revenue provided under the I-X mechanism would
not be sufficient to recover the entire revenue requirement associated with the prudent capital
expenditures for the program or project.561
565. In Decision 2013-435, the Commission determined that the accounting test should be
based on a “project net cost approach,” which is sufficient to satisfy the Commission that all of
the forecast or actual expenditures for a capital project are, or a portion is, outside the normal
course of the company’s ongoing operations, as required to satisfy Criterion 1. Under this
approach, the extent to which a project is underfunded by the I-X mechanism is calculated by
comparing the forecast or actual revenue requirement for that project to the going-in revenue
560
Transcript, Volume 5, page 799, lines 12-13 (Mr. Shymanski). 561
Decision 2013-435, paragraphs 149-150.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 119
historically associated with a similar type of capital expenditures escalated by I-X and including
the effect on revenue of any changes in billing determinants.562 The Commission referred to the
latter component, the impact on revenue of any changes in billing determinants, which is
calculated as the forecast percentage change in billing determinants in any given PBR year,
as “Q.”563
566. EDTI submitted that, in both the 2013 capital tracker true-up application and the 2014-
2015 capital tracker forecast application, it has performed the accounting test in accordance with
the methodology set out in Decision 2013-435, which generally involved the following steps:564
Calculate the revenue requirement associated with the forecast capital additions net of
customer contributions for each project or program proposed for capital tracker treatment
in the coming PBR year. The revenue requirement calculations use the mid-year
convention and include the cost of service components set out in paragraph 977 of
Decision 2012-237.
Identify the portion of rate base associated with the going-in rates, for each capital
expenditure category that is similar to a project or program proposed for capital tracker
treatment based on the company’s proposed grouping of projects, and calculate the
amount of the going-in revenue requirement associated with each capital expenditure
category.
Determine the amount of revenue that the I-X mechanism will provide in a PBR year for
a project or program proposed for capital tracker treatment by escalating the calculated
going-in revenue requirement associated with the capital expenditure category similar to
that project or program by the I-X index times Q.
Calculate the portion of the revenue requirement for a project or program proposed for
capital tracker treatment that is not funded under the I-X mechanism in a PBR year by
subtracting the amount provided under the I-X mechanism for that project or program
from the forecast revenue requirement for that project or program for the PBR year.
567. EDTI’s accounting test model for the 2013 capital tracker true-up application was
provided in Schedule 1565 and Schedule 2.566 EDTI’s accounting test model for the 2014-2015
capital tracker forecast application was provided in corrected and revised Schedule 1,567
Schedule 2568 and Schedule 3.569
Commission findings
568. The Commission has reviewed EDTI’s schedules that make up its accounting test
analysis in the 2013 capital tracker true-up application and in the 2014-2015 capital tracker
forecast application and finds these schedules to be reasonable and generally consistent with the
accounting test methodology approved in Decision 2013-435. Subject to the determination of
certain issues discussed in sections 8.2 to 8.4, the Commission is satisfied, in general, that
562
Decision 2013-435, paragraphs 262-263. 563
Decision 2013-435, paragraph 499. 564
Decision 2013-435, paragraphs 497-501. 565
Proceeding 3216, Exhibit 37. 566
Proceeding 3216, Exhibit 38. 567
Proceeding 3100, Exhibit 93.02, AUC-EDTI-01 Attachment 2. 568
Proceeding 3100, Exhibit 93.03, AUC-EDTI-01 Attachment 3. 569
Proceeding 3100, Exhibit 93.04, AUC-EDTI-01 Attachment 4.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
120 • Decision 3100-D01-2015 (January 25, 2015)
EDTI’s accounting test model can be used to demonstrate that all of the forecast or actual
expenditures for a capital project are, or a portion is, outside the normal course of the company’s
ongoing operations, as required to satisfy the accounting test component of Criterion 1.
569. Sections 8.2 to 8.4 deal with issues concerning certain inputs into EDTI’s accounting test;
specifically, the I-X index and Q factor, the weighted average cost of capital (WACC) rate, and
asset service lives. The Commission’s determinations on whether EDTI’s projects or programs
proposed for capital tracker treatment in 2013-2015 satisfy the accounting test and the project
assessment requirement under Criterion 1, are set out in Section 8.5.
8.2 I-X index and Q factor used in the accounting test
570. In the accounting test for the 2013 capital tracker true-up, EDTI used the 2013 I-X index
of 1.71 per cent approved in Decision 2013-072.570 The 2013 Q factor value was 0.54 per cent,
the same value used in EDTI’s 2013 capital tracker forecast application and approved in
Decision 2013-435.571
571. In response to AUC-EDTI-5(a),572 EDTI explained that the 2013 Q factor of 0.54 per cent
was based on the approved 2012 billing determinants and a preliminary forecast of 2013 billing
determinants. The preliminary forecast of the 2013 billing determinants was approved in
Decision 2013-072. In response to AUC-EDTI-5(a), EDTI also indicated that the preliminary
forecast of the 2013 billing determinants exhibited lower site counts than the final 2013 billing
determinants forecast approved in Decision 2013-270.573 According to EDTI’s calculations, the
2013 Q factor would have been 1.46 per cent if the final forecast billing determinants approved
in Decision 2013-270 were used.574
572. In the accounting test for 2014, EDTI used the 2014 I-X index of 1.59 per cent approved
in Decision 2013-462.575 In the accounting test for 2015, EDTI used an I factor value of
2.70 per cent. This value was calculated using the method approved in Decision 2012-237, and
based on Dr. David Ryan’s 2014 to 2015 inflation forecasts.576
573. The 2014 Q factor of 1.96 per cent was based on EDTI’s final forecast of 2013 billing
determinants and final forecast of 2014 billing determinants. The 2014 billing determinants
forecast was approved in Decision 2013-462. The 2015 Q factor of 0.64 per cent was based on
the final forecast of the 2014 billing determinants and a preliminary forecast of the 2015 billing
determinants.577
570
Decision 2013-072: 2012 Performance-Based Regulation Compliance Filings AltaGas Utilities Inc., ATCO
Electric Ltd., ATCO Gas and Pipelines Ltd., EPCOR Distribution & Transmission Inc. and FortisAlberta Inc.,
Application No. 1608826, Proceeding ID No. 2130, March 4, 2013, paragraph 28. 571
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 29. 572
Proceeding 3100, Exhibit 93.01, AUC-EDTI-5(a). 573
Decision 2013-270: 2012 Performance-Based Regulation Second Compliance Filings AltaGas Utilities Inc.,
ATCO Electric Ltd., ATCO Gas and Pipelines Ltd., EPCOR Distribution & Transmission Inc. and
FortisAlberta Inc., Application No. 1609367, Proceeding ID No. 2477, July 19, 2013. 574
Proceeding 3100, Exhibit 122. 575
Decision 2013-462: EPCOR Distribution & Transmission Inc. 2014 Annual PBR Rate Adjustment Filing,
Application No. 1609912, Proceeding ID No. 2823, December 20, 2013, paragraph 40. 576
Proceeding 3100, Exhibit 68, Appendix E. 577
Proceeding 3100, Exhibit 93.01, AUC-EDTI-5(a).
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 121
574. In AUC-EDTI-5(d), the Commission inquired whether, given that EDTI was required to
estimate the 2015 I factor and Q factor, EDTI would be using the updated I factor and Q factor,
based on the approved 2015 I factor and approved forecast of billing determinants for 2015, in its
2015 capital tracker true-up filing. EDTI responded that, for purposes of regulatory efficiency, it
will not update either the I factor or the Q factor in its 2015 capital tracker true-up filing.578
However, during the hearing, Mr. Baraniecki stated that EDTI would have no objection in
principle to using approved 2015 I factor and Q factor values for purposes of the 2015 capital
tracker true-up application.579
Commission findings
575. Because the 2014-2015 capital tracker forecast application was filed much in advance of
its 2015 annual PBR rate adjustment filing, EDTI did not have the approved I factor nor the
approved forecast of billing determinants, on which the Q factor is based, for 2015. EDTI had to
estimate these values based on its preliminary forecasts for 2015. EDTI was of the view that for
purposes of regulatory efficiency, there is no need to update either the I factor nor the Q factor to
reflect the approved values in its 2015 capital tracker true-up filing.580
576. In support of its view that the preliminary estimate of the 2015 Q factor and, for
consistency, the 2015 I factor should not be updated in the 2015 capital tracker true-up
application to reflect the final approved numbers. EDTI referred to paragraph 477 of Decision
2013-435 where the Commission stated:
477. … the Commission agrees with EPCOR’s view that, given the relatively small
expected impact of the annual change in billing determinants on a company’s revenue,
the revenue offset should be performed on the basis of the forecast, rather than the actual,
change in billing determinants. In Decision 2013-270, the Commission determined that
“any future true-up of base PBR rates and any K, Y and Z factors that do not have a
separate collection rider or mechanism should be dealt with on the basis of forecast rather
than actual usage-per-customer and billing determinants.” As EPCOR pointed out, using
forecast billing determinants will simplify the capital tracker true-up applications.581
[footnotes removed]
577. However, during the hearing, Mr. Baraniecki acknowledged that while the above passage
states that the Q factor should be based on a forecast, rather than the actual, change in billing
determinants, it does not mean that a preliminary forecast can be used in place of a final
approved forecast.582 In the Commission’s view, EDTI’s accounting test for its capital tracker
true-up application for a given year should utilize the approved I-X index and the Q factor based
on the final approved forecast of billing determinants for that year. This is because, unlike
preliminary forecast numbers that are often interim, the final approved forecast numbers are
subject to greater rigour, more fully tested by parties and are used in all of a company’s
applications throughout the year, and not just the capital tracker applications. EDTI did not
object to this approach.583
578
Proceeding 3100, Exhibit 93.01, AUC-EDTI-5(d). 579
Transcript, Volume 2, page 267, lines 15-22 (Mr. Baraniecki). 580
Proceeding 3100, Exhibit 93.01, AUC-EDTI-5(d). 581
Decision 2013-435, paragraph 477. 582
Transcript, Volume 2, page 264, lines 3-14 (Mr. Baraniecki). 583
Transcript, Volume 2, page 267, lines 15-22 (Mr. Baraniecki).
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122 • Decision 3100-D01-2015 (January 25, 2015)
578. EDTI calculated the 2013 Q factor of 0.54 per cent based on the preliminary forecast of
2013 billing determinants approved in Decision 2013-072.584 In its compliance filing to this
decision, the Commission directs EDTI to use the 2013 Q factor of 1.46 per cent585 based on the
final forecast billing determinants approved in Decision 2013-270, for the 2013 capital tracker
true-up accounting test. Similarly, in its future capital tracker true-up applications, the
Commission directs EDTI, to utilize the approved I-X index and the Q factor based on a final
approved billing determinants forecast for that year in the accounting test.
579. Regarding the I-X index and Q factor values used for purposes of capital tracker forecast
applications, the Commission acknowledges that, because these applications are typically filed
before the September 10 date of the annual PBR rate adjustment filing, a company may be
required to estimate the I factor and Q factor for the coming year. In the accounting test for the
2014 capital tracker forecast, EDTI used the approved 2014 I-X index and Q factor values, as
they were known at the time of the application. However, there were no approved values for
2015. Therefore, in the accounting test for 2015, EDTI used the I factor value of 2.70 per cent,
based on Dr. Ryan’s 2014 to 2015 inflation forecasts.586 EDTI’s 2015 Q factor of 0.64 per cent
was based on the final forecast of the 2014 billing determinants and a preliminary forecast of the
2015 billing determinants.587 The Commission accepts, in principle, the use of such forecasting
methods when the final approved numbers are not available.
580. Nevertheless, the Commission observes that, since the filing of EDTI’s 2014-2015 capital
tracker forecast application, the 2015 I-X index and billing determinants forecast have been
approved in Decision 2014-346,588 which deals with EDTI’s 2015 annual PBR rate adjustment
filing. To minimize future true-ups, the Commission directs EDTI, in its compliance filing to this
decision, to use the 2015 I-X index value and the Q factor based on the forecast billing
determinants approved in Decision 2014-346 for purposes of its 2015 capital tracker forecast
accounting test.
8.3 WACC rate
581. As set out in Section 4.4 of Decision 2013-435, the accounting test, as it relates to
revenue calculations, consists of two components. The first component is the revenue provided
under the I-X mechanism for a project or program proposed for capital tracker treatment. The
second component is the revenue requirement calculations based on the forecast or actual capital
additions for that project or program for a given PBR year.
582. In both the 2013 capital tracker true-up application and the 2014-2015 capital tracker
forecast application, EDTI used the WACC rate of 6.96 per cent from its going-in rates in the
first component of the accounting test.589
583. For the second component of the accounting test, in the 2014-2015 capital tracker
forecast application, EDTI used a WACC rate of 6.99 per cent. This rate was based on EDTI’s
584
Proceeding 3100, Exhibit 93.01, AUC-EDTI-5(a). 585
Proceeding 3100, Exhibit 122. 586
Proceeding 3100, Exhibit 68, Appendix E. 587
Proceeding 3100, Exhibit 93.01, AUC-EDTI-5(a). 588
Decision 2014-346: EPCOR Distribution & Transmission Inc. 2015 Annual PBR Rate Adjustment Filing,
Application No. 1610834, Proceeding 3403 December 15, 2014. 589
Transcript, Volume 2, page 267, line 23 to page 268, lines 6-10 (Mr. Baraniecki).
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Decision 3100-D01-2015 (January 25, 2015) • 123
forecast cost of debt at the end of December 2013 of 5.77 per cent, the 2013 ROE placeholder of
8.75 per cent and the 2013 placeholder equity thickness of 41 per cent.590
584. For the purposes of the 2013 capital tracker true-up application, EDTI used the same
6.99 per cent WACC rate. However, EDTI determined that its actual 2013 WACC rate is
6.98 per cent, based on the actual cost of debt of 5.70 per cent, the actual equity thickness of
approximately 42 per cent and an ROE placeholder of 8.75 per cent.591
585. EDTI explained that the 2013 actual WACC rate was determined in April 2014 and EDTI
did not have sufficient time to incorporate the 2013 actual WACC rate into its 2013 capital
tracker true-up application. EDTI proposed to update its 2013 capital tracker true-up accounting
test model to reflect the actual 2013 WACC rate in its compliance filing.
586. In its argument, the CCA observed that EDTI, in its accounting test model, appeared to
use the 2012 WACC to determine the revenue requirement. The CCA also pointed out that the
companies’ WACC assumptions are subject to an ongoing Proceeding 3434592 and stated it will
be arguing in that proceeding that actual debt costs should be utilized for determining the
revenue requirement component of the accounting test.593
587. In a similar vein, EDTI submitted it will put forward its position on WACC assumptions
used in the accounting test and respond to other parties, including the CCA, as necessary in
Proceeding 3434.594
Commission findings
588. As the CCA and EDTI pointed out, the Commission has initiated Proceeding 3434 to
examine the possible use of a consistent set of assumptions with respect to the values comprising
the companies’ respective WACC rates; specifically, debt rates, ROE rates and capital structure,
both on a forecast and actual basis. As part of that proceeding, the Commission will examine
EDTI’s WACC assumptions used in both the 2013 capital tracker true-up and the 2014-2015
capital tracker forecast applications.
589. Accordingly, in its decision in Proceeding 3434, the Commission will assess the
reasonableness of, and the need for any changes to, EDTI’s WACC rates used for its 2013 true-
up and 2014-2015 forecast accounting tests. The Commission expects that a decision in
Proceeding 3434 will be issued in time to allow EDTI to reflect any directed changes to WACC
rates used in the accounting test in its compliance filing to this decision. EDTI is directed to
incorporate into its compliance filing to this decision any changes to 2013, 2014 and 2015
WACC rates directed by the Commission’s decision in Proceeding 3434.
8.4 Asset service lives
590. As explained in paragraph 977 of Decision 2012-237, revenue requirement calculations
under the capital tracker mechanism “will be similar to revenue requirement calculations under
590
Proceeding 3100, Exhibit 123, Table UT-1. 591
Proceeding 3100, Exhibit 123, Table UT-2. 592
Proceeding 3434, Commission-initiated review of assumptions used in the accounting test for capital trackers. 593
Exhibit 136.01, CCA argument, paragraph 2. 594
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 45.
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124 • Decision 3100-D01-2015 (January 25, 2015)
cost of service, except that the calculation will be limited to the depreciation, taxes and return
associated with the incremental rate base for the expenditures that form the capital tracker.”
591. In his evidence for the UCA, Mr. Shymanski took issue with the depreciation component
of EDTI’s return calculations, performed as part of the accounting test. Mr. Shymanski explained
that in calculating the depreciation amount, EDTI uses indicative service lives, whether a
specific account service life or an average of several service lives, when more than one asset
account is used in the calculation.
592. Mr. Shymanski pointed out that in Decision 2012-272, EDTI applied for and received
Commission approval for a change in average service lives for a number of its asset accounts.
These changes were approved on a prospective basis only, with pre-2012 assets retaining the
previously approved average service lives.595 However, in its accounting test, EDTI uses the
same indicative service life for all calculations, whether the assets are pre-2012 or for 2013, 2014
and 2015.
593. In Mr. Shymanski’s view, the service lives used prior to 2012 should be retained for
depreciation expense purposes in determining pre-2012 revenue requirement for capital tracker
purposes, while the revenue requirement calculations for 2013 to 2015 inclusive should use the
new service lives approved in Decision 2012-272.596
594. Regarding the effect of this proposed change, Mr. Shymanski stated he did not prepare a
detailed calculation of the effect because that would require a full scale re-building of EDTI’s
accounting test model. However, Mr. Shymanski did indicate that “a quick calculation shows
that there would be little impact on the resulting K Factor calculations (likely less than
$100,000).”597 Mr. Shymanski did not recommend that EDTI change the calculation for this
application but, rather, he recommended that EDTI be directed to correct the calculations for the
next capital tracker application “to ensure the appropriate Indicative Service Lives are used
(i.e., pre and post 2012) for the calculation of the K factor.”598 The UCA supported this
recommendation in its argument.599
595. In its rebuttal evidence, EDTI did not agree that it should be required to use different
service lives for assets installed pre-2012 as compared to assets installed in 2012 and beyond.
EDTI explained that it calculates the depreciation related to investments in each year using its
approved direct life method (DLM) model. EDTI indicated that Mr. Shymanski’s
recommendation will increase the complexity of EDTI’s accounting test model, which is
inconsistent with PBR Principle 3 that “[a] PBR plan should be easy to understand, implement
and administer and should reduce the regulatory burden over time.” EDTI explained that this
recommendation would make the return calculation under both the first and second components
of the accounting test more complicated.
596. Further, EDTI noted it expects to continue to update its service lives from time to time as
required. As such, over time there will be multiple service lives for each project included in the
595
Decision 2012-272, paragraph 193. 596
Proceeding 3100, Exhibit 97.02, evidence of Mr. Shymanski, paragraphs 91-92. 597
Proceeding 3100, Exhibit 97.02, evidence of Mr. Shymanski, paragraph 94. 598
Proceeding 3100, Exhibit 97.02, evidence of Mr. Shymanski, paragraph 94. 599
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 60.
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accounting test model if Mr. Shymanski’s recommendation was to be adopted, further increasing
the complexity of EDTI’s model.
597. Finally, EDTI compared the difference in service lives for each of its projects between
2011 and 2012 and concluded that there are no significant difference between the service lives in
2011 and 2012 for the vast majority of its projects. Therefore, EDTI speculated that
Mr. Shymanski’s recommendation will have little effect on the K factor amount for the vast
majority of EDTI’s projects.600 During the hearing, Mr. Baraniecki acknowledged that EDTI did
not calculate the actual effect because of the complexity associated with such calculations.
Mr. Baraniecki further elaborated on this issue:
And the reason why we don't think it's going to be a significant difference, or at least an
immaterial difference, is given the […] normalization step that we take in our capital
tracker model where we compare the DLM model, which does use the historical service
lives and the future service lives, based on whatever assets were put in place at that time.
So previous stuff, and then, on a go-forward basis, the new service lives.
And when we compare and adjust the capital tracker funding shortfall model to -- so that
they balance, it's basically caught up there. It's not perfect. We'll admit that that's not a
perfect calculation, but it is -- I guess the Commission termed it last proceeding in the
decision on capital trackers, it was a reasonable approach for determining what the capital
cost was going in as compared to what we'll be receiving through the I minus X
memorandum.601
598. In oral examination, Mr. Shymanski addressed these points. With respect to the alleged
complexity associated with using different service lives for assets installed pre-2012, as
compared to assets installed in 2012 and beyond, Mr. Shymanski stated “I think it’s relatively
easy to do. It’s a creation of one other cell in their spreadsheet, which is pretty large as it sits
right now.”602
599. With respect to the likelihood of using multiple depreciable life changes in EDTI’s
accounting test if new service lives are approved in the future, Mr. Shymanski surmised that the
risk of such an outcome appears to be small given that there has been only one change in EDTI’s
depreciation lives since 2004.603 Mr. Shymanski also referred to EDTI’s testimony that there
were no current plans to commission a new depreciation study.604 Mr. Shymanski agreed,
however, that if there were several instances of service life changes, the administration of his
proposed method would become onerous, because EDTI will have to use multiple service lives
for a given asset class in its accounting test. Mr. Shymanski acknowledged that in a circumstance
of “three or four or five different changes, it does become more complicated …”605
600
Proceeding 3100, Exhibit 107, EDTI rebuttal evidence, pages 26-29. 601
Transcript, Volume 2, pages 194-195 (Mr. Baraniecki). 602
Transcript, Volume 5, page 824, lines 12-14 (Mr. Shymanski). 603
Transcript, Volume 5, page 822, lines 8-17 (Mr. Shymanski). 604
Transcript, Volume 2, page 196, line 20 to page 197, line 2 (Mr. Baraniecki). 605
Transcript, Volume 5, page 822, lines 11-13 (Mr. Shymanski).
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600. During the hearing, Mr. Shymanski also appeared to suggest an alternative methodology
to account for asset service lives:
I would hope that with the next -- with the rebasing, that there would be either a form of
the depreciation study or possibly a view that they can have the service lives for DLM
purposes, have the service lives the same for all of the vintages of assets, in which case
they'd match up.606
601. Based on Mr. Shymanski’s oral testimony, the UCA submitted in its argument that “it
would be appropriate and more in keeping with standard depreciation practice in Alberta, if at
the time of the next depreciation study, EDTI moved to having the service lives the same for all
of the vintages of assets within an asset class, thus eliminating this issue [of having to use
multiple service lives] altogether.”607
Commission findings
602. The Commission has considered the evidence of both Mr. Shymanski and EDTI on this
issue and rejects Mr. Shymanski’s recommendation to use different service lives for assets
installed pre-2012 as compared to assets installed in 2012 and beyond in EDTI’s accounting test,
for the following reasons.
603. First, the Commission agrees with EDTI’s view that Mr. Shymanski’s recommendation
will increase the complexity of EDTI’s accounting test model with little overall effect.
Mr. Shymanski expressed his view that it is “relatively easy to do.”608 However, as EDTI pointed
out, implementing this change would bring additional complexity to both components of the
accounting test for each project (i.e., when calculating revenue provided under the
I-X mechanism and for revenue requirement calculations based on the forecast or actual capital
additions for a project or program proposed for capital tracker treatment in a given PBR year).
The Commission is not persuaded that a resulting impact of “likely less than $100,000”609 on the
K factor calculation justifies the additional complexity.
604. Second, Mr. Shymanski agreed that if there were several instances of service life
changes, the administration of his proposed method could become onerous, because EDTI would
have to use multiple sets of service lives for a given asset class in its accounting test.610
605. Finally, as Mr. Baraniecki explained during the hearing, EDTI’s accounting test model
involves a normalization step that aligns the sum of individual projects’ return and depreciation
with the total return and depreciation calculated under its DLM model for depreciation. Because
EDTI’s DLM model incorporates multiple vintages of assets within an asset class, this
normalization step effectively results in the same outcome as Mr. Shymanski’s recommendation,
although less precisely.611 In an undertaking to the UCA, EDTI confirmed that when more assets
606
Transcript, Volume 5, page 822, lines 18-23 (Mr. Shymanski). 607
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 66. 608
Transcript, Volume 5, page 824, lines 12-14 (Mr. Shymanski). 609
Proceeding 3100, Exhibit 97.02, Evidence of Mr. Shymanski, paragraph 94. 610
Transcript, Volume 5, page 822, lines 11-13 (Mr. Shymanski). 611
Transcript, Volume 2, pages 194-195 (Mr. Baraniecki).
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or capital additions at the new service lives are included in the DLM model, this will not increase
the difference between the results from the two approaches.612
606. The UCA recommended that “at the time of the next depreciation study, EDTI move to
having the service lives the same for all of the vintages of assets within an asset class.”613
Although the Commission sees merit in considering this recommendation in principle, it is
outside the scope of the present proceedings but would be relevant in EDTI’s next application
that includes a depreciation study.
8.5 Commission’s conclusions on Criterion 1
607. In Section 7 of this decision, based on the project assessment under Criterion 1, the
Commission approved the need for each project or program that EDTI proposed for capital
tracker treatment either on an actual basis (for 2013) or on a forecast basis (for 2014 or 2015),
with the exception of the AMI project. The Commission also confirmed the prudency of actual
capital additions for the true up of each of the capital tracker projects or programs in 2013. As
well, the Commission determined that EDTI’s forecast capital expenditures for the proposed
2014-2015 capital tracker projects (with the exception of the AMI project) are reasonable. The
AMI project is discussed in Section 11.
608. In Section 8.1 of this decision, the Commission found the form of EDTI’s accounting test
model to be reasonable and generally consistent with the accounting test methodology approved
in Decision 2013-435. In Section 8.3, the Commission did not accept Mr. Shymanski’s proposal
for EDTI to revise its accounting test model to reflect different service lives for assets installed
pre-2012 as compared to assets installed in 2012 and beyond. However, in Section 8.2, the
Commission directed some changes with respect to EDTI’s accounting test assumptions related
to the I-X index and Q factor values for 2013 and 2015. Also, as noted in Section 8.3, there may
be changes to EDTI’s WACC rate assumptions resulting from Proceeding 3434.
609. Accordingly, although the Commission finds the general form of EDTI’s accounting test
model to be reasonable and consistent with the methodology approved in Decision 2013-435, the
Commission cannot make a determination in this decision as to whether any of EDTI’s projects
or programs proposed for capital tracker treatment in 2013-2015 satisfies the accounting test
requirement of Criterion 1 and accordingly, whether any of EDTI’s projects or programs satisfy
Criterion 1 in its entirety. The Commission directs EDTI, in its compliance filing to this decision,
to revise its accounting test for 2013, as well as for 2014-2015, based on approved final forecast
or actual capital additions and model assumptions and other directions as set out in the previous
sections of this decision.
9 Criterion 2 – ordinarily the project must be for replacement of existing capital
assets or undertaking the project must be required by an external party
610. With respect to Criterion 2, the Commission clarified in Decision 2013-435 that, in
addition to asset replacement projects and projects required by an external party, in principle, a
growth-related project will satisfy the requirements of Criterion 2 where it can be demonstrated
that customer contributions, together with incremental revenues allocated to the project on some
612
Proceeding 3100, Exhibit 120. 613
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 66.
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reasonable basis, when added to the revenue provided under the I-X mechanism, are insufficient
to offset the revenue requirement associated with the project in a PBR year.614 Certain projects
for capital tracker treatment that do not fall into any of the growth-related, asset replacement or
external party related categories might also satisfy Criterion 2 in certain circumstances as
discussed in Section 3.2.4 of Decision 2013-435.615
611. In the 2013 capital tracker true-up application, EDTI expressed its view that the purpose
of the true-up process is to review the prudence of actual capital additions associated with capital
tracker projects completed in a given PBR year and to confirm that these projects were executed
in the most effective manner. According to EDTI, the true-up process for previously approved
capital tracker projects is not intended to be a reassessment of each project under the capital
tracker criteria.616 Therefore, EDTI did not provide any additional evidence on how the 2013
capital tracker projects or programs approved in Decision 2013-435 satisfy the requirements of
Criterion 2.
612. However, EDTI did provide information in support of its proposal that three new projects
proposed for capital tracker treatment in 2013, which were not previously approved by the
Commission, satisfy the requirements of Criterion 2. These projects are the UID Servicing -
Rebates, Acceptance Inspections and Terminations project, Neighbourhood Renewal program
and Customer Revenue Metering – Growth and Life Cycle Replacements project. EDTI also
provided evidence in support of its proposal that its proposed 2014-2015 capital tracker projects
or programs satisfy the requirements of Criterion 2. EDTI assessed each capital tracker project or
program and identified the reasons it considered the project or program satisfied the second
capital tracker criterion.
613. Table 10 below provides a summary of the EDTI evidence with respect to Criterion 2 set
out in the 2014-2015 capital tracker forecast application. For the three capital trackers proposed
for 2013 on an actual basis that have not been previously approved by the Commission,
references to the 2013 capital tracker true-up application were also included.
614
Decision 2013-435, paragraph 309. 615
Decision 2013-435, paragraph 314. 616
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 10.
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Table 10. Applied-for 2013-2015 capital tracker projects or programs and Criterion 2 requirements
Project name Criterion 2
project type
Application paragraph (Proceeding 3100,
Exhibit 80)
Applied-for projects or programs approved for capital tracker treatment in Decision 2013-435
Third-party Driven Relocations External party driven/ replacement 96, 110, 123, 138,
Life Cycle Replacement and Extension of Underground Distribution Cable Replacement 191
New 15-kV and 25-kV Circuit Additions Growth/external party driven 207
New Underground Cable and Aerial Line Reconfigurations and Extensions to Meet Customer Growth
Growth/external party driven 221
Distribution Pole and Aerial Line Life Cycle Replacements Replacement 239
Aerial and Underground Distribution Transformers – New Services and Life Cycle Replacement
Growth/external party driven 253
Capitalized Underground System Damage Replacement 267
Vehicles – Growth and Life Cycle Replacements Replacement 282
New Underground and Aerial Service Connections for Commercial, Industrial, Multi-family and Misc. Customers
Growth/external party driven 296
URD Servicing – Rebates, Acceptance Inspections & Terminations
Growth/external party driven 312
Capital Tools and Instrument Purchases Replacement 327
Poundmaker Feeders Growth 343
Applied-for projects or programs that have not been previously approved for capital tracker treatment
OMS/DMS Life Cycle Replacement Replacement 360
Capitalized Aerial System Damage Replacement 374
UID Servicing – Rebates, Acceptance Inspections & Terminations
Growth/external party driven 389617
Replacement of Faulted Distribution PILC Cables Replacement 402
Neighbourhood Renewal Program Replacement 418618
Customer Revenue Metering – Growth & Life Cycle Replacements
Replacement, also a portion of growth/external party driven 433619
Life Cycle Replacement of Network Transformers Replacement 459
Street Light Service Connections and Security Lighting Addition and Capital Replacement
Growth/external party driven 473
Life Cycle Replacement of PILC Cable Systems Replacement 489
Commission findings
614. As set out in Section 3 of this decision, the Commission determined that for purposes of
the true-up of capital tracker projects or programs previously approved, unless the driver
(replacement of existing assets, external party, growth, other) for the project or program has
changed, there is no need to undertake a reassessment against the Criterion 2 requirements.
615. In the 2013 capital tracker true-up application, EDTI did not provide any additional
evidence on how the 2013 project or programs approved for capital tracker treatment in
617
Proceeding 3216, Exhibit1, 2013 true-up application, paragraph 412. 618
Proceeding 3216, Exhibit1, 2013 true-up application, paragraph 449. 619
Proceeding 3216, Exhibit1, 2013 true-up application, paragraph 478.
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Decision 2013-435 satisfy the requirements of Criterion 2. Upon review of the 2013 actual cost
information and variance explanations, the Commission concludes that the drivers have not
changed for any of EDTI’s projects or programs approved for capital tracker treatment in
Decision 2013-435, so as to warrant a reassessment under Criterion 2. The Commission finds
that these 2013 projects or programs continue to satisfy the requirements of Criterion 2.
616. In subsequent capital tracker true-up applications, the Commission directs EDTI to
address whether the driver for any of the previously approved forecast projects or programs has
changed, so as to warrant a reassessment under Criterion 2. In the event that the driver of the
project or program has changed since the forecast project or program was approved, EDTI is
directed to identify such projects and programs and to provide evidentiary support that each
project or program continues to satisfy the requirements of Criterion 2.
617. The Commission has reviewed the evidence and the reasons provided by EDTI for any
new projects in 2013 not previously approved and for the forecast capital projects for 2014 and
2015 proposed for capital tracker treatment, as summarized in Table 10 above. The Commission
finds that the driver for each of EDTI’s proposed capital tracker projects and programs falls into
one of the following Criterion 2 categories: asset replacement or refurbishment; required by an
external party or growth related. Accordingly, the Commission finds that EDTI’s projects or
programs presented in Table 10 satisfy the requirements of Criterion 2.
618. The Commission requires clarification regarding the Aerial and Underground
Distribution Transformers – New Services and Life Cycle Replacement project. At
paragraph 253 of the 2014-2015 capital tracker forecast application, EDTI indicated that this
project satisfies the Criterion 2 requirements because it is a growth-related project, but also a
project that is required by an external party.620 In the business case for this project, in
Appendix A-7, EDTI indicated that, as part of this project, some of the new transformers are
used for replacement purposes as well:
This project is comprised of the costs associated with new aerial and underground
transformers that are brought into service from EDTI’s inventory. These transformers are
utilized for the replacement of failed transformers or for new installations to service new
sites on EDTI’s system.621
619. Further, in an updated table in response to AUC-EDTI-1(b), EDTI labelled this project as
“Replacement/Growth.”622 The Commission directs EDTI, in its compliance filing to this
decision, to explain whether any part of the Aerial and Underground Distribution Transformers –
New Services and Life Cycle Replacement project, deals with the replacement of existing
transformers and how this may affect the assessment under Criterion 2. In addition, if there are
different drivers for different aspects of this project, EDTI is directed to explain why these assets
have been grouped into a single capital tracker project category.
620
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 253. 621
Proceeding 3100, Exhibit 24, Appendix A-7, paragraph 3. 622
Proceeding 3100, Exhibit 93.02, AUC-EDTI-01 Attachment 1, Table 1.0-1.
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10 Criterion 3 – the project must have a material effect on the company’s finances
620. Section 8 of this decision addressed EDTI’s accounting test, which determines whether
all of the forecast or actual expenditures for a capital project are, or a portion is, outside the
normal course of the company’s ongoing operations, as required to satisfy Criterion 1. This is
established by demonstrating that the associated revenue provided under the I-X mechanism
would not be sufficient to recover the entire revenue requirement associated with the prudent
capital expenditures for the program or project proposed for capital tracker treatment.
621. In accordance with the Commission determinations in Decision 2013-435, the portion of
the revenue requirement for a project or program proposed for capital tracker treatment that is
not funded under the I-X mechanism in a PBR year, calculated as part of the accounting test, is
then assessed against the two-tiered materiality test under Criterion 3. The first tier of the
materiality threshold, a “four basis point threshold,” is applied at a project level (grouped in the
manner approved by the Commission). The second tier of the materiality threshold, a “40 basis
point threshold,” is applied to the aggregate revenue requirement proposed to be recovered by
way of all capital trackers.623
622. In Decision 2013-435, the Commission calculated the four basis point threshold and the
40 basis point threshold based on a respective dollar value of EDTI’s ROE in 2012. The
Commission indicated that in subsequent PBR years, the four basis point threshold and the
40 basis point threshold are to be calculated by escalating the dollar value of a respective amount
in 2012 by I-X.624
623. For 2013, the Commission approved a four basis point threshold of $102,000 and a
40 basis point threshold of $1.017 million for EDTI.625 EDTI used these approved materiality
threshold values in the 2013 capital tracker true-up application to establish that the 2013 capital
tracker projects satisfy the requirements of Criterion 3.626
624. In the 2014-2015 capital tracker forecast application, EDTI calculated the 2014 and 2015
materiality thresholds, following the methodology set out in Decision 2013-435. Specifically,
EDTI calculated the 2014 four basis point threshold of $103,237 by escalating the 2012 amount
by the approved 2013 and 2014 I-X index values. Using the same methodology, EDTI calculated
the 40 basis point threshold to be $1.033 million for 2014.
625. As discussed in Section 8.2, at the time of the 2014-2015 capital tracker forecast
application, EDTI did not have the approved I factor for 2015. As such, EDTI used the I factor
value of 2.70 per cent, based on Dr. Ryan’s 2014 and 2015 inflation forecasts.627 Accordingly,
EDTI’s 2015 four basis point threshold and 40 basis point threshold of $104,918 and $1.049
million, respectively, were based on this I factor estimate.628 EDTI assessed each of its projects or
623
Decision 2013-435, paragraphs 382-385. 624
Decision 2013-435, paragraphs 378 and 384. 625
Decision 2013-435, paragraph 385 and Table 8 on page 88. 626
Proceeding 3216, Exhibit 38, Schedule 2, Tab “3. 2013 K.” 627
Proceeding 3100, Exhibit 68, Appendix E. 628
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 66-70.
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programs proposed for capital tracker treatment in 2014 or 2015 against the respective two-tiered
thresholds for those years and determined it meets the Criterion 3 requirements.629
626. In his evidence, Mr. Shymanski for the UCA indicated the following with respect to
EDTI’s Capital Tools and Instrument Purchases project and the Replacement of Faulted PILC
Cables project:
I have examined a number of EDTI’s proposed CT projects and have determined that at
least two of them, while slightly above the Tier 1 materiality, should not qualify for CT
status and thus K Factor calculation because EDTI’s forecasts are optimistic. A more
reasonable forecast, based on EDTI’s track record for that project in 2013, would result in
a slightly lower forecast capital addition that would not allow it to qualify for CT status
and thus K Factor inclusion.630
627. During the hearing, Mr. Shymanski further explained that his proposal effectively results
in a “buffer zone” around the first tier of the materiality threshold:
But if we look at now a buffer zone, perhaps 5 or 10 percent, that kind of buffer zone,
around the forecast numbers. So if it's $100,000, if it's between 95 and 105, it doesn't get
capital tracker treatment.631
628. In its argument, the UCA interpreted Mr. Shymanski’s position with regards to EDTI’s
Capital Tools and Instrument Purchases project and the Replacement of Faulted PILC Cables
project as follows:
To be clear, the point of Mr. Shymanski’s evidence about these two projects is not that
they should be rejected because they are just over the materiality threshold, but that they
should be rejected because their forecast costs are too high, and if the forecasts costs are
adjusted for reasonableness, the projects will in fact fall below the materiality standard.632
629. EDTI, in its argument, took issue with Mr. Shymanski’s interpretation of the tier one
materiality threshold. According to EDTI, “there is nothing in the Commission’s previous
guidance to remotely support the contention that being slightly above the Tier 1 materiality
threshold is a basis on which a project could be denied Capital Tracker treatment.”633 Further,
EDTI submitted that “Mr. Shymanski’s position in this regard is little more than an inappropriate
attempt to arbitrarily increase the Tier 1 materiality threshold above that conclusively set by the
Commission, so as to exclude Capital Tracker projects that clearly meet the Commission’s
criteria.”634 Therefore, EDTI argued that Mr. Shymanski’s proposal should be rejected.
Commission findings
630. In the 2013 capital tracker true-up application, EDTI used the materiality threshold
values approved in Decision 2013-435. For 2014, EDTI calculated the first and second tier
materiality thresholds by escalating the respective 2012 values by the approved 2013 and 2014
629
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 70; Exhibit 93.03, AUC-EDTI-01
Attachment 3; Exhibit 93.04, AUC-EDTI-01 Attachment 4. 630
Proceeding 3100, Exhibit 97.02, evidence of Mr. Shymanski, paragraph 74. 631
Transcript, Volume 5, page 815, lines 11-14 (Mr. Shymanski). 632
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 55. 633
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 130. 634
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 131.
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I-X index values. The Commission has reviewed EDTI’s calculations and finds the resulting
2014 four basis point threshold of $103,237 and the 40 basis point threshold of $1.033 million to
be reasonable.
631. For 2015, EDTI calculated the first and second tier materiality thresholds by escalating
the respective 2012 values by the approved 2013 and 2014 I-X indexes, and then the estimated
2015 I-X index value. As discussed in Section 8.2, given that EDTI did not have an approved
I factor for 2015 when it filed its 2014-2015 capital tracker forecast application, it used a 2015
I factor estimate based on Dr. Ryan’s forecasts. The Commission accepts, in principle, the use of
such forecasting methods when the final approved numbers are not available.
632. At the same time, consistent with the findings in Section 8.2, the Commission considers
that the calculation of the first and second tier materiality thresholds for purposes of the capital
tracker true-up application for a given year should be based on the approved I-X index for that
year. The Commission directs EDTI to follow this approach in future capital tracker true-up
applications.
633. The Commission observes that, since the filing of EDTI’s 2014-2015 capital tracker
forecast application, the 2015 I-X index had been approved in Decision 2014-136. To minimize
future true-ups, the Commission directs EDTI, in its compliance filing to this decision, to use the
2015 I-X index value of 1.49 per cent approved in Decision 2014-346 to calculate the first and
second tier materiality thresholds for 2015.
634. In his evidence, Mr. Shymanski proposed to deny capital tracker treatment for EDTI’s
Capital Tools and Instrument Purchases project and the Replacement of Faulted PILC Cables
project as being “slightly above the Tier 1 materiality” threshold, effectively advocating to
implement a buffer zone around the established threshold values.635 During the hearing,
Mr. Shymanski recognized that in Decision 2013-435, the Commission approved the two-tier
materiality test under Criterion 3 with no buffer around the established threshold amounts.
Mr. Shymanski suggested consideration of “a buffer zone, perhaps 5 or 10 percent, that kind of
buffer zone, around the forecast numbers.”636
635. The Commission observes that in its argument, the UCA submitted that “the point of
Mr. Shymanski’s evidence about these two projects is not that they should be rejected because
they are just over the materiality threshold, but that they should be rejected because their forecast
costs are too high, and if the forecasts costs are adjusted for reasonableness, the projects will in
fact fall below the materiality standard.”637
636. Consistent with its determinations in Decision 2013-435, the Commission will not
implement a buffer zone around the established threshold amounts for EDTI. With respect to the
UCA’s position that the Capital Tools and Instrument Purchases project and the Replacement of
Faulted PILC Cables project should be rejected because their forecast costs are too high and the
projects will fall below the materiality standard,638 the Commission has addressed the
reasonableness of EDTI’s forecasts for these two projects in 2014 and 2015 as part of the project
assessment under Criterion 1 and found them to be reasonable.
635
Proceeding 3100, Exhibit 97.02, evidence of Mr. Shymanski, paragraph 74. 636
Transcript, Volume 5, page 815, lines 11-14 (Mr. Shymanski). 637
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 55. 638
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 55.
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637. The Commission has reviewed EDTI’s calculations, and is generally satisfied that EDTI
has interpreted the Criterion 3 test properly and has applied the test properly. However, as
discussed earlier in this section, the two-tiered materiality test under Criterion 3 is applied to the
portion of the revenue requirement for a project or program proposed for capital tracker
treatment that is not funded under the I-X mechanism in a PBR year, calculated as part of the
accounting test. In Section 8.5, the Commission directed EDTI, in its compliance filing to this
decision, to revise its accounting test based on approved actual or forecast capital additions and
model assumptions. Accordingly, because EDTI’s accounting test for each of 2013, 2014 and
2015 needs to be revised, the Commission cannot determine in this decision whether any of
EDTI’s projects or programs proposed for capital tracker treatment in the periods from 2013 to
2015 satisfy the materiality test requirement of Criterion 3.
638. Given these findings, the Commission directs EDTI, in its compliance filing to this
decision, to reassess whether each of its projects or programs proposed for capital tracker
treatment in 2013 to 2015, satisfies the two-tiered materiality test requirement of Criterion 3. For
this reassessment, EDTI will use the approved 2013 and 2014 threshold amounts, as well as
revised 2015 threshold amounts, as directed above.
11 Advanced Metering Infrastructure project
11.1 AMI as the solution for customer revenue metering
639. This multi-year project consists of the installation of an Advanced Metering
Infrastructure (AMI) system. EDTI explained that AMI technology will replace currently used
manual processes for reading and energizing or de-energizing meters, enabling more efficient
access to end-user information such as usage, voltage, tamper detection and service
interruption/restoration indication, coupled with the ability to manage remotely such functions as
service connections, service disconnections, load limiting and firmware upgrades.639 EDTI
provided a business case and an engineering study for the AMI project in Appendix A-19 of the
2014-2015 capital tracker forecast application.
640. EDTI proposed to implement this program from 2014 to 2017 in two phases. Phase 1 will
consist of constructing and testing the AMI network infrastructure, including collectors and all
computer hardware and software, and installing approximately 10,000 meters to test the system.
Following the conclusion of phase 1, where EDTI will confirm the successful deployment of the
AMI infrastructure and seamless integration with existing applications, phase 2 will begin. Phase
2 will occur over 2016 and 2017 and will involve replacing the majority of EDTI’s
approximately 360,000 existing meters (composed of a mix of electro-mechanical meters and
electronic automated meter reading (AMR) meters) with AMI meters.640
641. EDTI applied for approval of a similar AMI project as part of its 2010-2011 GTA. In
Decision 2010-505, the Commission did not approve capital expenditures for EDTI’s AMI
project for two reasons: the business case for the project was not well founded641 and the absence
639
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 436. 640
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 437. Proceeding 3100, Exhibit 56,
Appendix A-19, paragraph 21. 641
Decision 2010-505, paragraphs 343-353.
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of a provincial smart grid policy.642 EDTI indicated that it has carefully considered both the AUC
Smart Grid Inquiry Report643 published in June 2011, and Decision 2010-505 as it related to
EDTI’s previously proposed AMI project, to ensure its current proposal aligns with the Smart
Grid Report findings and the relevant findings of the Commission in Decision 2010-505.644
642. Specifically, with respect to a provincial smart grid policy, EDTI pointed out that since
the time of Decision 2010-505, the Alberta Department of Energy released the AUC Smart Grid
Inquiry Report on June 1, 2011. In the announcement letter dated June 1, 2011, from the Minster
of Energy to EDTI, the Minister indicated that “the Government of Alberta does not intend to
implement mandatory requirements for smart meters” and that “this does not preclude utilities
from implementing smart meters on their own initiative.” The letter adds that the “Government
will continue to promote improvements in electricity consumption measurement and the
modernization of Alberta’s electricity grid.”645 In response to a Commission IR, EDTI further
indicated that:
Senior representatives of the [Department of Energy] and EPCOR meet regularly on a
monthly basis to discuss relevant industry topics and to date these discussions have not
resulted in any changes in direction as communicated in the June 1, 2011 letter.646
643. As a result of these developments, EDTI indicated that the Department of Energy has
provided clarity with respect to its policy on mandating smart meter deployment in Alberta and
has reaffirmed its support for improvements in electricity consumption measurement and the
modernization of Alberta’s electricity grid. According to EDTI, its decision to acquire an AMI
system to automate meter reading and associated meter processes is consistent with Government
policy in relation to smart meters.647
644. In addition, EDTI indicated that it has considered the Commission’s findings on the
deficiencies of its 2010 AMI business case set out in Decision 2010-505 and incorporated
changes to its current business case to address the concerns identified in that decision. Among
others, EDTI has included an analysis of the project’s costs and benefits from a revenue
requirement perspective, as well as from a cash flow perspective. EDTI also retained Dr. Ryan to
analyze the project structure, and costs and benefits; and to provide EDTI with his opinion as to a
reasonable inflation escalator. The analysis of the costs and benefits of the AMI project was
limited to those that have a direct effect on EDTI’s revenue requirement, and did not include
effects on other entities affiliated with EDTI. Finally, EDTI compared the life cycle of both
conventional meters and AMI meters within the 20-year analysis period.648
645. In performing the cost-benefit analysis for the AMI project and other alternatives to
perform the customer revenue metering function, EDTI considered the new Measurement
Canada specification S-S-06 that introduces more stringent regulations regarding meter
compliance sample testing and meter replacements, which came into effect January 1, 2014.
As discussed in Section 7.3.6, this new specification increases the number of sample meters to be
642
Decision 2010-505, paragraphs 355-359. 643 Alberta Smart Grid Inquiry, Proceeding ID No. 598, January 31, 2011. 644
Proceeding 3100, Exhibit 56, Appendix A-19, paragraph 3. 645
Proceeding 3100, Exhibit 56, Appendix A-19, paragraph 15. 646
Proceeding 3100, Exhibit 93.01, AUC-EDTI-28(a). 647
Proceeding 3100, Exhibit 56, Appendix A-19, paragraph 11. 648
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 10-11.
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pulled for testing, reduces the time that meters may be left in service for meter groups that pass
testing and introduces provisions for financial penalties for failed meter groups.
646. EDTI indicated that Measurement Canada specification S-S-06 will result in significant
increases in compliance sampling and meter replacement costs for EDTI’s existing meter
population over the next 20 years as the remaining inventory of electromechanical meters
approach the end of their operating lives. EDTI explained that without any measures to mitigate
the impact of Measurement Canada specification S-S-06, the company will incur higher
operating costs (e.g., costs to read meters) and capital costs (e.g., costs to replace meters), all of
which will ultimately be borne by customers through higher rates.649
647. In order to address the impact of Measurement Canada specification S-S-06, EDTI
considered four possible alternatives. The first alternative considered was the status quo, which
would involve the current practice of installing AMR meters to support new growth and
replacement meter needs and which would replace all analog meters over a 20-year period.
Based on EDTI’s analysis, this approach would result in increased costs of compliance with
Measurement Canada specification S-S-06 and customers would not benefit from the automation
of meter reading until all meters have been replaced.650
648. The second alternative was the implementation of an AMR solution using drive-by
technology. This alternative would supplant walking meter readers with vehicles driving through
neighbourhoods. EDTI indicated that under this approach, it would avoid a significant portion of
the meter compliance sampling, testing, and replacement costs that would otherwise be required
during the 20-year analysis period, and customers would benefit from the automation of meter
reading much sooner than under the status quo approach. However, as compared to the AMI
project, there are still a number of drawbacks to this method. For example, customers would not
benefit from cost reductions from automated meter energize and de-energize processes as AMR
meters do not have remote connect/disconnect functionality.651
649. The third alternative was the implementation of AMI. Under this approach, customers
would benefit from the elimination of meter reading costs, a reduction in energization costs, and
a reduction in testing, sampling and replacement costs over 20 years as compared to the status
quo alternative. The drawback to this alternative is that it requires the largest capital investment
of all four options in the near term.652
650. The fourth alternative was the implementation of an AMR solution using a fixed network.
This alternative would replace the majority of EDTI’s current meters. Under this approach,
customers would benefit from the elimination of meter reading costs and a reduction in testing,
sampling and replacement costs over 20 years as compared to the status quo alternative.
However, as compared to the AMI project, there are a number of drawbacks to this alternative.
For example, because the AMR meters only support basic energy measurement, this platform
cannot enable benefits from other smart grid initiatives such as outage management, asset
management, integration to home area networks, and theft management.653
649
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 443. 650
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 42-44. 651
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 46-49. 652
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 53-54. 653
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 109-112.
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651. Consistent with the recommendations in Decision 2010-505, EDTI performed a net
present value (NPV) analysis of the four alternatives from a revenue requirement perspective, as
well as from a cash flow perspective over a 20-year period from 2014 to 2034. Under EDTI’s
NPV net cash flow analysis, the present value of project costs is deducted from the present value
of the expected benefits. Under this analysis, a project with the highest NPV would be selected.
Alternatively, EDTI’s NPV of revenue requirement analysis reflects a reduction in the revenue
requirement and, therefore, the largest negative value would normally be chosen.654 Table 11
below presents the results of EDTI’s NPV project analyses.
Table 11. Net present value analysis of alternatives to AMI ($ million)655
Alternative Net cash flow NPV Revenue requirement reduction NPV
Alternative 1 - Status Quo (26.36) 21.85
Alternative 2 - AMR Drive-by 30.01 (26.88)
Alternative 3 - AMI 36.11 (33.67)
Alternative 4 - AMR Network 32.50 (28.50)
652. With reference to the results reproduced in Table 11, EDTI indicated that the AMI
alternative provides the highest financial benefits and the greatest reduction in revenue
requirement for customers. The status quo (Alternative 1) reflects the capital and operating cost
increases that customers will incur should EDTI continue with its current practice of installing
AMR meters to support growth and replacement needs. Based on the results of this analysis,
EDTI concluded that the implementation of AMI (Alternative 3) is “clearly the superior option
that provides the greatest financial benefit to customers and the best technology platform choice
for the years ahead.”656 In argument, EDTI reiterated that the AMI project “is the best (i.e., most
cost effective) alternative to dealing with the changes in Measurement Canada requirements.”657
653. Specifically, as part of the NPV net cash flow analysis, EDTI indicated that the AMI
project will result in significant long-term capital and operating cost savings (in each of three
operating categories: meter reading, meter operations, and distribution operations) for
customers.658 The bulk of the quantifiable benefits from the AMI project are from operating
savings.659 EDTI’s NPV analysis showed that, after the initial capital investment of $72.9 million,
the AMI has negative net cash flow from 2014-2017. In 2018, the net cash flow becomes
positive in the amount of approximately $10 million annually, until 2034.660 Based on the NPV
of revenue requirement analysis, EDTI indicated that the AMI project will result in small annual
increases to EDTI’s revenue requirement in 2016-2019 (with the maximum annual increase to its
revenue requirement occurring in 2017), after which customers will enjoy substantial and
growing reductions in the revenue requirement each year thereafter.661
654. The interveners asked a number of IRs regarding the assumptions of EDTI’s NPV
analyses; however, they did not argue with EDTI’s conclusion that the AMI project is the least
654
Proceeding 3100, Exhibit 93.01, AUC-EDTI-30(a). 655
Proceeding 3100, Exhibit 93.01, AUC-EDTI-30(a), Table AUC-EDTI-30-1. 656
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 115-116. 657
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 195. 658
Proceeding 3100, Exhibit 56, Appendix A-19, paragraph 68. 659
Proceeding 3100, Exhibit 93.01, AUC-EDTI-30(c). 660
Proceeding 3100, Exhibit 56, Appendix A-19, Table 4.3.1-1 on page 20. 661
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 107-108.
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cost alternative to customer revenue metering in the long term, given among others, the impact
of the new Measurement Canada specification S-S-06.
655. Specifically, in its IRs, the CCA asked questions of EDTI on certain inputs and
assumptions of its models, such as meter prices, installation costs, selection of the 20-year
analysis period, depreciation rates and assumptions as to volumes of meters required.662 In its
argument, when describing the AMI project, the CCA provided highlights of EDTI’s cost-benefit
analysis of the AMI project.663 The CCA concluded that “… on a forecast basis it appears the
project should be approved and all parties, subject to various caveats and levels of enthusiasm
appear to agree.”664
656. In response to a UCA IR, EDTI provided a sensitivity analysis for the AMI project for
such factors as a two per cent escalation rate (rather than 2.9 per cent used by EDTI), cost of
implementation (±10 and 20 per cent), and benefits (±10 and 20 per cent). EDTI maintained that
the AMI project remains of substantial benefit to customers under each scenario postulated by
the UCA.665 The UCA, in its argument, observed that “EDTI has presented evidence that
demonstrates that the AMI project results in the least cost alternative, when the long-term view is
considered.”666
Commission findings
657. EDTI is required to meter the energy it delivers to customers. The federal Electricity and
Gas Inspection Act requires that Measurement Canada approve the meters to be installed for
customer billing. The Act also mandates that meters be tested and maintained in accordance with
regulations.
658. The Commission has considered the evidence of EDTI and other parties and finds that the
current AMI proposal does not suffer from the same drawbacks as the earlier AMI proposal,
which was rejected by the Commission in Decision 2010-505. Specifically, the Commission has
reviewed EDTI’s business case and finds that EDTI has sufficiently addressed the deficiencies
identified by the Commission in Decision 2010-505 and has demonstrated an improved cost-
benefit analysis result for the project.667 Regarding the clarity of a provincial smart grid policy,
the Alberta Department of Energy released the AUC Smart Grid Inquiry Report on June 1, 2011.
Therefore, the Commission agrees with EDTI’s conclusion that its currently “proposed AMI
project is consistent with the findings of the Commission’s Smart Grid Report and the relevant
findings of the Commission in Decision 2010-505.”668
659. While the issue of whether the AMI project qualifies for capital tracker treatment
generated much discussion in the present proceedings, the CCA and the UCA did not object to
the results of EDTI’s cost-benefit analyses (NPV net cash flow analysis and NPV of revenue
requirement analysis). In their respective arguments, the UCA669 and the CCA670 appeared to
662
Proceeding 3100, Exhibit 94.01, CCA-EDTI-32, CCA-EDTI-37, CCA-EDTI-42, CCA-EDTI-44,
CCA-EDTI-48. 663
Proceeding 3100, Exhibit 136.01, CCA argument, paragraphs 65-67. 664
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 90. 665
Proceeding 3100, Exhibit 95.01, UCA-EDTI-26. 666
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 35. 667
Proceeding 3100, Exhibit 56, Appendix A-19, paragraphs 10-11. 668
Proceeding 3100, Exhibit 107, EDTI rebuttal evidence, page 6. 669
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 35.
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accept that the AMI project is the least cost alternative for performing the customer revenue
metering function in the long term.
660. In numerous information requests, the Commission and interested parties explored the
assumptions and inputs to EDTI’s cost-benefit analyses. For example, in response to UCA-
EDTI-26, EDTI provided a sensitivity analysis for the AMI project for such factors as a
two per cent escalation rate (rather than 2.9 per cent used by EDTI), cost of implementation (±10
and 20 per cent), and benefits (±10 and 20 per cent).671 In response to a Commission IR, EDTI
provided a sensitivity analysis with respect to the projected AMI meter failure and out-of-
tolerance rates (±10 per cent), as well as AMI meter purchasing price (in the range
commensurate with the range of obtained meter price quotes).672
661. The Commission has reviewed EDTI’s business case for the AMI project, including the
two NPV analyses, and finds EDTI’s cost-benefit analysis for the AMI project to be reasonable.
Based on the evidence in the present proceedings, the Commission finds that, over the 20-year
period presented in the business case, the AMI project represents the least cost alternative for
performing the customer revenue metering function for EDTI, at this time.
11.2 Utility asset disposition implications on the retirement of existing meters
662. The implementation of the AMI project will result in the wholesale retirement of the
majority of existing electro-mechanical and AMR meters on EDTI’s system. The Commission
queried the company through information requests and at the oral hearing on the implications of
proceeding with the AMI project as proposed in light of Decision 2013-417,673 the Utility Asset
Disposition (UAD) decision. In particular, the Commission identified the issue of whether the
rate base associated with the existing meters should be removed from EDTI’s utility rate base
upon implementation of the AMI program, and moved to a non-utility account for the account of
the company’s shareholder. EDTI estimated the outstanding net book value of the existing meter
assets that would need to be retired, as of the end of 2013, to be approximately $10 million to
$12 million.674
663. At paragraph 327 of the UAD decision, the Commission made the following statement
regarding situations where a utility’s shareholder would be responsible for undepreciated rate
base associated with retired assets:
In order to give effect to the court’s guidance that the “rate-regulation process allows and
compels the Commission to decide what is in the rate base, i.e. what assets (still) are
relevant utility investment on which the rates should give the company a return,” the
Commission directs each of the utilities to review its rate base and confirm in its next
revenue requirement filing that all assets in rate base continue to be used or required to be
used (presently used, reasonably used or likely to be used in the future) to provide utility
services. Accordingly, the utilities are required to confirm that there is no surplus land in
rate base and that there are no depreciable assets in rate base which should be treated as
extraordinary retirements and removed because they are obsolete property, property to be
670
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 90. 671
Proceeding 3100, Exhibit 95.01, UCA-EDTI-26. 672
Proceeding 3100, Exhibit 93.01, AUC-EDTI-32(b). 673
Decision 2013-417: Utility Asset Disposition, Application No. 1566373, Proceeding ID No. 20,
November 26, 2013. 674
Transcript, Volume 4, page 664 (Mr. Baraniecki).
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abandoned, overdeveloped property and more facilities than necessary for future needs,
property used for non-utility purposes, property that should be removed because of
circumstances including unusual casualties (fire, storm, flood, etc.), sudden and complete
obsolescence, or un-expected and permanent shutdown of an entire operating assembly or
plant. As stated above, these types of assets must be retired (removed from rate base) and
moved to a non-utility account because they have become no longer used or required to
be used as the result of causes that were not reasonably assumed to have been anticipated
or contemplated in prior depreciation or amortization provisions. Each utility will also
describe those assets that have been removed from rate base as a result of this exercise.
At this time, the Commission will not require the utilities to make additional filings to
verify the continued operational purpose of utility assets.675 [footnotes removed]
664. The Commission asked EDTI an information request regarding whether the
circumstances of the paragraph above should apply to the circumstances of the wholesale
retirement of EDTI’s existing meters as part of the AMI project and, in particular, whether the
retirement of the existing meters would constitute “sudden and complete obsolescence.” EDTI
responded that it does not consider that the retirement would constitute sudden and complete
obsolescence within the meaning of the UAD decision. EDTI does not consider that the existing
meters should be considered obsolete because they still operate today and remain capable of
operating into the foreseeable future to provide safe and reliable utility service.676
665. In paragraph 327 of Decision 2013-417, the Commission indicated that a relevant
consideration in determining whether a retirement is to be deemed extraordinary and, therefore,
for the account of the utility shareholders, is whether the retirement occurred as a “result of
causes that were not reasonably assumed to have been anticipated or contemplated in prior
depreciation or amortization provisions.” Accordingly, the Commission inquired as to whether
the wholesale retirement of EDTI’s meters was contemplated in EDTI’s last depreciation study.
666. Mr. Kennedy of Gannett Fleming, who performed the depreciation study in EDTI’s last
GTA,677 responded in writing to a series of requests made by the Commission at the oral hearing
regarding the parameters that were considered in determining the depreciation rate that is
currently being used for meters. Mr. Kennedy, acting on behalf of EDTI, responded that “in the
review of EDTI’s average service life estimates Mr. Kennedy did consider a number of factors,
and did recommend changes to the average service life estimates where the current life estimates
were not considered to be indicative of the manner in which the assets would be retired.”678 The
factors considered by Mr. Kennedy included the changes to the Measurement Canada meter
testing standards and requirements, the corresponding response by numerous regulated utilities in
Canada, which were considered to be the peer group in EDTI’s last depreciation study, to the
changes in the new Measurement Canada specification S-S-06, and the announcement by the
AUC of an inquiry into SMART metering and AMI programs.679 In considering depreciation
studies for peer utilities, many of which included short-term, large-scale, retirements of analog
meters, the IR response stated: “Mr. Kennedy, in making his recommendations for the EDTI
metering account, considered that a large scale retirement program was probable.”680 As a result,
675
Decision 2013-417, paragraph 327. 676
Proceeding 3216, Exhibit 93.01, AUC-EDTI-33(b). 677
Proceeding 1596, Exhibit 77, Appendix G-1, EDTI Average Service Life Review Gannett Fleming. 678
Proceeding 3100, Exhibit 130.01, Mr. Kennedy response to AUC(a). 679
Alberta Smart Grid Inquiry, Proceeding ID No. 598, January 31, 2011. 680
Proceeding 3100, Exhibit 130.01, Mr. Kennedy response to AUC(a).
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Mr. Kennedy recommended that EDTI reduce its 25-year average service life for analog meters
to 20 years, considering the potential for a large-scale analog meter retirement program.
667. Mr. Kennedy provided numerous examples of peer companies that had been faced with
large-scale replacements of meters, and explained the actions that he has taken in the past in
similar circumstances to reduce the service lives of the existing meters using the knowledge that
a large-scale replacement was forecast to occur. However, Mr. Kennedy did not introduce a
specific life span over which all of the remaining unrecovered investment would be amortized
because EDTI had not identified a specific replacement program at the time of the last
depreciation study.681
668. The Commission also asked the UCA’s witness, Mr. Shymanski, for his understanding of
how wholesale retirements of a particular group of assets should be handled in a depreciation
study. Mr. Shymanski recognized that Mr. Kennedy had reduced the service lives for analog
meters from 25 years to 20 years as a result of comparisons to peer utilities, which had
experience with large-scale replacement of meters, and not necessarily because of any specific
information that EDTI had with respect to a forecast replacement program.682 Mr. Shymanski
explained that a preferable method for an asset category where an accelerated retirement pattern
is known would be:
So if you had perfect information and it was, say, this proceeding and you have -- doing a
depreciation study and you knew the end date for the analogue meters, you'd say, "Okay,
analogue meters are going to be out by the year 2017," or whatever date it is. You would
take the – if you like, the remaining balance for the analogue meters, and you would
depreciate them over that reduced period. It might be a significant number, and you might
have to do some buffering in terms of a rate impact, but you would take into account a
specific reduction in the life.683
669. Mr. Shymanski noted that Mr. Kennedy did not have the information necessary to utilize
this preferred method, and used a more general reduction in service lives from 25 years to
20 years based on the knowledge he had when his analysis was performed.684
670. EDTI clarified that the primary reason the existing meter assets are being replaced is to
“substantially reduce the overall cost to customers that is associated with meters on its system.”
EDTI considered that “concluding that the retirement of EDTI’s existing meters constitutes an
‘extra-ordinary retirement’ as contemplated in the UAD Decision (thereby forcing EDTI and its
shareholder to bear the capital costs associated with those assets) would create a positive
incentive for EDTI to actively avoid these types of projects.” EDTI considered that such an
outcome would be contrary to the fundamental premise of PBR, and would undermine the
incentives for innovation and discovery that PBR is intended to create.685
671. The UCA concluded that in EDTI’s last depreciation study, Mr. Kennedy did not fully
reflect the shortened life of existing meters to three to five years to reflect a short-term, large-
scale, retirement of the meters because no specific replacement program had been identified at
681
Proceeding 3100, Exhibit 130.01, Mr. Kennedy response to AUC(a). 682
Transcript, Volume 6, page 893, lines 14-19 (Mr. Shymanski). 683
Transcript, Volume 6, page 895 (Mr. Shymanski). 684
Transcript, Volume 6, page 895 (Mr. Shymanski). 685
Proceeding 3100, Exhibit 93.01, AUC-EDTI-33(b).
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the time the last depreciation study was done and, therefore, the retirements would be considered
extraordinary.686 The UCA agreed with EDTI’s position that holding EDTI’s shareholder
accountable for all remaining costs associated with the meters replaced and taken out of service
would undermine any incentive a utility owner like EDTI has to seek out and implement such
projects for the benefit of customers.687 The UCA submitted that for such circumstances, such as
when there are competing principles between the PBR Decision 2012-237 and the UAD
Decision 2013-417, that were not contemplated when PBR was implemented, “the guiding
principle must be to look for an approach that is in the over-all public interest.”688
672. The UCA considered that one possible solution may be for the Commission to deny
K factor treatment for the AMI project, but encourage EDTI to apply for approval for Z factor
treatment for the project. The UCA expected that as part of the Z factor application, EDTI would
request an approval of an accelerated capital cost recovery program for its analog meters.689
673. In its argument, EDTI requested an “explicit determination as to whether or not the
Commission finds that the retirement of EDTI’s existing meters constitutes an extraordinary
retirement within the meaning of the UADR Decision.”690 EDTI considered that the Z factor
treatment for the project proposed by the UCA would generally accomplish the same outcome as
a K factor, but would prefer not to rely on the Z factor treatment for recovery because it would
need to wait until after the project had been completed before applying for Z factor treatment.
Accordingly, EDTI requested the same explicit determination from the Commission in respect of
the UCA’s suggestion regarding the potential use of an accelerated cost recovery approach, if the
Commission were to see merit in such an approach.691 EDTI indicated that if the retirements of
the existing meters were determined to be extraordinary, and substantial additional costs were,
therefore, imposed on EDTI, it would not be in a position to proceed with the project.692
Commission findings
674. The Commission must determine if the retirement of existing meters and the replacement
of those meters with AMI meters, as proposed by EDTI in its business case, engage the
fundamental corporate and property law principles addressed in the Supreme Court of Canada’s
decision in ATCO Gas & Pipelines Ltd. v. Alberta (Energy & Utilities Board), 2006 SCC 4,
[2006] 1 S.C.R. 140 (Stores Block), as further considered by the Alberta Court of Appeal and
which were subsequently examined in the Commission’s UAD decision.
675. In Decision 2014-297,693 the Commission considered the implications of these
fundamental principles of corporate and property law given the fires that destroyed the electric
distribution assets of ATCO Electric in the Town of Slave Lake. The Commission referred to the
Stores Block line of decisions and to the Commission’s UAD decision and stated:
686
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 79. 687
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 82. 688
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 83. 689
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 84. 690
Proceeding 3100, Exhibit 135.01, EDTI argument, paragraph 190. 691
Proceeding 3100, Exhibit 138.01, EDTI reply argument, paragraph 27. 692
Proceeding 3100, Exhibit 135.01, EDTI argument, paragraph 190. 693
Decision 2014-297: ATCO Electric 2012 Distribution Deferral Accounts and Annual Filing for Adjustment
Balances, Application No. 1609719, Proceeding No. 2682, October 29, 2014.
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52. The Commission recognizes that the Stores Block decision and the series of
Alberta Court of Appeal decisions that followed are all cases dealing with the disposition
of assets of gas utilities under the provisions of the Gas Utilities Act, RSA 2000, G-5.
However, the specific words of the Gas Utilities Act do not establish the relevant
foundational principles upon which the cases were decided. It is the fundamental
principles of corporate law and private property law that the Supreme Court of Canada
used in assessing the facts, interpreting the Gas Utilities Act and in determining
entitlements, risks and burdens in the Stores Block decision. The principles that informed
the court were, first, that the assets used for utility service are the property of the
company. Customers do not acquire an interest in the property merely by paying for the
services provided through the assets. And second, along with property ownership comes
the right to any gain and the risk of any loss.
…
56. The Commission found in the UAD decision that where the Electric Utilities Act
defines an “electric utility” in part, as an “electric distribution system” that is “used” to
provide utility services and an electric distribution system as the “plant, works,
equipment, systems and services necessary to distribute electricity in a service area,” the
words are to the same effect as the words “used or required to be used” employed in the
Gas Utilities Act to define facilities to be included in rate base. Application of these
fundamental principles requires that the costs associated with assets that are sold or lost
due to any cause (and therefore no longer necessary to provide service) be removed from
the calculation of rates and the risk of the loss (or the benefit of any gain) be for the
account of the owner of the property. The application of the principles is unrelated to the
accounting construct of rate base or whether the legislation requires that assets be placed
in a rate base for purposes of determining a tariff. As the Supreme Court of Canada stated
in Stores Block: “The argument that assets purchased are reflected in rate base should not
cloud the issue of determining who is the appropriate owner and risk bearer.”
57. The Commission has considered whether there are express terms of the Electric
Utilities Act that override the fundamental corporate and property law principles
expressed in the Stores Block decision. Those principles embody a symmetrical allocation
of risk and reward. The owners of the utility have the benefit of any gains on assets and
have the risk of losses. Customers pay for the service delivered through or across those
assets as they use them. Customers are not residual claimants to the property – either
gains or losses. In the Commission’s view, only the clearest of language in the Electric
Utilities Act could overturn the corporate and property law principles to achieve an
asymmetrical result where customers are responsible for all losses and the company is the
claimant of all gains. In the absence of such express language, statutory provisions
relating to the recovery from customers of costs considered prudent when incurred by the
utility do not change the fundamental nature of the property and corporate law principles
which dictate the entitlement to, or burden of, associated gains and losses.
58. Applying these fundamental principles to the present case leads the Commission
to conclude that any losses and any gains in notional value of utility assets arising from
the destruction of those assets should be treated no differently than if the assets were
removed from rate base or disposed of by the utility either voluntarily or otherwise.
Those assets are no longer providing service and, in the words of the Electric Utilities
Act, no longer “used directly or indirectly for the public” or “necessary to distribute
electricity.” Therefore, any losses and any gains are for the account of the owners of the
assets – the shareholders – not the customers. In general terms, if gains in value belong to
the company, rates to customers would be higher than they would otherwise be, and vice
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versa. If losses in value are the responsibility of the company, rates to customers would
be lower than they would otherwise be, and vice versa. [footnotes omitted]
676. The Commission concluded from the above analysis at paragraph 59 of Decision 2014-
297:
Since Stores Block, it can no longer simply be assumed that the costs of assets, once
found by the regulator to be prudently acquired, will be recoverable under all
circumstances (unless the actions of the utility justified different treatment). The owners
of the property bear the benefits of gains on the assets and the risk of losses when those
assets are no longer required for utility service.
677. EDTI is contemplating the replacement of assets with other assets that will render the
existing meters no longer “used directly or indirectly for the public” or “necessary to distribute
electricity” prior to the point in time where their full capital costs have been recovered through
rates. The fundamental principles of corporate and property law apply as outlined in Stores
Block. That is, the responsibilities and detriments of property ownership are the inextricable
corollary to the rights and entitlements of property ownership. The Commission considers that
the principles espoused in the Stores Block line of decisions, as reviewed in the Commission’s
UAD decision and in Decision 2014-297, must be applied to the circumstances in the present
proceeding.
678. In Decision 2014-297, the Commission applied the corporate and property law principles
that were set out in the Stores Block line of decisions, as discussed in the UAD decision, to the
record in that proceeding. The Commission determined that the responsibility for the
undepreciated capital costs for the destroyed assets flowed from a consideration of whether the
Slave Lake fires event was an “ordinary retirement” or an “extraordinary retirement” as those
terms were considered in the UAD decision. The Commission stated at paragraph 66 of Decision
2014-297:
The UAD decision recognized the concepts underlying the currently-used depreciation
methods as being consistent with the Stores Block principles because they are intended to
recover the costs of assets used in utility service over their service lives in ordinary
circumstances, recognizing that retirements outside of the relevant scope of considered
retirement events, regardless of the effect on depreciation parameters, would be classified
as extraordinary retirements and, in accordance with the Stores Block principles, would
be for the shareholder’s account. In the Commission’s view it is the characteristics of the
event that are relevant to the determination of whether the event had been contemplated
or anticipated by a prior depreciation study. If the characteristics of the Slave Lake fires
event are sufficiently different to distinguish the Slave Lake fires from the events
considered in the previous depreciation study such that the characteristics of the Slave
Lake fires cannot be said to have been reasonably contemplated or anticipated in the
determination of the depreciation parameters in that study, then the Commission would
consider the event to give rise to an extraordinary retirement and the $400,000 notional
net book value of the destroyed assets would be for the account of the shareholders.
679. In Decision 2014-297, the Commission determined that the characteristics of the Slave
Lake fires were sufficiently different from the characteristics of the fires and natural disaster
events that have occurred in the past such that it was not reasonable to assume that an event with
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the characteristics of the Slave Lake fires could have been anticipated or contemplated in the last
depreciation study. The Commission stated at paragraph 69 of Decision 2014-297:
Relying on its review of this history of losses and of the entire record of this proceeding,
the Commission makes a finding of fact that the characteristics of the Slave Lake fires
which destroyed the ATCO Electric assets are sufficiently different from the
characteristics of the fires and natural disaster events that have occurred over the past ten
years and the events upon which the Board made its RID [reserve for injuries and
damages] account assessments in Decision 2007-071 Consequently, the Commission also
finds that these fires could not reasonably have been anticipated or contemplated in the
determination of the parameters used in the previous depreciation study dated as at
December 31, 2008. Accordingly, for regulatory purposes the Slave Lake fires give rise
to an extraordinary retirement of the destroyed assets. As a result of this finding of fact,
the principles established by Stores Block and the related Court of Appeal decisions
dictate that the $400,000 notional net book value of the destroyed assets must be for the
account of the ATCO Electric shareholders. The Commission has no discretion to do
otherwise.694
[footnotes removed]
680. In the present proceeding, the Commission must conduct an analysis of whether a
retirement of the existing meters resulting from their replacement with AMI meters constitutes
an “ordinary retirement” or an “extraordinary retirement.” Accordingly, the Commission will
consider whether it is reasonable to find that the characteristics of the proposed retirement of
EDTI’s existing meters over a forecast three year period were anticipated or contemplated in the
determination of the parameters used in the preparation of EDTI’s most recent depreciation
review.
681. The Commission notes the position of EDTI that the UAD decision does not apply
because the retirement of the existing meters would not trigger issues of sudden and complete
obsolescence or extraordinary retirement as contemplated in the UAD decision. Further, even if
it did, EDTI stated the wholesale retirement of meters was contemplated in the last depreciation
review prepared for the company and reflected in the reduction in EDTI’s meter service lives
from 25 to 20 years.695 EDTI also stated that the existing meters should not be considered
obsolete because they still operate and remain capable of operating in the future to provide safe
and reliable utility service.696
682. EDTI’s position, however, fails to address the question of whether the meters are “used
directly or indirectly for the public” or “necessary to distribute electricity” after they are replaced
by AMI meters and taken out of service, irrespective of whether they remain capable of
operating in the future. The record does not provide any evidence that the replaced meters would
continue to have an operational purpose in providing utility service. The Commission finds that
the existing electro-mechanical and AMR meters would be rendered obsolete as they are
replaced by new AMI meters. Accordingly, the Commission finds that the existing meters would
no longer be “used directly or indirectly for the public” or “necessary to distribute electricity.”
683. Having found that the existing electro-mechanical and AMR meters would be rendered
obsolete and no longer “used directly or indirectly for the public” or “necessary to distribute
694
Decision 2014-297, paragraph 69. 695
Exhibit 135.01. EDTI argument, paragraph 219. 696
Proceeding 3216, Exhibit 93.01, AUC-EDTI-33(b).
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electricity,” the Commission must now determine whether it is reasonable to find that the
characteristics of the proposed retirement of EDTI’s existing meters over a forecast three year
period were anticipated or contemplated in the determination of the parameters used in the
preparation of EDTI’s most recent depreciation review.
684. Mr. Kennedy stated he was aware of the possibility of the wholesale retirement of the
majority of existing meters at the time he completed EDTI’s last depreciation review, dated
October 11, 2011.697 The depreciation review was reflected in the rates approved for EDTI in
Decision 2012-272, which were used to establish the going-in rates for EDTI’s PBR plan in
Decision 2012-237. According to Mr. Kennedy, the Gannett Fleming study made an adjustment
to the depreciation rates to shorten the lives of the existing meters to reflect changes to
Measurement Canada specifications and the possibility of the implementation of AMI, which
would wholly supplant the existing meters.
685. The response to a Commission’s request at the hearing with respect to how the
recommended service life for meters was determined in the depreciation review stated:
Giving consideration to all of the above information related to the wide spread
implementation of digital meters to meet the Measurement Canada testing guidelines, and
the implementation of AMI and AMR programs that were being considered by many
in the peer group, Mr. Kennedy recommended that EDTI reduce its 25 year average
service life estimate to 20 years, considering the potential for a large scale analog meter
retirement program. However, without a specific program identified by EDTI at that
time, the introduction of a specific life span date over which all remaining
unrecovered investment would be amortized was not yet considered appropriate.698
686. In assessing the characteristics of the retirements of EDTI’s existing meters that would
result from the implementation of AMI, the Commission notes that, at the time Mr. Kennedy
prepared his depreciation review for EDTI, he was aware that an event of this type may occur
because the implementation of AMI and AMR programs were being considered by many in the
peer group. The Commission also notes that Mr. Kennedy recognized that an event of this type
would result in a large-scale, retirement of the existing meters.699
687. The response to a Commission’s request at the hearing with respect to how the
recommended service life for meters was determined in the depreciation review also stated:
As such, Mr. Kennedy, in making his recommendations for the EDTI metering account,
considered that a large scale retirement program was probable.700
688. Although Mr. Kennedy considered that a large scale retirement was probable, he also
indicated that:
… without a specific program identified by EDTI at that time, the introduction of a
specific life span date over which all remaining unrecovered investment would be
amortized was not yet considered appropriate.701
697
Proceeding 1596, Exhibit 77, Appendix G-1, EDTI Average Service Life Review Gannett Fleming. 698
Proceeding 3100, Exhibit 130.01, Mr. Kennedy’s response to AUC(a). 699
Proceeding 3100, Exhibit 130.01, Mr. Kennedy’s response to AUC(a), page 2. 700
Proceeding 3100, Exhibit 130.01, Mr. Kennedy’s response to AUC(a).
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689. Having considered all of the above, “Mr. Kennedy recommended that EDTI reduce its
25 year average service life estimate to 20 years, considering the potential for a large scale
analog meter retirement program.”702
690. Given the record in the present proceedings, the Commission finds it is not reasonable to
conclude that the characteristics of the proposed retirement of EDTI’s existing meters over a
forecast three-year period were anticipated or contemplated in the determination of the
parameters used in the preparation of EDTI’s most recent depreciation review, and subsequently
reflected in EDTI’s rates. Although Mr. Kennedy considered that a large-scale replacement was
probable, he only adjusted the service life from 25 to 20 years, in the absence a specific
replacement program by EDTI. The resulting depreciation amounts were reflected in the rates
approved for EDTI in Decision 2012-272, which were used to establish the going-in rates for
EDTI’s PBR plan. As a result, the rates established for EDTI in Decision 2012-272 could not
have accounted for the now proposed large-scale retirement of existing meters, given the
adjusted average service life of 20 years and the now proposed three-year retirement period.
691. The AMI business case proposes the wholesale retirement of all existing meters using a
two-stage process starting in 2014, to be completed in 2017. This implementation of AMI by the
end of 2017 would result in undepreciated existing meters. EDTI estimated that the net book
value of the undepreciated meters would be some $10 to $12 million.703 Given the Commission’s
finding that it is not reasonable to conclude that the characteristics of the proposed retirement of
EDTI’s existing meters over a forecast three-year period were anticipated or contemplated in the
determination of the parameters used in the preparation of EDTI’s most recent depreciation
review and reflected in EDTI’s rates, the book value of the undepreciated meters is to the
account of EDTI’s shareholder.
11.3 Capital tracker treatment for the AMI project
692. EDTI applied for capital tracker treatment of the AMI project in 2015, when the first
capital additions of $10.39 million associated with phase one of this project are scheduled to take
place. EDTI did not forecast any capital additions in 2014 and, as such, capital tracker treatment
was not requested for 2014.704
693. In the 2014-2015 capital tracker forecast application, EDTI provided its view on how the
AMI project meets the Commission’s capital tracker criteria. In reply argument, EDTI clarified
that it applied, and continues to apply, for K factor treatment for this project. EDTI’s position
was that, consistent with the Commission’s determinations in Decision 2012-237 and Decision
2013-435, any operating cost savings resulting from the AMI project during the PBR term will
accrue to EDTI as the utility owner. At the end of the PBR term, those savings will accrue to
customers through rebasing.705
694. However, during the hearing, EDTI indicated that because the AMI project would be
largely undertaken to mitigate the impact of changes to Measurement Canada rules that can be
701
Proceeding 3100, Exhibit 130.01, Mr. Kennedy’s response to AUC(a). 702
Proceeding 3100, Exhibit 130.01, Mr. Kennedy’s response to AUC(a). 703
Transcript, Volume 4, page 664 (Mr. Baraniecki). 704
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 438. 705
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 73.
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considered a change in law, EDTI would consider refunding tangible (“hard”706) operating cost
savings to customers through a Y factor, should the AMI project be implemented.707 Mr. Elford
elaborated on this proposal:
A. MR. ELFORD: Okay. At the highest level, it's not necessarily the operating and
maintenance costs associated with AMI per se; it's the operating and maintenance costs
associated with changes in Measurement Canada rules and/or legislation that is a change
of law that has put us at a crossroads, if you will.
We have two choices: One is status quo, which will increase capital costs for meter
replacements, based on more stringent standards, and will also increase our operating
costs associated with such things as meter testing. We have to do that. Change in law,
change in rule.
So we would propose that those operating costs, we would apply for a Y factor to recover
those as long as they're in excess of the Commission's Y factor threshold.
Now, conversely, we've offered up another alternative to that same issue, and that's a
wholesale meter replacement, which will relieve us of the increased testing costs because
essentially all the meters will be new and will relieve customers of the accelerated capital
costs of the lifecycle replacement of conventional meters because they won't be there to
replace, will all have been replaced.
So what we're saying is, in that case, there is actually going to be net operating benefits
when -- after the project is implemented. And our view is, again it's being driven, the case
is being driven by these change in rules, Measurement Canada law if you will. And as a
result if we're going to apply for cost increases, if we stay on the status quo, it's only
equitable that if we are able to implement AMI as the solution to this issue, those cost
decreases should be refunded through some mechanism, and we believe that would be the
Y factor because the Commission was very, very clear that there's no netting of benefits
against the K factor for projects just because they generate benefits. Those are captured
by the X factor.
In this case, the benefits are being generated based on a solution we're proposing to a
change in law. So we don't think we can have it one way and not the other. It's an
equitable approach to this issue.708
695. Further, as mentioned in the reference above, EDTI was of the view that if the AMI
project is not implemented, the company would apply for a Y factor to recover increases in
operating costs resulting from the changes to Measurement Canada rules. In its rebuttal evidence,
EDTI stated:
In the absence of an AMI project that mitigates the impact of these changes in regulatory
requirements, Alternative 1 (Status Quo) of the AMI Business Case (Appendix A-19,
Table 4.1.1-1) demonstrates that EDTI will incur an additional approximately
$1.13 million in meter-related operating costs in 2016 alone. EDTI believes that the
increase in operating costs, being driven by a change in law and the associated changes in
the requirements of a regulatory body, would qualify for Y factor treatment under the
PBR Plan, and EDTI would apply for recovery of these incremental costs as such at the
appropriate time.709
706
Proceeding 3100, Exhibit 135, EDTI argument, paragraph 196. 707
Transcript, Volume 1, page 105, lines 19-23 (Mr. Elford). 708
Transcript, Volume 5, pages 705-706 (Mr. Elford). 709
Proceeding 3100, Exhibit 107, EDTI rebuttal evidence, page 10.
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696. Parties to the proceedings queried whether capital costs and operating costs (including
any savings offsets) associated with the AMI project should be combined and dealt with together
by way of a Z factor application. When questioned by the Commission, EDTI expressed its view
that the Z factor mechanism does not appear to be an appropriate approach to dealing with this
project.710 However, Mr. Elford indicated that “if the Commission determines that the Z factor
seems to make more sense despite our interpretation of how these things work, it still would
probably generally accomplish the same thing.”711
697. Based on the evidence of its witness, Mr. Bell, the UCA argued that the AMI project
should not be approved for capital tracker treatment as it does not meet the requirements of
Criterion 1 as they relate to the need for the project.712 During the hearing, Mr. Bell indicated he
was not in favour of EDTI’s proposal to have a K factor for the capital costs and a Y factor for
the operating costs of the project.713 However, Mr. Bell did not object to EDTI’s proposal to
refund to customers the O&M savings arising from the AMI project as demonstrated by his
statement that if the AMI project is approved for capital tracker treatment, “all operating cost
benefits must be included in the CT [capital tracker] calculation.”714 Mr. Bell expressed his view
that Z factor treatment for the AMI project is best aligned with the principles of PBR.715
698. In a similar vein, the CCA generally agreed with EDTI’s proposal to refund to customers
some of the operating cost savings associated with the AMI project. While the CCA believed a
Z factor treatment to be more appropriate, it indicated that refunding O&M savings through a
Y factor or Z factor appropriately structured to ensure fairness “would probably accomplish the
same thing.”716
699. In response to the Commission’s IR, EDTI confirmed that if the Commission were to
deny capital tracker treatment for the AMI project, then it would continue with the status quo
option, as the costs incurred by EDTI on the AMI project could not be fully offset by the realized
benefits within the term of the PBR. In addition, EDTI stated that “the substantial level of capital
investment required for the AMI project is too large for EDTI to pursue the project without prior
Commission approval.”717
700. During the hearing EDTI indicated that it is the company’s position that, should the
Commission make a determination that the early retirement of the meters to be replaced with
AMI meters would constitute “sudden and complete obsolescence” as contemplated in Decision
2013-417, EDTI would choose not to implement the AMI project.
A. MR. BARANIECKI: Yes. As outlined in the response to AUC-EDTI-33(b), if the
Commission determined that the replaced meters constituted an extraordinary retirement,
as set out in the utility asset disposition review decision, that the foregone amount of
capital that we have or that we would have to expense doesn't -- it just doesn't make sense
for the company to do that.
710
Transcript, Volume 5, pages 713-715 (Mr. Elford). 711
Transcript, Volume 5, page 715, lines 22-25 (Mr. Elford). 712
Proceeding 3100, Exhibit 137.02, UCA argument, paragraphs 12-15. 713
Transcript, Volume 6, pages 859-861 (Mr. Bell). 714
Proceeding 3100, Exhibit 97.03, UCA evidence of Mr. Bell, page 14. 715
Transcript, Volume 6, pages 890-891 (Mr. Bell). 716
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 79. 717
Proceeding 3100, Exhibit 93.01, AUC-EDTI-31(a).
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And, further, we don't view that as in any way consistent with -- a determination of that
sort is in any way consistent with the spirit and intent of PBR, nor sound business
practice; and that making a determination of that form would disincent companies from
pursuing any type of process improvement that had the potential to -- I'll use the word
"strand assets" that can no longer be put into rate base and earn on.718
701. In this regard, the UCA expressed its concern with EDTI’s assertion that it will only
proceed with the AMI project if the project is approved for capital tracker treatment. The UCA
observed that, according to EDTI’s evidence, the AMI project results in the least cost alternative
for customer revenue metering, when the long-term view is considered. On this issue, Mr. Bell
stated in his evidence:
… utility management is obliged to provide safe and reliable service at the lowers cost
possible. It is incumbent for utility management to select the least cost alternative. As
such, if EDTI chooses a higher cost alternative, it should be at risk for a finding of
imprudent action.719
702. In a similar vein, the UCA submitted:
A utility has an obligation to pursue the least cost option to providing utility service. This
obligation does not depend on the Commission approving a particular means by which
the utility must recover its prudent costs. In this case, even if Capital Tracker treatment is
not approved for the AMI project, EDTI will still have a reasonable opportunity to
recover its reasonable costs of the project, during the PBR term through the mechanism
of a Z Factor application. Following the PBR term of course, EDTI would earn a return
and charge depreciation on the capital assets.720
703. In its argument, the CCA generally supported this position of the UCA.721
704. In its rebuttal evidence, EDTI commented on this matter as follows:
Mr. Bell’s position is tantamount to asserting that the Commission should, in an indirect
and backhanded way, force EDTI to proceed with the AMI project in the absence of
Capital Tracker approval, through the threat of penalizing EDTI for not proceeding.
Contrary to Mr. Bell’s musings, there is absolutely nothing in the PBR and Capital
Tracker decisions to date, nor in the Commission’s objectives and principles of PBR, that
would suggest that the Commission intended anything of the sort. EDTI has proposed a
project that, following substantial capital expenditures on EDTI’s part, offers huge
financial benefits for customers over the long term. There is nothing in the Commission’s
decisions or inherently in PBR that would suggest that EDTI should be forced to incur
such substantial capital expenditures prior to having certainty that the project will be
approved by the Commission, or prior to having significant comfort that the Commission
will find the level of costs required to undertake the project to be reasonable (both of
which are inherent in a Capital Tracker approval). If the AMI project is not approved by
the Commission, then that project would clearly become irrelevant for purposes of
considering the prudence of any other related capital project.722
718
Transcript, Volume 5, page 724, lines 4-18 (Mr. Baraniecki). 719
Proceeding 3100, Exhibit 97.03, UCA evidence of Mr. Bell, page 13. 720
Proceeding 3100, Exhibit 137.02, UCA argument, paragraph 36. 721
Proceeding 3100, Exhibit 136.01, CCA argument, paragraphs 87-89. 722
Proceeding 3100, Exhibit 107, EDTI rebuttal evidence, page 9.
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Commission findings
705. In Section 11.2 of this decision, the Commission determined that the early retirement of
the meters to be replaced with AMI meters would constitute “sudden and complete
obsolescence” as contemplated in the UAD decision, Decision 2013-417. EDTI’s position is that
it will not implement the AMI project if its shareholders will be responsible for the remaining net
book value of the existing electro-mechanical and AMR meters when they are retired. Given
EDTI’s position, the Commission is making no determination in this decision as to whether the
AMI project qualifies for capital tracker treatment on a forecast basis as the issue is moot. The
Commission directs EDTI to remove the 2015 forecast capital additions of $10.39 million
associated with the AMI project from the 2015 forecast K factor calculation.
706. EDTI also indicated that if capital tracker treatment is not extended to the AMI project on
a forecast basis, EDTI will proceed with the status quo meter replacement project, rather than
undertake the AMI project.723 In this regard, at paragraph 615 of Decision 2012-237, the
Commission indicated that a company may choose to undertake a capital investment prior to
applying for capital tracker treatment in a subsequent annual capital tracker filing. In other
words, a company does not have to wait for the Commission’s approval of its forecast for capital
tracker treatment to proceed with projects required to maintain service reliability and safety at
adequate levels.
707. In Section 11.1, the Commission found that based on the evidence in the present
proceedings, the AMI project represents the least cost alternative for performing the customer
revenue metering function for EDTI. The Commission agrees with Mr. Bell’s view724 that any
requests associated with the customer revenue metering function as part of a Y, Z or K factor
application must be considered in light of this finding.
708. The Commission will consider applications for Y or Z factor adjustments associated with
the customer revenue metering function, including any refunds of O&M cost savings or
collection of higher O&M costs, when they are received.
12 Other matters raised by the CCA
12.1 Reporting capital tracker and non-capital tracker capital costs separately
709. During the hearing, the CCA proposed segregating the reporting of capital tracker and
non-capital tracker additions in EDTI’s financial reporting filed annually pursuant to AUC
Rule 005.725 726 In argument, the CCA summarized the issue, stating “it is important to note that
the CCA is not talking about testing I-X capital and O&M expenses, but simply proposing that
Rule 5 segregate capital tracker from non-capital trackers as well as its consequential impacts.”727
710. In reply, EDTI pointed out that AUC Rule 005 does not require the level of reporting
sought by the CCA. EDTI expressed its view that the additional reporting suggested by the CCA
is unnecessary since the information is already provided in detail in EDTI’s capital tracker
723
Proceeding 3100, Exhibit 93.01, AUC-EDTI-31(a). 724
Proceeding 3100, Exhibit 97.03, UCA evidence of Mr. Bell, page 13. 725
AUC Rule 005: Annual Reporting Requirements of Financial and Operational Results (AUC Rule 005). 726
Transcript, Volume 1, page 65, lines 16-18 (Mr. Wachowich). 727
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 7.
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applications, including detailed variance explanations, and would create a needless additional
administrative burden. Additionally, EDTI pointed out that there is an established process
pursuant to which the Commission develops its rules, whereby it considers stakeholder feedback
and enacts or modifies its proposed rules. EDTI argued it is within that process that the CCA’s
proposal should be addressed. EDTI submitted that the current proceedings are to assess its
capital tracker applications, and are not an appropriate forum for addressing potential changes to
AUC Rule 005.728
Commission findings
711. The Commission considers that the CCA’s proposal to segregate the reporting of capital
tracker and non-capital tracker additions in EDTI’s financial reporting filed in accordance with
AUC Rule 005 is outside the scope of the present proceedings. As EDTI pointed out, there is an
established process pursuant to which the Commission develops its rules, whereby it considers
stakeholder feedback and enacts or modifies its proposed rules. The Commission agrees with
EDTI’s view that it is within that process that changes to AUC Rule 005 should be considered.
712. Further, the Commission has established Proceeding 3558,729 that will address the
minimum filing requirements for capital tracker applications, including how actual capital
additions should be reflected in future capital tracker applications and true-up applications.
12.2 Changes to the efficiency carry-over mechanism
713. In Decision 2012-237, the Commission approved the inclusion of an efficiency carry-
over mechanism (ECM) in the companies’ PBR plans. As explained in that decision, a
company’s incentive to find efficiencies weakens as the end of the PBR term approaches,
because there is less time remaining for the company to benefit from any efficiency gains. The
purpose of an ECM is to address this problem by permitting the company to continue to benefit
from any efficiency gains after the end of the PBR term.730
714. During the hearing, Mr. Bell for the UCA discussed a potential for changes to the ECM
to deal with recovery of capital costs that the Commission could consider for the next PBR term.
However, Mr. Bell did not recommend making any changes to the structure of currently
approved PBR plans:
… I'm not saying that to try and change this one, but my suggestion is at the end of this
term it might be wise given the issues we've had with capital and capital trackers to look
around and see what else is out there that might be working and put a different structure
in place.731
715. The CCA expressed its view that the ECM should only apply to the I-X component of the
PBR plan and that it “does not belong in capital tracker cost-of-service world.”732 However, the
CCA agreed with Mr. Bell’s view that no changes to the ECM should be made in the current
PBR term. Additionally, the CCA pointed out that because EDTI is only one of five companies
728
Proceeding 3100, Exhibit 138, EDTI reply argument, paragraph 47. 729
Proceeding 3558, Commission-initiated Proceeding to Consider Modifications to the Minimum Filing
Requirements for Capital Tracker Applications. 730
Decision 2012-237, paragraph 759. 731
Transcript, Volume 6, pages 865, line 21 to page 866, line 1 (Mr. Bell). 732
Proceeding 3100, Exhibit 136.01, CCA argument, paragraph 10.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 153
under PBR, changes to the structure of PBR plans established in a generic proceeding should not
be made in a proceeding dealing with only one company.733
Commission findings
716. Given that the present proceedings are dealing with the true-up of the 2013 capital tracker
costs and the approval of forecast 2014-2015 capital tracker costs under an existing PBR plan in
place until December 31, 2017, the Commission considers the issue of potential changes to the
ECM to be outside the scope of these proceedings. Both Mr. Bell and the CCA expressed their
views that no changes to the ECM should be made in the current term of PBR.
13 K factor calculation
13.1 2013 K factor true-up
717. In Decision 2013-435, the Commission approved the 2013 forecast K factor of
$4.87 million to be recovered from EDTI’s customers on an interim basis.734 In the 2013 capital
tracker true-up application, EDTI calculated an actual 2013 K factor to be $5.96 million,
resulting in a proposed 2013 K factor true-up adjustment of $1.20 million, as shown in Table 1
from Section 4 of this decision.
718. EDTI indicated that it calculated the proposed 2013 K factor true-up adjustment in
accordance with the provisions set out in Decision 2012-237 and Decision 2013-435.735
Specifically, at paragraph 976 of Decision 2012-237, the Commission stated:
976. The results of the prudence review and cost true-up will be an adjustment to the
K factor included in the following year’s rates. The companies will calculate the revenue
requirements resulting from the actual capital tracker expenditures, and compare those to
the forecast amounts that were collected on an interim basis in the prior year. The
difference between the approved revenue requirements and the forecast revenue
requirements for the prior year will form the basis for the K factor true-up rate
adjustment. In addition, because the capital expenditures will remain in the tracker for the
duration of the PBR term, the amounts to include in the capital tracker revenue
requirement calculations in subsequent years during the PBR term will be based on the
actual approved expenditures rather than the initial forecasts.
719. The Commission provided further guidance on the K factor true-up at paragraphs 503 to
506 of Decision 2013-435:
503. At the time of the true-up applications, the above calculations will be repeated
using the actual, rather than the forecast, capital additions for the previous PBR year. If
the actual capital additions for a project or program approved for capital tracker treatment
in the previous year are lower than the forecast, but still exceed the four basis point
threshold, that project will continue to receive capital tracker treatment. This means that
in subsequent years a revised, lower portion of the revenue requirement not funded under
the I-X mechanism in the previous year shall be included in the K factor calculation. The
difference between the lower portion of the revenue requirement not funded under the
733
Proceeding 3100, Exhibit 136.01, CCA argument, paragraphs 9 and 18. 734
Decision 2013-435, paragraph 989. 735
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraphs 14-17.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
154 • Decision 3100-D01-2015 (January 25, 2015)
I-X mechanism in the previous year and the amounts collected by way of a capital tracker
in the previous year for that project, or program, will be refunded to customers.
504. If the actual capital additions for a project or program approved for capital
tracker treatment in a previous year are lower than forecast and do not exceed the four
basis point threshold, on true-up, the K factor will be adjusted in respect of the previous
year based on the actual dollars spent on that project or program. The difference between
the forecast portion of the revenue requirement not funded under the I-X mechanism and
the actual portion not funded under the I-X mechanism for that project, or program, will
be refunded to customers. However, capital tracker treatment for the previous year’s
project or program will be discontinued for subsequent PBR years. This means that in
subsequent years none of the revenue requirement for this project or program shall be
included in the K factor calculation. If the project or program extends into a subsequent
PBR year, in order to receive capital tracker treatment for that project or program in the
subsequent PBR year, the company will be required to reapply for capital tracker
treatment.
505. Consistent with this approach, in the event that the actual K factor (i.e., the sum
of all portions of the revenue requirements not funded under the I-X mechanism for all
capital trackers), based on the company’s actual additions in the previous year, does not
satisfy the 40 basis point threshold, on true-up, the findings in the preceding paragraph
will apply to all of the projects approved for capital tracker treatment in the previous
year.
506. Finally, if the actual capital additions for a project or program approved for
capital tracker treatment in a previous PBR year are lower than forecast to the extent that
a project or a program was, in effect, fully funded under the I-X mechanism in the
previous year, the K factor will be adjusted in respect of the previous year so that no
portion of the revenue requirement for that project will be included in the K factor
calculation in that year. The portion of the revenue requirement collected by way of a
capital tracker on a forecast basis, in the previous year, will be refunded to customers.
Capital tracker treatment for the previous year’s project or program will be discontinued
for subsequent PBR years. If the project or program extends into a subsequent PBR year,
in order to receive capital tracker treatment for that project or program in the subsequent
PBR year, the company will be required to reapply for capital tracker treatment.
720. EDTI noted that in Decision 2013-435, the Commission directed EDTI to recover the
difference between the 2013 K factor placeholder amount and the approved 2013 K factor
forecast amount using Rider DJ.736 To be consistent with this direction, EDTI proposed to use
Rider DJ to collect the applied-for 2013 K factor true-up adjustment of $1.20 million. This rider
is proposed to be in effect over the two-month period from March 1, 2015 to April 30, 2015.
721. EDTI indicated it used the same approach to calculate Rider DJ in the 2013 capital
tracker true-up application, as it did in its 2013 capital tracker true-up rider application, approved
in Decision 2014-174.737 Specifically, EDTI first allocated the $1.2 million 2013 K factor true-up
adjustment to customer rate classes using the simplified approach approved by the Commission
736
Decision 2013-435, paragraph 990. 737
Decision 2014-174: EPCOR Distribution & Transmission Inc., 2013 K Factor True-up Rider, Application
No. 1610244, Proceeding No. 3026, June 17, 2014.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 155
in Decision 2013-072. EDTI then calculated Rider DJ for each rate class by dividing the
allocated rate class amount by the relevant billing determinants for that rate class.738
722. EDTI further explained that since its final approved 2015 billing determinants were not
available at the time of filing the 2013 capital tracker true-up application, it used preliminary
2015 distribution access service (DAS) billing determinants to calculate Rider DJ. EDTI
indicated it will update the Rider DJ calculation if the 2015 DAS billing determinants approved
by the Commission, as part of the 2015 annual PBR rate adjustment filing, differ from the
preliminary determinants used in its 2013 capital tracker true-up application.739
Commission findings
723. In Section 7, the Commission confirmed the prudency of actual capital additions
associated with each of EDTI’s capital tracker projects or programs in 2013. However, as set out
in sections 8.5 and 10 of this decision, the Commission directed EDTI, in its compliance filing to
this decision, to revise its accounting test assessment under Criterion 1 and the two-tiered
materiality test assessment under Criterion 3. Because these revisions will result in changes to
the 2013 actual K factor amount, the Commission cannot approve any 2013 K factor true-up
adjustment for EDTI in this decision.
724. Nevertheless, the Commission has reviewed EDTI’s calculations and finds that EDTI’s
K factor true-up methodology is generally consistent with the requirements set out in Decision
2012-237 and Decision 2013-435. Further, the Commission agrees in principle with EDTI’s
proposal to use Rider DJ to collect the 2013 K factor true-up adjustment upon approval by the
Commission. The Commission also agrees with EDTI’s methodology to calculate the Rider DJ
rate by first allocating the true-up adjustment amount to rate classes using the simplified
approach and then calculating Rider DJ rate for each rate class by dividing the allocated rate
class amount by the relevant billing determinants. This methodology has been previously
approved for EDTI in Decision 2014-174.
725. EDTI proposed to update the Rider DJ calculation if the 2015 DAS billing determinants
approved by the Commission as part of the 2015 annual PBR rate adjustment filing differ from
the preliminary determinants used in its 2013 capital tracker true-up application.740 The
Commission agrees with this proposal and directs EDTI, in calculating the Rider DJ rate for each
rate class, to use the 2015 final billing determinants approved in Decision 2014-346.
726. In Section 14 of this decision, the Commission directs EDTI to file a compliance filing
application in accordance with the directions set out in this decision on March 3, 2015. Given
this refiling date, EDTI’s proposed collection period for Rider DJ from March 1, 2015 to April
30, 2015 is no longer feasible.
727. As discussed in Section 13.2 below, in addition to collecting the 2013 K factor true-up
amount, the Commission considers that EDTI should also collect the difference between the
respective 2014 and 2015 K factor placeholder amounts and the approved 2014 and 2015 K
factor forecast amounts using the same Rider DJ. Therefore, rather than including the Rider DJ
rate in its compliance filing to this decision, the Commission directs EDTI to file a separate
738
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 487. 739
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 489. 740
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 489.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
156 • Decision 3100-D01-2015 (January 25, 2015)
application for the combined Rider DJ rate, following approval of the 2013 true-up actual
K factor amounts and 2014-2015 forecast K factor amounts in the compliance filing decision.
The effective date and the duration of the new collection period for the combined Rider DJ
should be commensurate with the Commission’s process timelines set out in Bulletin 2010-16
and take into account the impact on customer bills.
13.2 2014-2015 K factor forecast
728. As summarized in Table 2 from Section 4 of this decision, in the 2014-2015 capital
tracker forecast application, EDTI calculated the 2014 and 2015 forecast K factors to be
$10.76 million and $20.12 million, respectively.741 EDTI indicated that it calculated the proposed
2014 and 2015 K factors in accordance with the provisions of Decision 2013-435.742
729. To calculate the K factor adjustment in its 2014 PBR rates, EDTI first allocated the
$10.76 million proposed 2014 K factor to rate components within customer rate classes using the
simplified approach approved by the Commission in Decision 2013-072. EDTI then calculated
the 2014 K factor rate adjustment for each rate component within rate classes by dividing the
allocated amount by the relevant billing determinants for that rate component.743
730. Regarding the 2015 K factor of $20.12 million, EDTI indicated it will provide the 2015
K factor rate adjustments in its 2015 annual PBR rate adjustment filing on September 10, 2015.744
Commission findings
731. In Section 7, the Commission determined that EDTI’s forecast capital expenditures for
the proposed 2014-2015 capital tracker projects (with the exception of the AMI project) were
reasonable. As set out in Section 11, Commission is making no determination in this decision as
to whether the AMI project qualifies for capital tracker treatment on a forecast basis. The
Commission directed EDTI to remove $10.39 million in capital additions associated with the
AMI project from the 2015 forecast K factor calculation. As set out in sections 8.5 and 10 of this
decision, the Commission directed EDTI, in its compliance filing to this decision, to revise its
accounting test assessment under Criterion 1 and the two-tiered materiality test assessment under
Criterion 3. Because these revisions will result in changes to the 2014 and 2015 forecast K factor
amounts, the Commission cannot approve any 2014 or 2015 K factor adjustments for EDTI, on a
forecast basis, in this decision.
732. Nevertheless, the Commission has reviewed EDTI’s calculations and finds that EDTI’s
K factor calculation methodology is generally consistent with the requirements set out in
Section 4.4 of Decision 2013-435. Further, the Commission agrees in principle with EDTI’s
proposal to calculate the 2014 and 2015 forecast K factor rate adjustments by first allocating the
forecast amount to rate classes using the simplified approach and then calculating the K factor
adjustment rate for each rate class by dividing the allocated amount by the relevant billing
determinants. The Commission has approved this approach to the K factor rate calculation for
EDTI in a number of decisions, most recently in Decision 2014-346, dealing with EDTI’s 2015
annual PBR rate adjustment filing.
741
Exhibit 93.02, AUC-EDTI-1, Attachment 1, Table 1.0-1. 742
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 17-21. 743
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraphs 495-499. 744
Proceeding 3100, Exhibit 80, 2014-2015 forecast application, paragraph 500.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 157
733. In Decision 2013-462, the Commission approved a K factor placeholder of $6.08 million,
representing some 60 per cent of the applied-for amount, to be included in EDTI’s 2014 PBR
rates.745 In Decision 2014-346, the Commission approved a K factor placeholder of $18.108
million, equal to 90 per cent of the proposed 2015 K factor, to be included in EDTI’s 2015 PBR
rates.746
734. Consistent with the findings in Section 13.1 of this decision, and consistent with EDTI’s
past practices, the Commission considers that EDTI should collect the difference between the
respective 2014 and 2015 K factor placeholder amounts and the approved 2014 and 2015
K factors forecast amounts using its existing Rider DJ mechanism. In Section 13.1, the
Commission directed EDTI, following the approval of the 2013 true-up actual K factor amounts
and 2014-2015 forecast K factor amounts in the compliance filing decision, to file a separate
application for the combined Rider DJ rate, which includes the 2013 true-up adjustment, and the
difference between the respective 2014 and 2015 K factor placeholder amounts and the approved
2014 and 2015 K factor forecast amounts.
745
Decision 2013-462, paragraphs 47, 57 and 58. 746
Decision 2014-346, paragraph 44.
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
158 • Decision 3100-D01-2015 (January 25, 2015)
14 Order
735. It is hereby ordered that:
(1) EPCOR Distribution & Transmission Inc. is directed to file a compliance filing
application in accordance with the directions contained within this decision on
March 3, 2015.
Dated on January 25, 2015.
Alberta Utilities Commission
M. Kolesar
Vice-Chair
H. van Egteren
Commission Member
N. Jamieson
Commission Member
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 159
Appendix 1 – Proceeding participants
Name of organization (abbreviation) counsel or representative
EPCOR Distribution & Transmission Inc. (EPCOR or EDTI)
Fasken Martineau Dumoulin LLP
ATCO Electric Ltd. (ATCO Electric)
AltaLink Management Ltd. (AltaLink)
ATCO Gas, a division of ATCO Gas and Pipelines Ltd. (ATCO Gas) Bennett Jones LLP
Consumers’ Coalition of Alberta (CCA)
FortisAlberta Inc. (Fortis)
Office of the Utilities Consumer Advocate (UCA) Brownlee LLP
The Alberta Utilities Commission Commission Panel M. Kolesar, Vice-Chair H. van Egteren, Commission Member N. Jamieson, Commission Member Commission Staff
B. McNulty (Associate general counsel) S. Boyd (Commission counsel) O. Vasetsky E. Deryabina C. Runge J. Work S. Levin
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
160 • Decision 3100-D01-2015 (January 25, 2015)
Appendix 2 – Oral hearing – registered appearances
Name of organization (abbreviation) counsel or representative
Witnesses
EPCOR Distribution & Transmission Inc. (EPCOR or EDTI)
J. Liteplo D. Both
K. Sorenson K. Hull J. Elford J. MIddleton J. Baraniecki R. Reimer
Office of the Utilities Consumer Advocate (UCA) T. D. Marriott K. Kellgren
R. Bell B. Shymanski
Consumers’ Coalition of Alberta (CCA)
J. A. Wachowich J. Thygesen
The Alberta Utilities Commission Commission Panel M. Kolesar, Vice-Chair H. van Egteren, Commission Member N. Jamieson, Commission Member Commission Staff
B. McNulty (Associate general counsel) S. Boyd (Commission counsel) D. Jagdev O. Vasetsky E. Deryabina R. Lee S. Levin
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 161
Appendix 3 – Summary of Commission directions
This section is provided for the convenience of readers. In the event of any difference between
the directions in this section and those in the main body of the decision, the wording in the main
body of the decision shall prevail.
1. At the same time, the Commission considers that it may be warranted to group all of
EDTI’s life cycle replacement and like projects together with the Neighbourhood
Renewal program for the purposes of the accounting test, given that it appears these
projects are all intended to replace or renew aging assets. Accordingly, EDTI is directed
to explain, in its next capital tracker application, whether it is possible to do so and
whether such grouping is warranted. ............................................................... Paragraph 78
2. The Commission considers that formal project management policies and procedures are
necessary to ensure the Commission understands that the scope, level, timing and costs of
forecast capital projects are reasonable and actual costs are prudently incurred. The
Commission directs EDTI to describe fully its formal project management policies and
procedures in its next capital tracker application. ......................................... Paragraph 152
3. EDTI calculated the 2013 Q factor of 0.54 per cent based on the preliminary forecast of
2013 billing determinants approved in Decision 2013-072. In its compliance filing to this
decision, the Commission directs EDTI to use the 2013 Q factor of 1.46 per cent based on
the final forecast billing determinants approved in Decision 2013-270, for the 2013
capital tracker true-up accounting test. Similarly, in its future capital tracker true-up
applications, the Commission directs EDTI, to utilize the approved I-X index and the Q
factor based on a final approved billing determinants forecast for that year in the
accounting test. ............................................................................................. Paragraph 578
4. Nevertheless, the Commission observes that, since the filing of EDTI’s 2014-2015 capital
tracker forecast application, the 2015 I-X index and billing determinants forecast have
been approved in Decision 2014-346, which deals with EDTI’s 2015 annual PBR rate
adjustment filing. To minimize future true-ups, the Commission directs EDTI, in its
compliance filing to this decision, to use the 2015 I-X index value and the Q factor based
on the forecast billing determinants approved in Decision 2014-346 for purposes of its
2015 capital tracker forecast accounting test. ................................................ Paragraph 580
5. Accordingly, in its decision in Proceeding 3434, the Commission will assess the
reasonableness of, and the need for any changes to, EDTI’s WACC rates used for its
2013 true-up and 2014-2015 forecast accounting tests. The Commission expects that a
decision in Proceeding 3434 will be issued in time to allow EDTI to reflect any directed
changes to WACC rates used in the accounting test in its compliance filing to this
decision. EDTI is directed to incorporate into its compliance filing to this decision any
changes to 2013, 2014 and 2015 WACC rates directed by the Commission’s decision in
Proceeding 3434. ........................................................................................... Paragraph 589
6. Accordingly, although the Commission finds the general form of EDTI’s accounting test
model to be reasonable and consistent with the methodology approved in Decision 2013-
435, the Commission cannot make a determination in this decision as to whether any of
EDTI’s projects or programs proposed for capital tracker treatment in 2013-2015 satisfies
the accounting test requirement of Criterion 1 and accordingly, whether any of EDTI’s
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
162 • Decision 3100-D01-2015 (January 25, 2015)
projects or programs satisfy Criterion 1 in its entirety. The Commission directs EDTI, in
its compliance filing to this decision, to revise its accounting test for 2013, as well as for
2014-2015, based on approved final forecast or actual capital additions and model
assumptions and other directions as set out in the previous sections of this decision.
........................................................................................................................ Paragraph 609
7. In subsequent capital tracker true-up applications, the Commission directs EDTI to
address whether the driver for any of the previously approved forecast projects or
programs has changed, so as to warrant a reassessment under Criterion 2. In the event
that the driver of the project or program has changed since the forecast project or
program was approved, EDTI is directed to identify such projects and programs and to
provide evidentiary support that each project or program continues to satisfy the
requirements of Criterion 2. .......................................................................... Paragraph 616
8. Further, in an updated table in response to AUC-EDTI-1(b), EDTI labelled this project as
“Replacement/Growth.” The Commission directs EDTI, in its compliance filing to this
decision, to explain whether any part of the Aerial and Underground Distribution
Transformers – New Services and Life Cycle Replacement project, deals with the
replacement of existing transformers and how this may affect the assessment under
Criterion 2. In addition, if there are different drivers for different aspects of this project,
EDTI is directed to explain why these assets have been grouped into a single capital
tracker project category. ................................................................................ Paragraph 619
9. At the same time, consistent with the findings in Section 8.2, the Commission considers
that the calculation of the first and second tier materiality thresholds for purposes of the
capital tracker true-up application for a given year should be based on the approved I-X
index for that year. The Commission directs EDTI to follow this approach in future
capital tracker true-up applications. ............................................................... Paragraph 632
10. The Commission observes that, since the filing of EDTI’s 2014-2015 capital tracker
forecast application, the 2015 I-X index had been approved in Decision 2014-136. To
minimize future true-ups, the Commission directs EDTI, in its compliance filing to this
decision, to use the 2015 I-X index value of 1.49 per cent approved in Decision 2014-346
to calculate the first and second tier materiality thresholds for 2015. ........... Paragraph 633
11. Given these findings, the Commission directs EDTI, in its compliance filing to this
decision, to reassess whether each of its projects or programs proposed for capital tracker
treatment in 2013 to 2015, satisfies the two-tiered materiality test requirement of
Criterion 3. For this reassessment, EDTI will use the approved 2013 and 2014 threshold
amounts, as well as revised 2015 threshold amounts, as directed above. ..... Paragraph 638
12. In Section 11.2 of this decision, the Commission determined that the early retirement of
the meters to be replaced with AMI meters would constitute “sudden and complete
obsolescence” as contemplated in the UAD decision, Decision 2013-417. EDTI’s
position is that it will not implement the AMI project if its shareholders will be
responsible for the remaining net book value of the existing electro-mechanical and AMR
meters when they are retired. Given EDTI’s position, the Commission is making no
determination in this decision as to whether the AMI project qualifies for capital tracker
treatment on a forecast basis as the issue is moot. The Commission directs EDTI to
remove the 2015 forecast capital additions of $10.39 million associated with the AMI
project from the 2015 forecast K factor calculation. .................................... Paragraph 705
2013 PBR Capital Tracker True-up and 2014-2015 PBR Capital Tracker Forecast EPCOR Distribution & Transmission Inc.
Decision 3100-D01-2015 (January 25, 2015) • 163
13. EDTI proposed to update the Rider DJ calculation if the 2015 DAS billing determinants
approved by the Commission as part of the 2015 annual PBR rate adjustment filing differ
from the preliminary determinants used in its 2013 capital tracker true-up application.747
The Commission agrees with this proposal and directs EDTI, in calculating the Rider DJ
rate for each rate class, to use the 2015 final billing determinants approved in Decision
2014-346. ....................................................................................................... Paragraph 725
14. As discussed in Section 13.2 below, in addition to collecting the 2013 K factor true-up
amount, the Commission considers that EDTI should also collect the difference between
the respective 2014 and 2015 K factor placeholder amounts and the approved 2014 and
2015 K factor forecast amounts using the same Rider DJ. Therefore, rather than including
the Rider DJ rate in its compliance filing to this decision, the Commission directs EDTI
to file a separate application for the combined Rider DJ rate, following approval of the
2013 true-up actual K factor amounts and 2014-2015 forecast K factor amounts in the
compliance filing decision. The effective date and the duration of the new collection
period for the combined Rider DJ should be commensurate with the Commission’s
process timelines set out in Bulletin 2010-16 and take into account the impact on
customer bills. ................................................................................................ Paragraph 727
15. It is hereby ordered that: (1) EPCOR Distribution & Transmission Inc. is directed to file a
compliance filing application in accordance with the directions contained within this
decision on March 3, 2015. . .......................................................................... Paragraph 735
747
Proceeding 3216, Exhibit 1, 2013 true-up application, paragraph 489.