The BC Old Age Pensioners' Organization Page 2.1.0 August ... · 29 BRC01 SBC BRC Replacement Bearing Cooling Coils ... Turbine Runner Replacement - Units 6,7 and 8- ... 184 SHU0610G

The BC Old Age Pensioners' Organization Information Request No. 2.1.0 Dated: August 22, 2006 British Columbia Hydro & Power Authority

Page 1

Response issued September 18, 2006 British Columbia Hydro & Power Authority BC Hydro F07/F08 Revenue Requirements Application

Exhibit: B-16

1.0 Reference: BCOAPO 1.2.1

2.1.0. Please provide the information requested in BCOAPO 1.2.1 for all BC Hydro work activities that are being managed as projects by Project Mangers from the Engineering Services Project Management group – i.e. all activities that involve direction, scheduling or coordination by a Project Manager should be included.

RESPONSE: All BC Hydro work activities managed by Project Managers in Engineering, with the exception of those noted below, are tabulated on Attachment 1. Statements of Objectives for the projects described in Attachment 1 are provided in Attachment 2 (CD-ROM).

The following categories of projects have been excluded from Attachments 1 and 2:

• All projects for BCTC;

• All projects for external clients; and

• All projects related to security upgrades to BC Hydro facilities.

B16-2

bharvey

BCH-F2007-08RR

ENGINEERING MANAGED PROJECTSReference: IR SCPO 1.2.1

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GENERATION PROJECTSSHORT NAME Title

1 ABF04RED ABF Redevelopment Definition Phase

2 ABF06RED . ABF Redevelopment Implementation Phase

3 ALU07DS Alouette Dam Instrumentation/Surveillance Improvements

4 ASH07PBR ASH Penstock Bridges Recoating

5 BGS05CWP BGS Circulating Water Discharge Pipe Rehabiliation

6 BGS05NGA BGS Natural Gas Line Emergency ValveNent

7 BGS05SSD BGS Safety Shutdown Load Shedding & Transfer System Upgrade

8 BGS060SS Burrard Offshore Structure Rehab Implementation

9 BGSWCWSP BGS Cycle Chemistry Instrumentation - Units 4, 5 and 6

10 BR101FR BR1 Fire Risk Reduction1-11 BR102BBR Bridge River 1 PIV Control Replacement

12 BR106ACS BR1 PH AC SS Main Distribution Panels & 480V SS Breakers

13 BR106DPR BR1 PH DC Station Service Replacement

14 BR106SST BR1 PH AC Station Service Replacement

15 BR107ASB BR1 Powerhouse Asbestos Clad

16 BR107PHC BR1 Powerhouse Utility Air System Refurbishment

17 BR 1 08G4G BR1 Unit 4 Governor & PAM Replacement Project

18 BR1WHEEL BR1 Wheelpit Platform

19 BR201 CW BR2 G5 - G8 Cooling Water Valves/Piping

20 BR201TCC BR2 G7 & G8 TIV Control System Upgrade

21 BR202FR1 BR2 Fire Risk Reduction (Imp Phase)

22 BR203ASB BR2 Powerhouse Asbestos Removal & Siding Replacement

23 BR203CRU BR2 Control Room, Lunchroom, Washroom Renovations

24 BR203SS1 BR2 AC Station Service Improvements

25 BR205TNI BR2 G7 & 8 Needle Rebuild

26 BR206DCR BR2 129V DC Distribution Upgrade

27 BR207PAM BR2 Unit 7 PAM (Protection, Alarm, Metering)

28 BR208PAM BR2 Unit 8 PAM (Protection, Alarm, Metering)

29 BRC01 SBC BRC Replacement Bearing Cooling Coils

30 BRG070SC BRG Northern Warehouse Oil Storage & Containment

31 BRR06TL T BRR Townsite Long Term Options

32 CBL07GDS CBL River Spillway gate Reliability Improvements

33 CMS04UP Protection, Alarming and Comm. Upgrade - CMS G2/T2 & S.S.

34 CMS06PIV CMS - PIV Valve Controls, System and Containment

35 CMS06TR CMS T1 & T2 Replacement

36 CMS07DPR CMS Drainage & Unwatering Sump Pump & Controls Replacement

37 CMS07FR Cheakamus G.S. Fire Risk Reduction - Final Upgrade Phase

38 COM03ASB COM Powerhouse Asbestos Removal & Cladding Replacement

39 COM03CWP COM Cooling Water System Replacement

40 COM05SPG COM Spillway Gate Control Replacement

41 COM06DBR COM Debris Boom Replacement

42 CQD03DS Coquitlam Dam Seismic Upgrade

43 DDM07lCR Duncan Dam Intake Gantry Crane Recoating

44 DDM07PPS Duncan Dam Power Plant Study

45 ELK06GHR ELK INOG Hoist Replacement

46 ELK06RWR Elko Penstock Inlet Valves - Retaining Wall Replacement

47 ENV98WQT Environment Water Quality Testing Equipment

48 FLS07T1 FLS T1 Transformer Replacement - Definition

49 FNG05SDC FNG Site Drainage and Concrete Project

50 FNG06WTP FNG Chemical Containment & Floor Drainage

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BCOAPO IR 2.1.0Attachment 1


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E N G I N E E R I N GIli

51 FVG01 SD FVG Immoblization and Siocking Devices for Water Passages

52 GE05VOLC Volcast Equation Update

53 GEN05PSS Generation Power System Stabilizer Upgrade Project

54 GEN06DW2 Coastal & Columbia Regions - Domestic Water

55 GMSOODWC GMS Domestic Water Pumps & Treatment System

56 GMSOOSPR GMS Sewage Treatment Plant Replacement

57 GMSOOUPN GMS Station Protection / DC Station Service Replacement

58 GMS02WR 1 Sennett Dam Weir R1 Foundation Grouting-59 GMS031SR GMS Intake Sridge & Stop Logs

60 GMS03PHC GMS Powerhouse Crane Controls Replacement

61 GMS04G7R GMS G7 Generator Rewind Project

62 GMS04WDG GMS G1-5 Spare Winding Project

63 GMS05DTC GMS - Draft Tube Crane Replacement

64 GMS05GTS GMS - Spare Generator Transformer

65 GMS051DS Sennett Dam OW Grouting

66 GMS05SR GMS Units 3 & 4 Stator Replacements P50

67 GMS06DS WAC Sennett Dam - Instrumentation Improvements -

68 GMS06CI GMS Units 6-8 Capacity Increase - Phase 1

69 GMS07TUR GMS G1-5 Turbine Upgrade Project

70 GMS99GTR GMS G1-G10 Generator Transformer Replacement

71 GMSCOMP GMS New Air Compressor

72 GMS-RS97 GMS - Turbine Runner Replacement - Units 6,7 and 8

73 HLK03TS HLK Recoat Navtower Steelwork----74 HLK05DS Keenleyside Seismic Upgrade

75 HLK06DSR HLK Debris Soom Refurbishment

76 HLK06SST Keenleyside Station Service Upgrade - Stage 1 & 2

77 HLK07SIR Seismic Restraint Installation - Definition - HL Keenleyside

78 JHT05SRK John Hart - Ladore Runback

79 JHT05ENG JHT Rehabilitation - Phase 2 Engineering Work

80 JHT06ETM JHT T2/4/6 ETM Replacement

81 JHT06GND JHT Station Grounding Improvements

82 JHT06PEN JHT Penstock Protection

83 JHT06UPS JHT 250V DC Station Sattery Sank & Charger Addition

84 JHT55REM JHT SCADA System Removal

85 JHTIGRAD John Hart Intake Gates Radio

86 JOR04GOV JOR Replace Governor Mechanical Head with Digital

87 JOR06CCR Elliot Dam Fibre Communication Link

88 JOR06DLC JOR/DIV Lowering Crane

89 JOR06GND JOR Station Grounding Upgrade

90 JOR06TIV JOR G1 Turbine Inlet Valve

91 JOR07HCV JOR Diversion Hollow Cone Valve

92 JOR08PAC JOR G1/T1T2 Protection Upgrade

93 JOROBPAM JOR G1 PAM Installation

94 KCL03HSR KCL Headworks Gate/ Superstructure Recoat

95 KCL05DC KCL 24V&125VDC Sat Chargers&Main DC Distr Panel Replace

96 KCL05DS KCL Canal Leakage Remediation

97 KCL061GC KCL - Intake Gantry Crane Recoating

98 KCL06TGC KCL - Tailrace Gantry Crane Corrosion Protection

99 KCL06U13 KCL Transformer 13 Replacement Project

100 KCL06UVM KCL Unit Vibration Monitor- Implementation

101 KCL07GOV KCL Governor Replacements G1-4

102 KCL07HER KCL Generator Heat Exchanger Refurbishment

103 LAJ02FR1 LAJ Fire Risk Reduction (Imp Phase)

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EN G I NEERINGIl104 LAJ02PR LAJ Penstock Recoating and Seal Replacement-105 LAJ05DS LAJ North Conduit Seismic Improvements

106 LAJ06SCR LAJ PH 125V DC Sattery & Charger Replacement

107 LAJ06DCR LAJ - 129V DC Distribution Upgrade'

108 LAJ06GSS LAJ G1 Governor Speed Switch Replacement

109 LS103DTR LS1 Draft Tube Replacement

110 LS105RSG Installation of Spare LS1 Governor

111 LS106GOL LS1 Generator Thrust Searing Oil Lift System

112 LS107DTG LS1 Draft Tube Gate Refurbishment

113 LS 1 07TIV LS1 Turbine Inlet Valve (TIV) Rehabilitation

114 LS107USC LS1 Upper Spillway Capacity Improvements

115 LS108PAM LS1 PAM (Protection, Alarm, Metering)

116 LDROOSTC Ladore Surge Tank Coating

117 LDR02FR Ladore G.S. Fire Risk Reduction

118 LDR02PIG LDR Intake Gates Recoating

119 LDR03TIV LDR TIV Seal Replacement

120 LDR04TCV LDR G1 & G2 TIV Control Valve Replacement

121 LDR05DTS LDR Draft Tube Stoplogs

122 LDR05GND LDR Station Grounding Upgrade

123 LDR05SMH LDR Spillway Stoplog Monorail Replacement

124 LDR05TSC LDR Tailrace Stoplog Crane

125 LDR06DIG LDR - Quinsam Diversion Gate Refurbishment

126 LDR08SCC LDR - Salmon Canal Concrete Replacement

127 LDR08STS LDR Salmon Timber Spillway

128 LSM05DS Life Safety Model Development

129 MCA04DI Mica Dam - Litte Chief Slide

130 MCA05SSC Mica Slue Sridge Coating & Structural Assessment

131 MCA05SHR MCA Srush Holder Replacement - DEFERRED TO F2007

132 MCA05DTR Mica Draft Tube Drain Valve Replacement

133 MCA05ECM Mica Elevator Controls Modernization

134 MCA05EXC MCA Exciter G1 - G4 Replacement

135 MCA05FPI MCA Fall Protection Installation

136 MCA05GOV MCA G1 - G4 Governor Upgrade

137 MCA050lU MCA Operational Information (01) Upgrade

138 MCA05SCC Mica G3 & G4 Synchronous Condenser Addition

139 MCA06COM MCA Communication System Upgrade

140 MCA06CWH MCA 80 psi Cooling Water Header Replacement

141 MCA06TUR MICA Units 1 & 2 Turbine Evaluation

142 MCA071DD MCA Intake Debris Soom

143 MCA071GR MCA Spare Intake Gate Cylinder Refurb

144 MCA07SCR Mica Dam Staircase Replacement

145 MCA07SDD MCA Spillway Debris Soom

146 MCASRIMP Mica Stator Repl - Implementation Phase147 PAM05LSS Protection, Alarm & Metering (PAM) Operating System Upgrade

148 PCN01 DWC PCN Domestic Water System Upgrade Project149 PCN03GEN RFP - Peace Canyon Generator Deficiency Project

150 PCN05GEN PCN Generators Refurbishment - Impl Phase

151 PCN05TO PCN Turbine Overhauls (P90 for all 4 Units)

152 PCN06CP PCN Companion Project to PCN05GEN

153 PCN07TO PCN Units 1, 2 & 3 Turbine Overhauls - Definition Phase

154 PUN01 SP PUN Oil Sump and Pump Addition

155 PUN02FR Puntledge G.S. - Fire Risk Reduction

156 PUN03CWP PUN Cooling Water System Replacement

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157 PUN03PHS PUN Seismic Upgrade Project (Non-structural)

158 PUN03SLR Comox Dam Sluiceway Gates Hoist & Wheel Refurbishment

159 PUN05DI Puntledge Dam Seismic and Flood Stability DI

160 PUN05GND PUN Station Grounding Upgrade

161 PUN071SC PUN Intake & Sluice Gate Communications

162 PUN07SPR PUN Sump Pump Replacement

163 PUN07STR Puntledge Dam Seismic Structural

164 PUN07TRX PUN Rebuild Trashrack Structure and Install Rakes

165 REGWUP Regulatory Approval for WUPs

166 REV05DS Downie Slide Drainage Upgrade-167 REVU507 Regulatory Completion and Definition Phase - 2

168 RUS05REH Ruskin Rehabilitation Study (Identification Phase)

169 RUS06GSS RUS G1/2/3 Governor Speed Switch Replacement

170 RUS07DO Ruskin Dam - Options Development & Assessment

171 SCA04DTG SCA Draft Tube Gates Refurbishment

172 SCA05GND SCA Station Grounding Upgrade

173 SCA061SL SCA Intake Stoplog Refurbishment

174 SCA07PSS SCA Powerhouse 125V DC Sattery Sank Replacement

175 SCA07PDA SCA G2 PDA Monitoring System

176 SCA08PDA SCA G1 PDA Monitoring System

177 SEV06DC SEV 24 & 125 VDC systems upgrade

178 SEV06GIS SEV Unit 1/2 GIS Replacement

179 SEV07GFP SEV GIS Roof Fall Protection & Rescue Provision

180 SEV07SCC SEV Synchronous condenser Air Recovery Upgrade

181 SEVSTTD SEV Searing Temperature Tripping Devices

182 SEVMU4C Seven Mile Unit 4 Deficiency Items Completion

183 SFN0501 SFN Operational Information Project

184 SHU0610G SHU G1 Intake Operating Gate Refurbishment

185 SON01FR1 SON Fire Risk Reduction (Imp Phase)

186 SON04WL T FORESAY/TAILRACE TELEMETRY UPGRADE

187 SON06CF Seton Canal Fencing Replacement Project

188 SON06CRU SON Control Room, Lunchroom, Washroom renovations

189 SON06DP Seton Drainage Improvements

190 SON06SRG Spillway Gate Dam Safety Upgrade

191 SPN07STL SPN Tunnel Stoplog Replacement

192 SS05DS Columbia Sasin - Dam Safety Improvements

193 VIG01 SD VIG Immoblization and Siocking Devices for Water Passages

194 WAHOOGOV Wahleach Governor Replacement

195 WAH04UP WAH G1/T1 Protection & PAM Replacment & VPN/Ollnstallation

196 WAH06DCR WAH 129V DC Distribution

197 WAH14T1 WAH T1 Replacement

198 WGS06FR Whatshan G.S, Fire Risk Reduction

199 WGS07CWS Whatshan Cooling Water Monitoring System Study

DISTRIBUTION PROJECTSSHORT NAME

~ ,..,Title

200 07 -MSC-06 NEL duct bank on Sky train ROW

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201 07-MSC-07 F621 to provide Additional Capacity to Port Moody

202 07-MMR-01 25552MRG feeder towards west side of Maple Ridge.

203 07-MMR-02 HNY Station Civil Work

204 07-MMR-03 HNY Feeder #1



207 07-MMR-06 1251 WNK voltage conversion

208 07-FVW-06 New CAM ductbank and feeder for RA V TPS

209 07-FVW-13 Addition to new RIM ductbank reqd for RAV relocation/service

210 07-SITS-01 SSR12F51 Conversion & Extension

211 06-0KK-11 Vernon Ductbank Addition

212 06-MSCM1 New SND feeder to supply Surnaby Mountain (UniverCity)

213 06-MNSC1 Lynn Valley standby feeder

214 06-FVW1 New ANN feeder to offload existing ANN feeders - to SWK 12319 (12F54 ANN).

215 06-FVW9 New TSW feeder to offoad existing TSW feeders via 25F61 TSW,

216 06-FVW27 Install MLN feeder to 208 & Douglas to offload MLN25F64

217 06-FVE6 Install 25F55KEN to tie to 25F51 MIS and improve reliability

218 06-FVE2 Install CSN feeder to Hwy 11 and Valley load to transfer 25F61 SMW to CSN

OTHER PROJECTSSHORT NAME Title

219 ROCKSAY5 Rockbay

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Page 1


Exhibit: B-16


2.2.1 Please indicate the volume and dollar value of CRMP hedging contracts held by Powerex and the volume and dollar value passed through to third parties.

RESPONSE: As of March 31, 2006, BC Hydro hedging contracts with Powerex totaled 1,611 GWh of electricity and 19,676,796 GJ of gas for a combined notional value of C$240 million. Powerex is BC Hydro’s exclusive counterparty for hedging transactions, as governed by the Transfer Pricing Agreement. Powerex manages their side of these transactions as part of their overall portfolio of market positions.


Page 1


Exhibit: B-16


2.2.2 Please provide a copy of BC Hydro’s application requesting approval of its hedging strategy and the Commission’s order approving the strategy.

RESPONSE: The BC Hydro Commodity Risk Management Policy for Short Term Domestic Obligations (the Policy), which governs the commodity hedging activities of BC Hydro, was approved by the BC Hydro Board of Directors on February 15, 2005. A presentation on the Policy was made to the BCUC on March 15, 2005 and a copy of the Policy was filed with the BCUC, on a confidential basis, in September 2005. BC Hydro also files with the BCUC quarterly reports on its hedging activity. Please also refer to response to BCUC IR 1.95.1.


Page 1


Exhibit: B-16

3.0 Reference: BCOAPO 1.10, BCOAPO 1.16, BCOAPO 1.17, BCOAPO 1.26,

BCOAPO 1.28, BCOAPO 1.32.

Explanation: BC Hydro appears to have misunderstood the subject-matter of these requests. In its responses to the referenced questions, BC Hydro makes reference to the Freedom of Information and Protection of Privacy Act (“FOIPPA”) but does not actually assert that the Act prohibits disclosure in these proceedings of the Personal Service Plans described in the referenced questions: for instance, it says in response to BCOAPO 1.17.1: Personal Service Plans (PSPs) are personal information under the Freedom of Information and Protection of Privacy Act (FOIPPA). In BC Hydro's view disclosure of the requested PSPs would be an unreasonable invasion of employees' personal privacy under section 22 of FOIPPA. Accordingly, the requested PSPs have not been provided. Section 3 (2) of FOIPPA provides as follows: 3(2) This Act does not limit the information available by law to a party to a proceeding. While BCOAPO does not accept any suggestion that the disclosure in these proceedings of these Plans is prohibited by FOIPPA; however, in any event, BCOAPO had not requested disclosure of individuals’ Personal Service Plans. It has requested specific items of information concerning targets and priorities. Goals and objectives that flow from BC Hydro’s annual planning process are implemented through these Personal Service Plans. For example, in the response to BCOAPO 1.10, the Team Objectives are provided. In order to achieve them objectives, the Vice Presidents include goals and targets in their Personal Service plans in support of Team Objectives. The Managers’ “Direct Reports” in turn set goals and targets that support their Vice President’s goals. These goals and targets influence expenditures and provide insight into BC Hydro’s view of the relative importance of various activities, and therefore the goals and targets that flow from BC Hydro’s planning process are relevant and subject to disclosure. 2.3.0 Please provide the goals and targets of each Vice President, Department Head etc. that are intended to influence work activities undertaken during 2006/2007. Please include the relative priority using a percentage scale of each goal or target.


Page 2


Exhibit: B-16

RESPONSE: BC Hydro continues to believe that disclosure of individual PSPs or the employment-related information contained in them would be an unreasonable invasion of employees’ personal privacy under section 22 of the Freedom of Information and Protection of Privacy Act. Accordingly, BC Hydro is not providing the requested employment-related goals and targets of individual employees. However, to provide more information at the Executive Management Team (EMT) level the members of the EMT have consented to disclosure of their personal performance objectives, which are summarised in attachment 1. The objectives of EMT members flow from the broader Executive Team objectives that were included in the response to BCOAPO IR 1.10.1. Individual performance goals and targets for each of the EMT members set the overall operational framework for the line of business that each member represents. The goals and objectives are also aligned with BC Hydro’s annual Service Plan. For additional information regarding BC Hydro’s performance measures and incentive plans, please refer to the response to BCUC IR 2.384.0.




Page 1


Exhibit: B-16


2.4.0 How many First Nations communities have requested that they be served under BC Hydro’s Zone II Electric Tariff provisions?

RESPONSE: BC Hydro did not keep records on the number of First Nations communities that requested service under BC Hydro’s Zone ll Electric Tariff provisions prior to the RCE program. Since the inception of the RCE program, no First Nations communities have requested service under BC Hydro’s Zone II Electric Tariff provisions.


Page 1


Exhibit: B-16

5.0 Reference: BCOAPO 1.32.2(page 4)

2.5.0 Please describe the conservation rate initiatives being considered by the Power Smart department.

RESPONSE: BC Hydro has filed with the BCUC pilot residential Time-of-Use rates. BC Hydro intends to examine the feasibility of other conservation rates such as real-time pricing, critical peak pricing, seasonal rates, and inverted block rate rates as part of developing a long-term rate strategy.


Page 1


Exhibit: B-16

6.0 Reference: BCOAPO 1.32.2(pages 9 - 18)

2.6.0 Please provide the operating and deferred capital budget for each business unit.

RESPONSE: The F2007 and F2008 Operating budgets for each business unit can be found on page 21 of the Appendix C of F07/F08 RRA and in the response to BCOAPO IR 1.32.2. The deferred capital budget for each business unit is as follows: Business Unit F2007

($ million) F2008

($ million)

Power Smart 39.1 42.8 Customer Care 16.2 13.8 Non-Integrated Areas 0.1 0.1 Total for Distribution 55.4 56.7


Page 1


Exhibit: B-16

7.0 Reference: BCUC 1.012.02 Attachment 1

The announcement by Ms Van Ruyven refers to the goal of achieving 10,000 GWh of conservation through DSM over the next 10 years. BCOAPO notes that the spending required to achieve this target has not been approved nor is approval for the spending being requested in the current Revenue Requirement or LTAP application. 2.7.0 What organizational changes are being implemented to ensure that BC Hydro is not over-staffed between now and when an appropriate DSM spending level is approved? Please describe the staffing level considerations being implemented to address the possibility that adequate funding to support this level of DSM will not be approved.

RESPONSE: Organizational changes are not required to ensure that BC Hydro is not over-staffed between now and when an appropriate DSM spending level is approved. Current DSM staffing is based on the current DSM initiatives outlined in the F07/F08 RRA. If adequate funding to achieve DSM targets was not approved, then BC Hydro would adjust any potential requirements for staffing to the levels required to implement DSM initiatives to achieve DSM targets within the approved spending levels.


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Exhibit: B-16

8.0 Reference: BCUC 1.025.02 (page 2 -3)

2.8.0 Please describe the Tier 2 Program Enabler Activities.

RESPONSE: Tier 2 program enabler activities are energy management practices and tools that large industrial customers can employ to address their specific barriers to energy efficiency improvements. They are meant to facilitate customers responding to the Tier 2 price signal. Without these activities, many of the five barriers to energy efficiency would persist, thereby limiting adoption of energy efficiency measures and practices in response to the Tier 2 price signal. Consistent with industry best practice, the activities target customer staff (people), business process or technology. The planned activities are: People Focus Energy Manager: Offers funding, technical support and training for an internal or external resource to implement energy management practices. The energy manager’s mandate is the identification and implementation of energy savings projects. As customers are exposed to the energy manager’s activities, their level of energy management awareness will be transformed such that they bring this perspective to future projects. Employee Awareness: Provision of a package of materials for, and potentially the delivery of, training programs to help customers increase employee awareness about energy savings opportunities. These activities can be completed specific to one customer site, across an industry sub-sector, or for certain cross-cutting technologies for the entire sector. Process Focus Strategic Energy Management Planning: Technical support for the development of a comprehensive action plan that details a customer’s energy management strategy and objectives, including a baseline of energy use, specific key performance indicators, targets, identified opportunities, and procurement policies. Energy Management Information Systems: Temporary loan of equipment to collect information for the purpose of energy management.


Page 2


Exhibit: B-16

Monitoring, Targeting and Reporting: Technical support for the development of a process and approach to monitor and track energy use trends, establish targets, and turning data into information that is appropriate for various audiences including executive level management facilitating a continual improvement culture for energy. Technology Focus Energy Studies: Provides funding and technical advice to customers to execute energy audits of their facilities to quantify energy savings opportunities. An energy study takes a comprehensive look at a facility's energy using systems and provides detailed recommendations for cost-effective options that can improve the energy efficiency of a facility. Demonstration Projects: Provides funding and technical advice for trials of new energy saving technologies and processes. Once the acceptance and awareness of these technologies is improved as a result of the demonstration, the technologies can be more widely adopted.


Page 1


Exhibit: B-16

9.0 Reference: Exhibit B-5-1 (Section 8.8.2.3), BC Hydro 2006 CFT Results

(posted at www.bchydro.com)

2.9.1 BC Hydro’s posted press release indicates that it has awarded contracts for 7,000 GWh of electricity purchases as a result of the 2006 Call. The 2006 Call was based on the need for 2,500 GWh. This change would appear to reduce the need for additional staff described in Section 8.8.2.3. Please present any revised staffing requirements in light of the increased volume of power purchases as a result of the 2006 Call.

RESPONSE: Please refer to the response to BCUC IR 2.358.0.


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Exhibit: B-16

9.0 Reference: Exhibit B-5-1 (Section 8.8.2.3), BC Hydro 2006 CFT Results

(posted at www.bchydro.com)

2.9.2 Reference BCUC 1.043.0.

(a) What is the status of the implementation of OATT business practices?

(b) Will the 2 additional FTE’s be required once the implementation of business practices is complete?

RESPONSE: (a) The business practices referenced in BC Hydro’s response to BCUC IR 1.43.0

relate to all interconnection/transmission issues and do not apply singularly to OATT. As for the implementation of OATT, the remaining item requiring considerable BC Hydro input is the development of the interconnection and transmission impact and cost analysis part of BC Hydro’s acquisition call process known as the Competitive Energy Acquisition Process (CEAP). This is expected to be filed by BCTC in proposal form before the end of F2007.

(b) The 2 FTEs which were identified in F2006 are in place and will be retained in

full-time positions to work on various interconnection and transmission issues, including OATT, NITS and business practices. As noted in the F07/F08 RRA, the Generator Interconnection & Transmission Services group is dealing with a high volume of activities which is not expected to decrease. This heavy workload includes the interconnection of generators for BC Hydro’s acquisition calls and the coordination of transmission planning processes with BCTC.


Page 1


Exhibit: B-16

10.0 Reference: BCOAPO 1.04.1, Exh B-5-1 (Section 2.3.3.1)

2.10.0 Please provide any analysis of the 2006 load and price variance.

RESPONSE: The following table provides the actual net impact of the load variance for F2005 and F2006.

RRA Actual Difference RRA Actual Difference

Domestic Energy Sales (GWh) Residential 15,836 15,814 (22) 16,063 16,261 198Light Industrial and Commercial 17,003 17,459 456 17,202 17,913 711Large Industrial 14,734 16,177 1,443 14,601 16,428 1,827Other 1,714 1,755 41 1,738 1,838 100Total 49,287 51,205 1,918 49,604 52,440 2,836Plus Losses (%) 11.05% 9.12% 11.05% 10.22% Total Including Losses 54,733 55,875 1,142 55,085 57,799 2,714

Domestic Revenues ($ million)Residential 1,018.0 1,015.8 (2.2) 1,032.0 1,045.6 13.6Light Industrial and Commercial 948.0 967.2 19.2 958.0 989.2 31.2Large Industrial 526.0 573.0 47.0 521.0 584.0 63.0Other 88.6 87.4 (1.2) 89.9 91.4 1.5Total 2,580.6 2,643.4 62.8 2,600.9 2,710.2 109.3

Average Price ($/MWh) 42.9 53.7 10.8 40.6 67.6 27.0

Load Variance ($ million) Price 12.3 73.2Load 49.0 110.2Total 61.3 183.4

Less Incremental Revenue ($ million) (62.8) (109.3)

Net Impact of Load Variance ($ million) (1.5) 74.1

F2005 F2006


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Exhibit: B-16

11.0 Reference: BCUC 1.01 – Triple Bottom Line Report

2.11.1 Does the BC Budget Transparency and Accountability Act require a crown corporation to produce a Triple Bottom Line report?

RESPONSE: No.


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Exhibit: B-16


2.11.2 Which Area of BC Hydro is responsible for producing the Triple Bottom Line Report?

RESPONSE: Communications.


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Exhibit: B-16


2.11.3 What is the estimated additional cost of producing a Triple Bottom Line report and ensuring that BC Hydro meets the reporting standards set out in Global Reporting Initiative 2002 as opposed to an Annual Financial report?

RESPONSE: The incremental cost to produce the Triple Bottom Line report is not significant and is not tracked.


Page 1


Exhibit: B-16


2.11.4 Does the BC Hydro’s focus on the Triple Bottom Line lead to any reductions in the cost of producing and delivering electricity?

RESPONSE: BC Hydro believes that better business decisions result by looking at the three bottom lines together and understanding that what happens in one area has effects on the others, which results in lower long-term costs. The triple bottom line approach is outlined in the attachment.

BC Hydro - Policies - Three Bottom Lines Page 1 of 1

Three Bottom LinesBC Hydro is accountable to British Columbians to take care ofthe environment, meet community needs and deliver excellent

financial results. As such, we are committed to a path ofsustain abilty whereby we balance, track and measure our

performance along environmental, social and economic bottomlines. We believe better business decisions result by looking atthese three bottom lines together and understanding that what

happens in one area has effects on the others.

Our environmental bottom line looks at how we manage impactsfrom our operations, weigh environmental values with economicones and plan for a future with more green energy in our system.

Our social bottom line includes how we ensure the safety andwell-being of people - our employees, customers and the generalpublic - and the health of the communities in which we live and

work.

Our economic bottom line means making it possible to stay inbusiness forever, by being an efficient, productive and profitable

company and by providing value to our customers and theprOVInce.

Last Modified: Octoper 27, 2005Copyright (Q 2006 BC Hydro, All rights reserved.

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Exhibit: B-16

12.0 Reference: BCUC 1.120 – Long Term Goal – Social

2.12.1 Please provide the list of values a supplier must demonstrate in order to do business with BC Hydro and identify the source of the list.



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Exhibit: B-16

12.0 Reference: BCUC 1.120 – Long Term Goal – Social

2.12.2 Can BC Hydro identify any circumstances where BC Hydro would refuse to do business with a supplier in spite of the fact that the supplier meets all laws and regulations of the jurisdiction where the supplier operates?



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Exhibit: B-16

13.0 Reference: BCUC 1.263.4

2.13.0 Please provide a description of the activities the Stakeholder Engagement Department is presently working on and plan to work on over the remainder 2006/2007 fiscal year.

RESPONSE: Through the remainder of the fiscal year the activities the Stakeholder Engagement Department will work on include:

• Integrated Electricity Plan (IEP) Implementation

• Planning for 2007 Call for Tender

• Non-Treaty Storage Agreement

• Conservation Research Initiative

• Advanced Metering Infrastructure

• Revelstoke 5

• Principles for Youth Engagement

• Electricity Conservation & Efficiency Advisory Committee

• 2007 Conservation Potential Review

• Rate Design Application

• Long Term Rate Strategy


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Exhibit: B-16

14.0 Reference: Exhibit B-5-4, Sheet 1 (“Revenue Requirements Summary”) line

12.

2.14.0 What are the market conditions that BC Hydro believes will cause Powerex net income to decline by 25.664 per cent from 2005 to 2006?

RESPONSE: Please refer to response to BCUC IR 1.284.0.

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