Demande R-3549-2004
Réponse R19.2
Original : 2004-12-07 HQT-10, Document 1.2

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
We wish to thank the COPE utilities that have contributed data for this report. They are:
AltaLink Management
ATCO Electric
Aquila Networks (BC)
B.C. Hydro
ENMAX
Hydro One
Hydro-Québec
Manitoba Hydro
New Brunswick Power
SaskPower
The COPE Program would also like to thank the participants from the CEA Programs listed below who have contributed to their respective reports. These companies include all CEA member utility companies. x Accident Statistics Report x Bulk Electricity System
For more information:
Peter Gelineau
Canadian Electricity Association
Tel: 514-866-5375
Email: gelineau@canelect.ca
Copyright © 2003 by Canadian Electricity Association. All rights reserved.
ii Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
This report provides information on the Canadian Utility Composite Performance and
Productivity results. The information is based on data received from the participating utilities for the year ended December 31, 2002 (March 31, 2003 for utilities with March year ends).
In 1995, the Committee on Corporate Performance and Productivity Evaluation (COPE) undertook an extensive strategic review. The database designed in the early 1980s was driven out of regulatory structure and reporting to regulatory bodies. The industry focus in the 1990s had shifted to “business performance.” The result was a new vision, mission, and a redesigned database. The “unbundled” database allows for participation in any combination of business units. The new database provides a “balanced scorecard approach” of key performance measures for each of its business units.
Power Supply
Transmission
Corporate Overall
Distribution Customer Service Corporate Services
The objectives of COPE are:
Ÿ To establish a common basis for inter-utility performance measurement.
Ÿ To maintain and update common definitions and terms used in performance measurement consistent with Canadian and USA utility practices
Ÿ To establish a framework for the integration of performance information collection and measurement to minimize costs for CEA and Utilities.
Ÿ To provide guidance in the collection, use and application of the information for the benefit of individual utilities’ performance achievement
This report provides a summarized version of the Transmission Business Unit Key
Performance Measures. It contains performance measures from the perspectives of customer, employee, and stakeholder. (Note: measures for the perspectives of environment and regulator are still under development).
Canadian Electricity Association iii

iv
2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
The data presented in this report is the weighted composite data of the participating companies for the respective Key Performance Indicator (KPI). Composite data brings together the data from the participants and presents an “average” picture of the information.
It is very important to note that the differences in the characteristics of the various companies can create a significant range in the data of the individual companies. These characteristics include many variables such as ownership, business operations, customer make up and service area. An example of this is the customer density for companies that are predominately urban compared to companies that are predominately rural or a combination of both as for some provincial utilities. The number of participants in each KPI varies and the composite data is impacted by the make up of the companies including their relative size with respect to the measure.
In benchmarking comparisons, it is important to understand the complete context of the data and the companies included in the analysis. As a result, a company comparison to composite data does not imply superior or inferior performance.
COPE versus CEA Composite
The graphs in this report refer to a COPE or CEA composite. Some Key Performance
Indicators used in the COPE program are derived from other CEA programs. The COPE
Composite values for the Key Performance Indicators represent the composite of those utilities participating in the COPE program. The CEA Composite represents the composite of those utilities participating in the CEA program.
Trending Data versus Present Year’s Data
Companies providing data to a given indicator may vary from year to year, typically this is the result of new members joining the program. Due to this, trend line Composite calculations may be impacted by participation and not represent accurately an industry trend.
To address this, some indicators show two different results for the data. The first result, for sake of consistency, uses the same calculation baseline from year to year, and provides a better understanding of the indicator's historical trend and is represented graphically as a trend line. The second result shows the Composite Index achieved when all participants (both old and new) are included in the 2002 program and represented graphically as one point in year
2002. In some cases, these two results are significantly different.
Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
Transmission (Minutes of Interruption per Year)
Transmission (Sustained Interruptions per Year)
(Total Injuries / 200 000 hours worked)
(FTE / 100 000 MWh)
(FTE / 1000 km)
($ / MWh)
($000 / km)
($000 / km)
Canadian Electricity Association v

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
MISSION
This business unit manages, operates or maintains all land structures, lines, switching and terminal stations, high tension apparatus, and their control and protecting equipment between a generating or receiving point and the entrance to a low side of a terminal station. It is a transportation entity only and does not buy or sell power. It also runs the ISO. It may also perform specific marketing activities in addition to the marketing support provided by Customer Service.
MAJOR FUNCTIONS
The functions that comprise this business unit include: x management of the transmission delivery systems including the negotiation of wheeling agreements and the provision of open access where applicable; x operation of the transmission systems including the monitoring and control functions, system inspection activities and system performance; x maintenance of the transmission systems including preventive, scheduled maintenance and corrective maintenance; x construction and modification of the transmission systems including systems planning and design.
DELINEATION POINT BETWEEN GENERATION AND TRANSMISSION
The assets and related costs in this business unit include the following: x all direct assets related to the transmission of electricity above 60kV transmission lines with the view of the "intent" of the wires as part of the generating assets or parts of the transmission system; and x all equipment prior to delivery of energy to the transmission system at the high side of the step-up transformer is part of the Generation business unit. vi Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
Transmission
(Minutes of Interruption per Year)
CEA Composite
1998
1999
2000
2001
2002
1993
1994
1995
1996
1997
Minutes '98 Ice Storm
64.18
79.69
100.02
58.59
62.36
67.5 371.07
113.79
87.57
83.68
101.22
TR_CU01R
Note: When referring to a Composite for comparison purposes, the annual data excludes the '98 Ice Storm. The '98 Ice Storm is represented with a dotted line in the graph on the opposite page.
Canadian Electricity Association vii

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
Transmission
400
350
300
250
200
150
100
50
0
1998 Results
Including Ice Storm 371 min
Excluding Ice Storm 67.5 min
1993 1994 1995 1996 1997 1998 1999 2000 2001 2002
Calendar Year Ending
Annual Data Including '98 Ice Storm
Definition: Total Duration of all Interruptions
Total # of Delivery Points Monitored
SAIDI= System Average Interruption Duration Index
This is an index of the average cumulative duration of delivery point interruptions to the Bulk
Electricity System (BES) per year. These interruptions are measured at the delivery point between the Transmission & Distribution Systems. This indicator has been sourced from the
CEA 2002 BES Delivery Point Performance & Significant Power Interruptions Report (10 participating utilities monitoring 3,503 Delivery Points -DPs).
Results: This indicator increased by 21% over last year. However, the 10-year trend has fluctuated between a minimum of 59 and a maximum of 114 (371 if you include the 98 Ice Storm) minutes per DP per year. The system configuration, length and density will impact the individual company indicator. The 5-year SAIDI for multi circuit configuration compared to single circuit configuration shows a large difference of 36 to 132 minutes per DP per year (not including the 98 Ice Storm).
The participant data in 2002 also included a wide range with a minimum of approximately 20 and a maximum of approximately 300 minutes per DP per year.
Canadian Electricity Association 1

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
2
Transmission
(Sustained Interruptions per Year)
CEA Composite
Note:
Year Interruptions Including per year '98 Ice Storm
1998
1999
2000
2001
2002
1993
1994
1995
1996
1997
0.95
1
1.21
1.25
1.03
1.16 1.38
1.12
1.01
0.90
0.92
TR_CU02R
When referring to a Composite for comparison purposes, the annual data excludes the '98 Ice Storm. The '98 Ice Storm is represented with a dotted line in the graph on the opposite page.
Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
Transmission
2.0
1.8
1.5
1.3
1.0
0.8
0.5
0.3
0.0
1993 1994 1995 1996 1997 1998 1999 2000 2001 2002
Annual Data Including '98 Ice Storm
Definition: Total # of Sustained Interruptions
Total # of Delivery Points Monitored
SAIFI= System Average Interruption Frequency Index
This is an index of the average number of sustained interruptions that a delivery point experiences on the Bulk Electricity System (BES) per year. These interruptions are measured at the delivery point between the Transmission & Distribution Systems. This indicator has been sourced from the CEA 2002 BES Delivery Point Performance & Significant Power
Interruptions Report (10 participating utilities monitoring 3,503 Delivery Points DPs).
Results: This indicator increased by 2% over last year. This year’s 0.92 interruptions continues to be near the best performance over the 10-year trend line, which has fluctuated between a minimum of 0.86 and a maximum of 1.16 (1.38 if you include the 98 Ice Storm) interruptions per DP per year. The system configuration, length and density will impact the individual company indicator.
The 5-year SAIFI for multi circuit configuration compared to single circuit configuration shows a large difference of 0.39 to 1.55 interruptions per DP per year. The participant data in 2002 included a wide range with a minimum of less than 0.1 and a maximum of over 5 interruptions per DP per year.
Canadian Electricity Association 3

4
2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
(Total injuries / 200 000 hours worked)
CEA Composite
Year Transmission Corporate
Rate Overall Rate
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
9.54
6.1
5.7
5.9
6.08 5.51
3.63 4.47
3.47 4.41
3.82 4.09
3.41 3.91
4.29 3.47
TR_EM04R
Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
10
8
6
4
2
0
1993 1994 1995 1996 1997 1998 1999 2000 2001 2002
Transmission (BU) Corporate Overall
Definition: (Disabling Injuries + Medical Aid Injuries) x 200,000
This graph demonstrates the frequency of medical aid injuries, disabling injuries and fatalities compared to the number of employee exposure hours in a calendar year. As well as providing the annual Business Unit (BU) CEA Composite, the Corporate Overall CEA
Composite is included for comparison purposes. This indicator is sourced from the CEA
Annual Accident Statistics Report (43 electric utilities, 19 of which reported separate
Transmission BU data).
Results: The 2002 All Injury Frequency Rate for the Transmission BU increased 26% over last year while the Corporate Overall category dropped by 11%. It is recognized that this indicator is directly impacted by the relative risk of accidents associated with the hours that employees work. This relative risk differs depending on the type of tasks an employee undertakes. (line personnel vs. office worker). As a result, the seriousness of the accidents (severity) also needs to be investigated in order to assess performance. The Severity rate for the Transmission BU improved slightly (0.2%) over last year.
Canadian Electricity Association 5

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
3
COPE Composite
Year (FTE / 100,000 MWh) (FTE / 100,000 MWh)
All 2002 Participants
2000
2001
2002
1.81
2.01
1.97 2.00
TR_EM07R
Trend Line Participants: 8
2002 Participants: 10
6 Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
(FTE / 100 000 MWh)
3.0
2.5
2.0
1.5
1.0
0.5
0.0
2000 2001
Calendar Year Ending
Participants in All 3 year Period
2002
All 2002 Participants
Definition: Transmission Total FTE
Total Energy Transmitted per 100,000 MWhr
This measure relates staffing to the amount of energy transported across the wires. Total Full
Time Equivalent Employees (FTE) includes contractors/contract equivalent employees.
Results: FTE per Energy Transmitted decreased by 1.8% from 2001 to 2002. Over the same period, Transmission Total FTE increased by 2.2% and Total Energy
Transmitted increased by 4.1%. The 3-year trend line includes 8 utilities and with a minimum value of approximately one and a maximum value of approximately 10 FTEs per Energy Transmitted. Individual company results are influenced by their respective system configuration, length and density.
Canadian Electricity Association 7

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
COPE Composite
Year
2000
2001
2002
(FTE / 1000 km) (FTE / 1000 km)
All 2002 Participants
28.08
30.64
31.21 32.04
TR_EM08R
Trend Line Participants: 9
2002 Participants: 10
8 Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
(FTE / 1000 km)
33
32
31
30
29
28
27
26
2000 2001
Calendar Year Ending
Participants in All 3 year period
2002
All 2002 Participants
Definition: Transmission Total FTE
Total 230 kV Equivalent Circuit (1000 KM)
This performance measure relates the number of staff required to support the transmission system in terms of 000's of 230kV equivalent circuit Km. Total Full Time Equivalent
Employees (FTE) includes contractors/contract equivalent employees.
Results: FTE per 230kV Equiv. Circuit km increased by 1.8% from 2001 to 2002. Over the same period, Transmission Total FTE increased by 2% and Total 230 kV
Equivalent Circuit increased by 0.1%. More notable, is the 9.1% increase in
FTE per 230kV Equiv. Circuit km from 2000 to 2001. Over this period,
Transmission Total FTE increased by 9.2% and Total 230 kV Equivalent Circuit increased by 0.1%. The 3-year trend line includes 9 utilities and with a minimum value of approximately 20 and a maximum value of approximately
1,200 FTEs per 230kV Equiv. Circuit km. Individual company results are influenced by their respective system configuration, length and density.
Canadian Electricity Association 9

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
COPE Composite
Year
2000
2001
2002
($/MWh) ($/MWh)
All 2002
Participants
9.18
9.51
9.02 8.85
TR_SH01D
Trend Line Participants: 6
2002 Participants: 7
10 Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
($/MWh)
9
8
7
6
11
10
2000 2001
Calendar Year Ending
Participants in All 3 year period
2002
All 2002 Participants
Definition: Transmission Total Cost (excluding taxes) ($)
Total MWh Transmitted
This measure relates total cost to the total amount of energy transported across the wires.
Results: Unit Cost decreased by 5.1% from 2001 to 2002. Over the same period,
Transmission Total Cost decreased by 1%, with a price index of 2.3%, and the
Total MWh Transmitted increased by 4.3%. The 3-year trend line includes 6 utilities and with a minimum value of less than $5 and a maximum value of over
$13 Unit Cost. Individual company results are influenced by their respective system configuration, length and density.
Canadian Electricity Association 11

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
COPE Composite
Year
2000
2001
2002
($000 / km) ($000 / km)
All 2002
Participants
14.61
14.78
14.65 14.60
TR_SH02D
Trend Line Participants: 6
2002 Participants: 7
12 Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
($000/km)
19
17
15
13
11
9
7
5
2000 2001
Calendar Year Ending
Participants in All 3 year period
2002
All 2002 Participants
Definition: Transmission Total Capital Cost ($000)
Total 230kV Equivalent Circuit (km)
This is an index that relates capital cost to the size of the system. Capital costs include interest and preferred dividends, depreciation and net income.
Results: Capital Unit Cost per 230kV Equiv. km decreased negligibly from 2001 to 2002.
Over the same period, Transmission Total Capital Cost decreased by 0.7%, with a price index of 2.3%, and the Total 230kV Equivalent Circuit increased by
0.1%. The 3-year trend line includes 6 utilities and with a minimum value of less than $12 and a maximum value of approximately $900 Capital Unit Cost per 230kV Equiv. km. Individual company results are influenced by their respective system configuration, length and density.
Canadian Electricity Association 13

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
COPE Composite
Year
2000
2001
2002
($000 / km)
2.59
2.93
2.77 2.75
TR_SH03D
($000 / km)
All 2002
Participants
Trend Line Participants: 7
2002 Participants: 8
14 Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
($000 / km)
5
4
3
2
1
0
2000 2001
Calendar Year Ending
Participants in All 3 year period
2002
All 2002 Participants
Definition: Transmission Direct Operations & Maintenance Cost ($000)
Total 230kV Equivalent Circuit (km)
This performance measure indicates the amount of O&M $ that are used to support the plant.
Results: Direct OM&A Cost per 230kV Equiv. km decreased 5.4% from 2001 to 2002.
Over the same period, Transmission Operations & Maintenance Cost decreased by 5.3%, with a price index of 2.3%, and the Total 230kV Equivalent
Circuit increased by 0.1%. The 3-year trend line includes 7 utilities and with a minimum value of less than $2 and a maximum value over $130 OM&A Cost per 230kV Equiv. km. Individual company results are influenced by their respective system configuration, length and density.
Canadian Electricity Association 15

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
COPE Composite
Year
2000
2001
2002
Percentage (%) Percentage (%)
All 2002
Participants
2.81
2.67
3.26 3.25
TR_SH13R
Trend Line Participants: 7
2002 Participants: 8
16 Canadian Electricity Association

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
5
4
3
2
1
0
2000 2001 2002
Calendar Year Ending
Participants in All 3 year period All 2002 Participants
Definition: Transmission Net Income x 100 .
[
Previous
Total Gross Fixed Assets +
Current
Total Gross Fixed Assets] /2
This performance measure is an indicator of financial performance as it relates to the return on average investment in Fixed Assets
Results: Return on Assets increased 22.2% from 2001 to 2002. Over the same period,
Transmission Net Income increased by 24.9% and Average Total Gross Fixed
Assets increased by 2.3%. The 3-year trend line includes 7 utilities and with a minimum less than 1% and a maximum of approximately 9% Return on Assets.
Canadian Electricity Association 17

2002 COPE EXECUTIVE SUMMARY - Transmission Business Unit
18 Canadian Electricity Association