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REQUESTOR NAME: Joint Industry Electricity Steering Committee INFORMATION REQUEST ROUND NO: 2 TO: BRITISH COLUMBIA HYDRO & POWER AUTHORITY DATE: May 16, 2007 PROJECT NO: 3698455 APPLICATION NAME: BCH – F2007 [COSA/] Rate Design
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10.0 Reference: Exhibit B-1, Page 18-20; Page 13, Figure 1; Exhibit B-3, JIESC IR 1.3.1
Explanation: BC Hydro has used 12CP or an average of monthly peak demand. Additional information is required to evaluate the data used and trends in system demand.
Request:
10.1 Provide the monthly coincident peak demands of each customer class, with and without losses, at the times of the domestic peak loads for the fiscal years 2001-2005 in the format used for fiscal year 2006 in the spreadsheet identified as JIESC_1_003_1 Attachment 1.
10.2 With respect to the data provided in response to JIESC IR 1.3.1 for F2006 and for F2001-F2005 provided in response to 10.1 above, please state whether the reported demands include any interruptible or curtailable loads that were not interrupted or curtailed.
10.3 If the demand data for F2001-F2006 include interruptible or curtailable loads, provide the monthly amounts of such loads for each customer class.
10.4 For F2001-F2006 provide the amounts (estimated as necessary) of interruptible or curtailable loads, by customer class, that were interrupted or curtailed at the time of each of the monthly peak demands.
11.0 Reference: Exhibit B-1, Page 21;
Explanation: Additional information is required to understand the basis for demand allocations and use of the Transmission system.
Request:
11.1 Provide a table of BC Hydro generation resources (owned and under contract) by generating unit (not in aggregate) with the in-service date and showing each resource’s dependable summer and winter capacity rating for the years F1999-F2006. Include all resources that were available at any time during these years.
11.2 Provide a tabulation of the planned maintenance schedules for all generating resources of BC Hydro for F1999-F2006 with the beginning and ending dates for all planned outages as scheduled at the beginning of each year. Identify extraordinary planned outages and the causes.
11.3 Provide a tabulation of the actual maintenance schedules for all generating resources of BC Hydro for F1999-F2006 with the beginning and ending dates for all outages. Identify extraordinary outages and the causes.
C18-3
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12.0 Reference: Exhibit B-3-1, JIESC IR 1.4.3;
Explanation: BC Hydro has provided information by NAIC codes. The IR specified electro-chemicals and it appears that electro-chemicals have been grouped with other chemicals.
Request:
12.1 Confirm that the data for chemicals includes customers other than electro-chemicals.
12.2 If the chemicals customer data includes customers other than electro-chemicals, provide the data for the three electro-chemical producers (four facilities).
13.0 Reference: Exhibit B-3, BCUC IR 1.3.2, BCUC IR 1.7.3, JIESC IR 1.1.2, JIESC IR 1.1.9, JIESC IR 1.1.10, JIESC IR 1.1.12; Exhibit B-1, Page 35-40;
Explanation: In the response to BCUC IR 1.3.2, BC Hydro states that the elimination of declining blocks and discounts is necessary to removing the misalignment between these existing rate structures and the message of energy conservation.
In response to BCUC IR 1.7.3, BC Hydro states that from a cost of service perspective, adding a sub group is the same as adding a rate class. Adding a rate class does not necessarily enhance the ability to match costs and revenues for a specific group. Adding a rate class would only increase the ability to match costs and revenues for a specific group if:
1. The load profile for the new group is known;
2. The load profile or interconnection requirements for the new group are materially different than the load profile or interconnection requirements of the existing rate class, resulting in a materially different cost to serve; and
3. Customers who would be in the new group can be readily identified with minimal debate.
For simplicity and to provide price signals that are not contrary to the promotion of energy efficiency and conservation, BC Hydro is proposing to flatten the demand and energy charges for the General Service >35 kW rate.
The graph of accounts by demand level provided in response to JIESC IR 1.1.10 appears to suggest that customers are not homogenous and that higher demand customers are materially different than the average and mean of the customers within the SG>35 kW rate class as provided in response to JIESC IR 1.1.9.
Request:
13.1 Does BC Hydro agree that one of the purposes of declining block rate structures was to limit the number of rate classes by designing rates that would apply across a broad range of customer demand and energy levels?
13.2 Does BC Hydro agree that declining block rates would take into account the lower unit costs of serving customers with higher demand and energy use within a rate class?
13.3 Does BC Hydro agree that the graph of the distribution of GS>35 kW indicates that there are a limited number of customers outside of a normal bell curve distribution of demands within the
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GS>35 kW rate class?
13.3.1 Do the customers meet the criteria for a separate rate class as set out by BC Hydro in response to BCUC IR 1.7.3? If not, why not?
13.4 Provide the rates and bill impacts (JIESC IR 1.1.2) assuming a separate GS rates (LGS) for the specified customer groups and revenue neutrality for the new rate classes:
13.4.1 Separate rate classes for customers with demands between 200 kW and 1,000 kW (LGS1) and customers with demands above 1,000 kW (LGS2).
13.4.2 Separate rate classes for customers with demands between 200 kW and 3,000 kW (LGS1) and customers with demands above 3,000 kW (LGS2).
13.5 Provide the rates and bill impacts (JIESC IR 1.1.2) assuming a separate GS rates (LGS) for the specified customer groups and revenue neutrality for the new rate classes with all GS>35 kW customers with demand >3,000 kW moved to a rate based on Schedule 1823(1823-B) with a rate rider designed to recover the revenue difference between GS>35 kW and Schedule 1823:
13.5.1 Separate rate class for customers with demands between 200 kW and 3,000 kW (LGS1).
13.5.2 Separate rate class for customers with demands between 300 kW and 3,000 kW (LGS1).
13.5.3 Confirm that a rate for customers billed under a form of Schedule 1823 would meet the BC Hydro objectives of simplicity, fairness and price signals to promote energy efficiency and conservation.
14.0 Reference: Exhibit B-3, JIESC IR 1.3.7; Attachment: CRI Workshop Presentation (.ppt)
Explanation: A portion of a CRI presentation providing load graphs that formed the basis of the JIESC IR has been attached for reference. From the data and graphs provided in the response, it is difficult to confirm that the data and graphs are the same as those provided in the attachment.
Request:
14.1 Confirm that the data and graphs are in the attachment and the IR response are the same.
14.2 If the data and graphs in the attachment and the IR response are not the same, indicate which information is correct and provide the supporting data and resulting graphs in the same format and quality as the attachment.
15.0 Reference: Exhibit B-3, JIESC IR 1.7.2;
Explanation: BC Hydro declined to respond to the information request.
Request:
15.1 Confirm that if transmission and generation demand and energy allocation methodologies are fixed, the effect of other generally accepted cost allocations on revenue-cost ratios would be expected to fall within a range of +/-5%.
Conservation Research Initiative Residential Time of
Use Program
Working Group Meeting #2
March 21, 2007
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Our Challenges - Winter PeakRecord Peak Day Load Shape
Domestic System November 2006
7,000
7,500
8,000
8,500
9,000
9,500
10,000
10,500
11,000
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hour Ending
MW
Nov 29th 2006 Peak Day
November Domestic Peak: 10,113 MWNovember 29, 2006at Hour Ending 18
Note: Peak Day Load Shape not adjusted for Voluntary and Involuntary Outages
3
Our Challenges - Winter PeakTotal Domestic System Monthly Peak
06/07
5,000
6,000
7,000
8,000
9,000
10,000
11,000
April
May
June Ju
ly
August
Septem
ber
October
Novembe
r
Decembe
r
Janu
ary
Februa
ry
M onth
MW
4
Our Challenges - Load Duration
Load Duration of the BC Hydro System
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
1 8,760
Hour in the Year
Perc
ent o
f pea
k lo
ad
5
Why Consider Residential? Typical Peak Week - by Rate Class
Comparison of Total Rate Class LoadsTypical Peak Week Jan 1 - Jan 7, 2005
1,000
1,500
2,000
2,500
3,000
3,500
1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21
Hour Ending
MW
Residential General Transmission
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Why Consider Residential? Typical VI Peak Week - by Rate Class
Comparison of Vancouver Island Rate Class LoadsTypical Peak Week Jan 1 - Jan 7 2005
200
300
400
500
600
700
800
900
1,000
1,100
1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21Hour Ending
MW
Residential General Transmission
7
Peak MonthsTotal Domestic System Monthly Peak
06/07
5,000
6,000
7,000
8,000
9,000
10,000
11,000
April
May
June Ju
ly
August
Septem
ber
October
Novembe
r
Decembe
r
Janu
ary
Februa
ry
M onth
MW
8
Peak Days
Comparison of Total Rate Class LoadsTypical Peak Week Jan 1 - Jan 7, 2005
1,000
1,500
2,000
2,500
3,000
3,500
1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21 1 5 9 13 17 21
Hour Ending
MW
Residential General Transmission
9
Peak HoursRecord Peak Day Load Shape
Domestic System November 2006
7,000
7,500
8,000
8,500
9,000
9,500
10,000
10,500
11,000
0 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hour Ending
MW
Nov 29th 2006 Peak Day
November Domestic Peak: 10,113 MWNovember 29, 2006at Hour Ending 18
Note: Peak Day Load Shape not adjusted for Voluntary and Involuntary Outages
