MainPower New Zealand Limited. Asset Management Plan

Transcription

1 MainPower New Zealand Limited. Asset Management Plan

2 MAINPOWER NEW ZEALAND LIMITED ASSET MANAGEMENT PLAN UPDATE MainPower New Zealand Limited Asset Management Plan Update P a g e 1

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4 Asset Management Plan Update for MainPower New Zealand Limited Planning Period: 1 April 2015 to 31 March 2025 Disclosure Year: Disclosure Date: 31 March 2015 Approved by Board: 3 March 2015 MainPower New Zealand Limited PO Box 346 Rangiora 7440 Website: Telephone: Facsimile: The owner and custodian of this document is the Network Division of MainPower New Zealand. All comments, queries and suggestions should be forwarded to the Engineering Manager. MainPower New Zealand Limited Asset Management Plan Update P a g e 3

5 CONTENTS ASSET MANAGEMENT PLAN UPDATE Scope of this Document Material Changes to the Network Development Plans Subtransmission System Distribution Development Material Changes to Life Cycle Asset Management Reasons for Material Changes to Forecast Expenditure (Schedules 11a and 11b) Capital Expenditure - Current Year Capital Expenditure - Future Forecasts Operational Expenditure - Current Year Operational Expenditure - Future Forecasts Changes to Asset Management Practices Disclosure Schedules 11a, 11b, 12a, 12b, 12c, 12d, 14a and MainPower New Zealand Limited Asset Management Plan Update P a g e 4

6 Liability Disclaimer This document has been produced and disclosed in accordance with the disclosure requirements under subpart 9 of Part 4 of the Commerce Act 1986 (Electricity Information Disclosure Determination 2012). Any information contained in this document is based on information available at the time of preparation. Numerous assumptions have been made to allow future resource requirements to be assessed. These assumptions may prove to be incorrect or inaccurate and consequently any of the future actions that are identified in this document may not occur. People use information contained in this document at their own risk. MainPower New Zealand Limited will not be liable to compensate any person for loss, injury or damage resulting from the use of the contents of this document. If any person wishes to take any action on the basis of the content of this document, they should contact MainPower New Zealand Limited for advice and confirmation of all relevant details before acting. MainPower New Zealand Limited Asset Management Plan Update P a g e 5

7 ASSET MANAGEMENT PLAN UPDATE 1.0 Scope of this Document In particular disclosure years, the Commerce Commission s Electricity Information Disclosure Determination 2012 allows a distribution lines company to prepare and disclose an Asset Management Plan Update rather than a full Asset Management Plan (AMP). The 31 st March 2015 disclosure date is one of these occasions when an update is permitted provided that a full AMP was disclosed the previous year. MainPower New Zealand Limited disclosed a full AMP in 2014 and has chosen to issue an AMP Update for the 31 st March 2015 disclosure period. This document is the MainPower New Zealand Limited electricity network Asset Management Plan Update. It presumes that the reader has examined the MainPower New Zealand Limited AMP and it provides details of material incremental changes to that plan. The layout of the document headings follows clause of the Electricity Distribution Information Disclosure Determination Material Changes to the Network Development Plans The Network Development Program is outlined in section 4.11 of the AMP. 2.1 Subtransmission System Swannanoa and Burnt Hill Substations The payment for several large items of plant was delayed and the expenditure has increased by $1m however the overall completed project cost and time remains unchanged. Culverden Grid Exit Point ( GXP ) Upgrade Transpower completed a Grid Reliability Standard assessment of Culverden GXP upgrade proposals. This highlighted that it was more economic to find a more staged solution to the issues rather than committing to a higher cost upgrade solution in the short term. This maximised the value of the existing 220/33kV transformers. The proposed upgrade path is for MainPower to install a new 40 MVA transformer at the Culverden GXP and an associated control building and switchboard to provide additional capacity and security. Provision will be made for a second 40 MVA transformer in the future. The existing Mouse Point substation will be retained for the medium term. The preferred solution is for MainPower to purchase the related assets at the GXP and for the asset ownership boundary to move to the 33kV incoming circuit breakers. A Solution Study Report for this solution will be prepared by Transpower by August 2015, with a target commissioning date of August The projected Transpower expenditure of $9m has been revised to $1m. MainPower s projected expenditure has been revised to $1m and $2m. MainPower New Zealand Limited Asset Management Plan Update P a g e 6

8 Rangiora East GXP MainPower had planned for Transpower to build a new Rangiora East GXP under their existing 66kV double circuit line east of Rangiora. It has proved very difficult to secure suitable land. MainPower is currently reviewing the options for creating this substation with the preferred solution now for MainPower to build a 66kV circuit between Southbrook and Ashley and to build a new Rangiora East Zone substation further from the Transpower lines. Transpower is currently investigating the impact of integrating this configuration into the North Canterbury network as part of an overall North Canterbury capacity study. The projected Transpower expenditure has been revised to $1.5m in for the 66kV connections at Ashley and Southbrook. The projected MainPower zone substation expenditure has been increased to $3m in and $3.5m in A further $0.5m has been budgeted in each of , & for the 66kV line build. Subtransmission Line Strengthening The upgrading of the Waipara Hawarden and Culverden Hanmer 33kV lines has been delayed until after the completion of the proposed Ashley Southbrook 66kV line for the Rangiora East substation. This will result in the existing elevated risk of failure under snow loadings continuing for an additional two years. 2.2 Distribution Development Rangiora West 22kV Conversion The budget for this for has been increased from $1.2m to $2.2m and work will now be completed at the end of this year. The total life projected expenditure for the Rangiora West Upgrade remains the same. DG Related Upgrades The budget provision for DG related upgrades has been incorporated into the Customer Network Extensions. Snow Strengthening Work to increase the strength of existing weaker lines in higher snow loading areas has been delayed by 2 years and will now start in Material Changes to Life Cycle Asset Management The only material change to life cycle management activities is a 30% increase in the budget for vegetation management from onwards. This is due to both the high incidence of tree faults in recent major storms and the increased public awareness of the issue leading to more co-operation from landowners in allowing trees to be cut. MainPower New Zealand Limited Asset Management Plan Update P a g e 7

9 4.0 Reasons for Material Changes to Forecast Expenditure (Schedules 11a and 11b) 4.1 Capital Expenditure - Current Year The Consumer Connection expenditure is expected to be $0.7m above budget due to the slower than expected taper off of post-earthquake residential development and accelerated conversion of the Eyrewell forest area to irrigation. System Growth is slightly above budget due to the need to ensure capacity constraints in 2015 can be relieved. Asset Replacement and renewal will be $1m below budget in the overhead line renewal program. This is due a resource shortfall due to the higher than expected Consumer Connection expenditure winter storms causing a high level of service restoration work (additional $0.3m). MainPower has contracted external resources to try to address this shortfall. 4.2 Capital Expenditure - Future Forecasts The escalation factors from constant to nominal values have been reviewed and more conservative data provided by Westpac used for the update. The System Growth forecasts have changed due to the network development changes presented above. The Quality of Supply forecasts have changed due to the slower project timeline for the strengthening of subtransmission and distribution lines. Expenditure on Underground Conversion for has increased from $0.2m to $ 0.6m due to an increased focus on removing old higher risk urban overhead low voltage lines. 4.3 Operational Expenditure - Current Year Service Interruptions and Emergencies expenditure will be $0.3m above budget due to storms. 4.4 Operational Expenditure - Future Forecasts The escalation factors from constant to nominal values have been reviewed and more conservative data provided by Westpac used for the update. As noted above, the provision for Vegetation Management has been increased by 30% for future years. 5.0 Changes to Asset Management Practices There have been no material changes to asset management practices during the last year that would affect the disclosure of Schedule 13 contents. MainPower New Zealand Limited Asset Management Plan Update P a g e 8

10 6.0 Disclosure Schedules 11a, 11b, 12a, 12b, 12c, 12d, 14a and 15 MainPower has chosen not to disclose Schedule 13 as is permitted in the Disclosure Determination. The disclosed schedules have been completed based on information available at 31 December 2014 scaled for end of year forecasts. MainPower New Zealand Limited Asset Management Plan Update P a g e 9

11 SCHEDULE 11a: REPORT ON FORECAST CAPITAL EXPENDITURE Company Name AMP Planning Period MainPower New Zealand Limited 1 April March 2025 This schedule requires a breakdown of forecast expenditure on assets for the current disclosure year and a 10 year planning period. The forecasts should be consistent with the supporting information set out in the AMP. The forecast is to be expressed in both constant price and nominal dollar terms. Also required is a forecast of the value of commissioned assets (i.e., the value of RAB additions) EDBs must provide explanatory comment on the difference between constant price and nominal dollar forecasts of expenditure on assets in Schedule 14a (Mandatory Explanatory Notes). This information is not part of audited disclosure information. sch ref 7 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 CY+6 CY+7 CY+8 CY+9 CY+10 8 for year ended 31 Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar a(i): Expenditure on Assets Forecast $000 (in nominal dollars) 10 Consumer connection 9,499 9,000 8,295 7,613 7,357 7,497 7,646 7,807 7,979 8,170 8, System growth 10,322 6,915 5,233 4,126 5,949 5,304 5,410 5,524 5,069 5,191 5, Asset replacement and renewal 2,139 3,312 4,013 3,965 3,894 4,022 4,158 4,304 4,460 4,631 4, Asset relocations Reliability, safety and environment: 15 Quality of supply ,851 2,178 2,057 1,546 1,578 1,613 1,652 1, Legislative and regulatory Other reliability, safety and environment Total reliability, safety and environment 421 1,514 1,126 3,426 2,656 2,544 2,043 2,085 2,131 2,182 1, Expenditure on network assets 22,381 20,740 18,667 19,130 19,855 19,366 19,257 19,720 19,639 20,174 20, Non-network assets 1,862 2,737 2,969 3,029 5,372 3,417 3,486 4,131 3,826 4,036 4, Expenditure on assets 24,243 23,478 21,636 22,159 25,227 22,783 22,743 23,851 23,465 24,210 24, plus Cost of financing less Value of capital contributions 5,700 5,400 4,977 4,569 4,414 4,498 4,588 4,684 4,787 4,902 5, plus Value of vested assets Capital expenditure forecast 18,543 18,078 16,659 17,590 20,813 18,285 18,155 19,167 18,678 19,308 19, Value of commissioned assets 20,543 18,194 17,014 17,357 20,007 18,917 18,188 18,914 18,800 19,150 19, Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 CY+6 CY+7 CY+8 CY+9 CY+10 for year ended 31 Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar $000 (in constant prices) 33 Consumer connection 9,499 9,000 8,100 7,289 6,926 6,926 6,926 6,926 6,926 6,926 6, System growth 10,322 6,915 5,110 3,950 5,600 4,900 4,900 4,900 4,400 4,400 4, Asset replacement and renewal 2,139 3,312 3,919 3,797 3,666 3,715 3,766 3,818 3,871 3,925 3, Asset relocations Reliability, safety and environment: 38 Quality of supply ,730 2,050 1,900 1,400 1,400 1,400 1,400 1, Legislative and regulatory Other reliability, safety and environment Total reliability, safety and environment 421 1,514 1,100 3,280 2,500 2,350 1,850 1,850 1,850 1,850 1, Expenditure on network assets 22,381 20,740 18,229 18,315 18,692 17,892 17,442 17,494 17,047 17,101 16, Non-network assets 1,862 2,737 2,900 2,900 5,057 3, Expenditure on assets 24,243 23,478 21,129 21,215 23,749 21,049 17,442 17,494 17,047 17,101 16, Subcomponents of expenditure on assets (where known) 47 Energy efficiency and demand side management, reduction of energy losses Overhead to underground conversion Research and development MainPower New Zealand Limited Asset Management Plan Update P a g e 10

12 57 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 CY+6 CY+7 CY+8 CY+9 CY for year ended 31 Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Difference between nominal and constant price forecasts $ Consumer connection ,053 1,245 1, System growth Asset replacement and renewal Asset relocations Reliability, safety and environment: 65 Quality of supply Legislative and regulatory Other reliability, safety and environment Total reliability, safety and environment Expenditure on network assets ,163 1,475 1,815 2,226 2,592 3,073 3, Non-network assets ,486 4,131 3,826 4,036 4, Expenditure on assets ,478 1,735 5,301 6,357 6,418 7,109 7, Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 for year ended 31 Mar Mar Mar Mar Mar Mar a(ii): Consumer Connection 75 Consumer types defined by EDB* $000 (in constant prices) 76 Residential 4,935 4,660 4,390 3,964 3,611 3, Other 1,484 1,495 1,380 1,300 1,242 1, Irrigation 2,800 2,550 2,250 2,025 1,993 1, Street light Large User Daiken DG *include additional rows if needed 82 Consumer connection expenditure 9,499 9,000 8,100 7,289 6,926 6, less Capital contributions funding consumer connection 5,643 5,346 4,811 4,330 4,114 4, Consumer connection less capital contributions 3,856 3,654 3,289 2,958 2,812 2, a(iii): System Growth 86 Subtransmission 2,427 1, Zone substations 2, ,500 1,900 3,000 3, Distribution and LV lines 1,162 1, Distribution and LV cables 1,162 1, Distribution substations and transformers 406 1, Distribution switchgear Other network assets 2, System growth expenditure 10,322 6,915 5,110 3,950 5,600 4, less Capital contributions funding system growth System growth less capital contributions 10,265 6,861 5,061 3,906 5,558 4,858 MainPower New Zealand Limited Asset Management Plan Update P a g e 11

13 103 Current Year CY CY+1 CY+2 CY+3 CY+4 CY for year ended 31 Mar Mar Mar Mar Mar Mar a(iv): Asset Replacement and Renewal $000 (in constant prices) 106 Subtransmission Zone substations Distribution and LV lines 593 1,102 1,160 1,181 1,207 1, Distribution and LV cables 593 1,102 1,160 1,181 1,207 1, Distribution substations and transformers Distribution switchgear Other network assets Asset replacement and renewal expenditure 2,139 3,312 3,919 3,797 3,666 3, less Capital contributions funding asset replacement and renewal Asset replacement and renewal less capital contributions 2,139 3,312 3,919 3,797 3,666 3, a(v):Asset Relocations 117 Project or programme* 118 Rangiora East 33kV relocation [Description of material project or programme] [Description of material project or programme] [Description of material project or programme] [Description of material project or programme] *include additional rows if needed 124 All other asset relocations projects or programmes Asset relocations expenditure less Capital contributions funding asset relocations Asset relocations less capital contributions a(vi):Quality of Supply 130 Project or programme* 131 Waipara Kaikoura 66kV , ABS replacement with controlled switches Network Automation Snow strengthening Culverden Hanmer 33kV Substation resonant earthing *include additional rows if needed 137 All other quality of supply projects or programmes Quality of supply expenditure ,730 2,050 1, less Capital contributions funding quality of supply Quality of supply less capital contributions ,730 2,050 1, a(vii): Legislative and Regulatory 143 Project or programme* 144 [Description of material project or programme] [Description of material project or programme] 146 [Description of material project or programme] 147 [Description of material project or programme] 148 [Description of material project or programme] 149 *include additional rows if needed 150 All other legislative and regulatory projects or programmes Legislative and regulatory expenditure less Capital contributions funding legislative and regulatory Legislative and regulatory less capital contributions MainPower New Zealand Limited Asset Management Plan Update P a g e 12

14 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 for year ended 31 Mar Mar Mar Mar Mar Mar a(viii): Other Reliability, Safety and Environment 164 Project or programme* $000 (in constant prices) 165 Underground conversion [Description of material project or programme] 167 [Description of material project or programme] 168 [Description of material project or programme] 169 [Description of material project or programme] 170 *include additional rows if needed 171 All other reliability, safety and environment projects or programmes Other reliability, safety and environment expenditure less Capital contributions funding other reliability, safety and environment Other reliability, safety and environment less capital contributions a(ix): Non-Network Assets 179 Routine expenditure 180 Project or programme* 181 Buildings Motor Vehicles 721 1,195 1,200 1,200 1,350 1, Plant Computers ,000 1,000 3,000 1, [Description of material project or programme] 186 *include additional rows if needed 187 All other routine expenditure projects or programmes Routine expenditure 1,862 2,737 2,900 2,900 5,057 3, Atypical expenditure 190 Project or programme* 191 [Description of material project or programme] [Description of material project or programme] 193 [Description of material project or programme] 194 [Description of material project or programme] 195 [Description of material project or programme] 196 *include additional rows if needed 197 All other atypical projects or programmes Atypical expenditure Non-network assets expenditure 1,862 2,737 2,900 2,900 5,057 3,157 MainPower New Zealand Limited Asset Management Plan Update P a g e 13

15 SCHEDULE 11b: REPORT ON FORECAST OPERATIONAL EXPENDITURE sch ref Company Name AMP Planning Period MainPower New Zealand Limited 1 April March 2025 This schedule requires a breakdown of forecast operational expenditure for the disclosure year and a 10 year planning period. The forecasts should be consistent with the supporting information set out in the AMP. The forecast is to be expressed in both constant price and nominal dollar terms. EDBs must provide explanatory comment on the difference between constant price and nominal dollar operational expenditure forecasts in Schedule 14a (Mandatory Explanatory Notes). This information is not part of audited disclosure information. 7 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 CY+6 CY+7 CY+8 CY+9 CY+10 8 for year ended 31 Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar 25 9 Operational Expenditure Forecast $000 (in nominal dollars) 10 Service interruptions and emergencies 1, ,015 1,053 1,094 1,139 1,186 1,236 1,236 1, Vegetation management ,000 1,041 1,085 1,085 1, Routine and corrective maintenance and inspection 1,664 1,559 1,640 1,707 1,770 1,840 1,914 1,994 2,078 2,078 2, Asset replacement and renewal Network Opex 3,804 3,535 3,640 3,786 3,927 4,080 4,189 4,362 4,548 4,548 4, System operations and network support 3,145 3,121 3,217 3,357 3,554 3,824 4,188 4,673 5,318 6,191 7, Business support 4,621 4,586 4,726 4,933 5,222 5,619 6,153 6,865 7,814 9,096 10, Non-network opex 7,766 7,707 7,943 8,290 8,776 9,443 10,341 11,538 13,132 15,287 18, Operational expenditure 11,570 11,242 11,583 12,076 12,703 13,523 14,530 15,900 17,680 19,835 22, Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 CY+6 CY+7 CY+8 CY+9 CY for year ended 31 Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar $000 (in constant prices) 22 Service interruptions and emergencies 1, ,011 1,031 1,052 1,073 1,073 1, Vegetation management Routine and corrective maintenance and inspection 1,664 1,559 1,602 1,634 1,667 1,700 1,734 1,769 1,804 1,804 1, Asset replacement and renewal Network Opex 3,804 3,535 3,555 3,625 3,697 3,770 3,794 3,870 3,947 3,947 4, System operations and network support 3,145 3,121 3,142 3,214 3,346 3,533 3,793 4,141 4,603 5,233 6, Business support 4,621 4,586 4,615 4,723 4,916 5,191 5,573 6,084 6,763 7,688 8, Non-network opex 7,766 7,707 7,757 7,937 8,262 8,724 9,366 10,225 11,365 12,920 15, Operational expenditure 11,570 11,242 11,312 11,562 11,959 12,494 13,160 14,095 15,313 16,868 19, Subcomponents of operational expenditure (where known) Direct billing* 35 Research and Development 36 Insurance 37 * Direct billing expenditure by suppliers that direct bill the majority of their consumers 38 Energy efficiency and demand side management, reduction of energy losses 39 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 CY+6 CY+7 CY+8 CY+9 CY for year ended 31 Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Mar Difference between nominal and real forecasts $ Service interruptions and emergencies Vegetation management Routine and corrective maintenance and inspection Asset replacement and renewal Network Opex System operations and network support , Business support ,051 1,408 1, Non-network opex ,313 1,767 2,367 3, Operational expenditure ,030 1,370 1,805 2,367 2,967 3,904 MainPower New Zealand Limited Asset Management Plan Update P a g e 14

16 SCHEDULE 12a: REPORT ON ASSET CONDITION Company Name AMP Planning Period MainPower New Zealand Limited 1 April March 2025 This schedule requires a breakdown of asset condition by asset class as at the start of the forecast year. The data accuracy assessment relates to the percentage values disclosed in the asset condition columns. Also required is a forecast of the percentage of units to be replaced in the next 5 years. All information should be consistent with the information provided in the AMP and the expenditure on assets forecast in Schedule 11a. All units relating to cable and line assets, that are expressed in km, refer to circuit lengths. sch ref Asset condition at start of planning period (percentage of units by grade) Voltage Asset category Asset class Units Grade 1 Grade 2 Grade 3 Grade 4 Grade unknown 10 All Overhead Line Concrete poles / steel structure No % 23.58% 57.84% 18.57% % 11 All Overhead Line Wood poles No. 0.03% 0.84% 26.68% 52.66% 19.79% % 12 All Overhead Line Other pole types No. [Select one] 13 HV Subtransmission Line Subtransmission OH up to 66kV conductor km % 23.65% % 14 HV Subtransmission Line Subtransmission OH 110kV+ conductor km [Select one] 15 HV Subtransmission Cable Subtransmission UG up to 66kV (XLPE) km % 36.47% % 16 HV Subtransmission Cable Subtransmission UG up to 66kV (Oil pressurised) km [Select one] 17 HV Subtransmission Cable Subtransmission UG up to 66kV (Gas pressurised) km [Select one] 18 HV Subtransmission Cable Subtransmission UG up to 66kV (PILC) km [Select one] 19 HV Subtransmission Cable Subtransmission UG 110kV+ (XLPE) km [Select one] 20 HV Subtransmission Cable Subtransmission UG 110kV+ (Oil pressurised) km [Select one] 21 HV Subtransmission Cable Subtransmission UG 110kV+ (Gas Pressurised) km [Select one] 22 HV Subtransmission Cable Subtransmission UG 110kV+ (PILC) km [Select one] 23 HV Subtransmission Cable Subtransmission submarine cable km [Select one] 24 HV Zone substation Buildings Zone substations up to 66kV No % 13.33% % 25 HV Zone substation Buildings Zone substations 110kV+ No. [Select one] 26 HV Zone substation switchgear 22/33kV CB (Indoor) No % 27 HV Zone substation switchgear 22/33kV CB (Outdoor) No % 80.00% % 28 HV Zone substation switchgear 33kV Switch (Ground Mounted) No. [Select one] 29 HV Zone substation switchgear 33kV Switch (Pole Mounted) No % 27.14% % 30 HV Zone substation switchgear 33kV RMU No. [Select one] 31 HV Zone substation switchgear 50/66/110kV CB (Indoor) No % 10.00% - [Select one] 32 HV Zone substation switchgear 50/66/110kV CB (Outdoor) No % 44.83% HV Zone substation switchgear 3.3/6.6/11/22kV CB (ground mounted) No % 21.95% % 34 HV Zone substation switchgear 3.3/6.6/11/22kV CB (pole mounted) No % 88.00% % Data accuracy (1 4) % of asset forecast to be replaced in next 5 years MainPower New Zealand Limited Asset Management Plan Update P a g e 15

17 Asset condition at start of planning period (percentage of units by grade) Voltage Asset category Asset class Units Grade 1 Grade 2 Grade 3 Grade 4 Grade unknown 45 HV Zone Substation Transformer Zone Substation Transformers No % 30.77% % 46 HV Distribution Line Distribution OH Open Wire Conductor km % 11.58% % 47 HV Distribution Line Distribution OH Aerial Cable Conductor km [Select one] 48 HV Distribution Line SWER conductor km % 3.76% HV Distribution Cable Distribution UG XLPE or PVC km % 61.70% % 50 HV Distribution Cable Distribution UG PILC km % 2.02% HV Distribution Cable Distribution Submarine Cable km [Select one] 52 HV Distribution switchgear 3.3/6.6/11/22kV CB (pole mounted) - reclosers and sectionalisers No % 48.39% % 53 HV Distribution switchgear 3.3/6.6/11/22kV CB (Indoor) No % 50.00% HV Distribution switchgear 3.3/6.6/11/22kV Switches and fuses (pole mounted) No % 25.87% % 55 HV Distribution switchgear 3.3/6.6/11/22kV Switch (ground mounted) - except RMU No. [Select one] 56 HV Distribution switchgear 3.3/6.6/11/22kV RMU No % 36.04% % 57 HV Distribution Transformer Pole Mounted Transformer No % 28.97% % 58 HV Distribution Transformer Ground Mounted Transformer No % 43.77% % 59 HV Distribution Transformer Voltage regulators No % 10.00% HV Distribution Substations Ground Mounted Substation Housing No % 30.28% % 61 LV LV Line LV OH Conductor km % 4.34% % 62 LV LV Cable LV UG Cable km % 40.66% LV LV Streetlighting LV OH/UG Streetlight circuit km % 28.58% % 64 LV Connections OH/UG consumer service connections No % 31.16% % 65 All Protection Protection relays (electromechanical, solid state and numeric) No % 47.02% 16.89% % 66 All SCADA and communications SCADA and communications equipment operating as a single system Lot % 81.40% 13.37% % 67 All Capacitor Banks Capacitors including controls No. [Select one] 68 All Load Control Centralised plant Lot % All Load Control Relays No % 25.50% % 70 All Civils Cable Tunnels km [Select one] Data accuracy (1 4) % of asset forecast to be replaced in next 5 years MainPower New Zealand Limited Asset Management Plan Update P a g e 16

18 SCHEDULE 12b: REPORT ON FORECAST CAPACITY This schedule requires a breakdown of current and forecast capacity and utilisation for each zone substation and current distribution transformer capacity. The data provided should be consistent with the information provided in the AMP. Information provided in this table should relate to the operation of the network in its normal steady state configuration. Company Name MainPower New Zealand Limited AMP Planning Period 1 April March 2025 sch ref 7 12b(i): System Growth - Zone Substations 8 Existing Zone Substations Current Peak Load (MVA) Installed Firm Capacity (MVA) Security of Supply Classification (type) Transfer Capacity (MVA) Utilisation of Installed Firm Capacity % Installed Firm Capacity +5 years (MVA) Utilisation of Installed Firm Capacity + 5yrs % 9 Southbrook N-1 switched 2 112% % Transformer Installed Firm Capacity Constraint +5 years (cause) 10 Cust 5 - N-1 switched* N/A Sub-transmission circuit * with irrig. load control, decommission Bennetts 5 4 N-1 switched* 2 128% - N/A Sub-transmission circuit * with irrig. load control, decommission Oxford 8 - N-1 switched* N/A Sub-transmission circuit * with irrig. load control, decommission Swannanoa 9 12 N-1 switched 3 78% 23 70% No constraint within +5 years 14 Rangiora North 6 - N-1 switched N/A Transformer 15 Amberley 6 4 N-1 switched 2 145% 4 150% Transformer 16 MacKenzies Rd 2 - N-1 switched N/A Transformer 17 Greta 1 - N N/A Transformer 18 Cheviot 3 - N N/A Transformer 19 Leader 1 - N-1 switched* N/A Transformer * with irrig. load control 20 Oaro 0 - N N/A Transformer decommission Ludstone Rd 6 6 N-1 switched** - 97% 6 100% Transformer ** With load control 22 Hawarden 3 - N-1 switched* N/A Transformer * with irrig. load control, decommission Mouse Point N-1 switched* 2 142% % Transformer 24 Marble Quarry 0 - N N/A Transformer 25 Lochiel 0 - N N/A Transformer 26 Hanmer 5 3 N - 184% 6 90% Transformer 27 Burnt Hill - N-1 switched % No constraint within +5 years Planned for 2015/ [Select one] 29 ¹ Extend forecast capacity table as necessary to disclose all capacity by each zone substation 30 12b(ii): Transformer Capacity 31 (MVA) 32 Distribution transformer capacity (EDB owned) Distribution transformer capacity (Non-EDB owned) 7 34 Total distribution transformer capacity Zone substation transformer capacity 118 Explanation MainPower New Zealand Limited Asset Management Plan Update P a g e 17

19 SCHEDULE 12C: REPORT ON FORECAST NETWORK DEMAND Company Name AMP Planning Period MainPower New Zealand Limited 1 April March 2025 This schedule requires a forecast of new connections (by consumer type), peak demand and energy volumes for the disclosure year and a 5 year planning period. The forecasts should be consistent with the supporting information set out in the AMP as well as the assumptions used in developing the expenditure forecasts in Schedule 11a and Schedule 11b and the capacity and utilisation forecasts in Schedule 12b. sch ref 7 12c(i): Consumer Connections 8 Number of ICPs connected in year by consumer type Number of connections 9 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 10 for year ended 31 Mar Mar Mar Mar Mar Mar Consumer types defined by EDB* 12 Residential 1, Other Irrigation Street light Large User Connections total 1,235 1,115 1, *include additional rows if needed 19 Distributed generation 20 Number of connections Installed connection capacity of distributed generation (MVA) c(ii) System Demand 23 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 24 Maximum coincident system demand (MW) for year ended 31 Mar Mar Mar Mar Mar Mar GXP demand plus Distributed generation output at HV and above Maximum coincident system demand less Net transfers to (from) other EDBs at HV and above (1) Demand on system for supply to consumers' connection points Electricity volumes carried (GWh) 31 Electricity supplied from GXPs less Electricity exports to GXPs plus Electricity supplied from distributed generation less Net electricity supplied to (from) other EDBs (5) Electricity entering system for supply to ICPs less Total energy delivered to ICPs Losses Load factor 69% 70% 70% 71% 72% 72% 40 Loss ratio 5.5% 5.4% 5.3% 5.3% 5.3% 5.3% MainPower New Zealand Limited Asset Management Plan Update P a g e 18

20 SCHEDULE 12d: REPORT FORECAST INTERRUPTIONS AND DURATION sch ref Company Name AMP Planning Period Network / Sub-network Name MainPower New Zealand Limited 1 April March 2025 This schedule requires a forecast of SAIFI and SAIDI for disclosure and a 5 year planning period. The forecasts should be consistent with the supporting information set out in the AMP as well as the assumed impact of planned and unplanned SAIFI and SAIDI on the expenditures forecast provided in Schedule 11a and Schedule 11b. 8 Current Year CY CY+1 CY+2 CY+3 CY+4 CY+5 9 for year ended 31 Mar Mar Mar Mar Mar Mar SAIDI 11 Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) SAIFI 14 Class B (planned interruptions on the network) Class C (unplanned interruptions on the network) MainPower New Zealand Limited Asset Management Plan Update P a g e 19

21 Company Name MainPower New Zealand Limited For Year Ended 2015 Schedule 14a Mandatory Explanatory Notes on Forecast Information (In this Schedule, clause references are to the Electricity Distribution Information Disclosure Determination 2012) 1. This Schedule provides for EDBs to provide explanatory notes to reports prepared in accordance with clause This Schedule is mandatory EDBs must provide the explanatory comment specified below, in accordance with clause This information is not part of the audited disclosure information, and so is not subject to the assurance requirements specified in section 2.8. Commentary on difference between nominal and constant price capital expenditure forecasts (Schedule 11a) 3. In the box below, comment on the difference between nominal and constant price capital expenditure for the disclosure year, as disclosed in Schedule 11a. Box 1: Commentary on difference between nominal and constant price capital expenditure forecasts The escalation factors from constant to nominal prices have changed from the 2014 plan and are based on Westpacs inflation forecasts dated the 12 January 2015 which are around 2% per annum. Commentary on difference between nominal and constant price operational expenditure forecasts (Schedule 11b) 4. In the box below, comment on the difference between nominal and constant price operational expenditure for the disclosure year, as disclosed in Schedule 11b. Box 2: Commentary on difference between nominal and constant price operational expenditure forecasts The escalation factors from constant to nominal prices have changed from the 2014 plan and are based on Westpacs inflation forecasts dated the 12 January 2015 which are around 2% per annum. MainPower New Zealand Limited Asset Management Plan Update P a g e 20

22 Company Name MainPower New Zealand Limited For Year Ended 2015 Schedule 15 Voluntary Explanatory Notes (In this Schedule, clause references are to the Electricity Distribution Information Disclosure Determination 2012) 5. This Schedule enable EDBs to provide, should they wish to- 5.1 additional explanatory comment to reports prepared in accordance with clauses 2.3.1, , , 2.5.1, 2.5.2, and 2.6.5; 5.2 information on any substantial changes to information disclosed in relation to a prior disclosure year, as a result of final wash-ups. 6. Information in this Schedule is not part of the audited disclosure information, and so is not subject to the assurance requirements specified in section Provide additional explanatory comment in the box below. Box 1: Voluntary explanatory comment on disclosed information With respect to Schedule 11A Forecast Capital Expenditure the value of Expenditure on Network Assets and Commissioned Assets exclude the sale of the Wigram Network Distribution System to Orion which places on the 31 March The Regulatory Asset base of Wigram at 31 March 2015 is estimated to be $900,000. MainPower New Zealand Limited Asset Management Plan Update P a g e 21