appendix 1: ac modern equivalent assets and replacement costs · 77 appendix 1: ac modern...

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Appendix 1: AC Modern Equivalent Assets and Replacement Costs

1.1 Detailed Design Assumptions 1.1.1 Assumptions Common to Generic Substation Building Blocks

Sizes of substations are categorised as follows:

Category No. of HV bays

Major 14 Medium 8 Small 6 Rural 2

It was assumed that there were to be no gantries and all busbars were to be of rigid tubular aluminium. “Worse case” dimensions have been applied, e.g. 33kV as opposed to 11 kV switchgear was used to dimension the switchgear room. All assumptions and design parameters are based on “best practice” principles as if the project was to be built today. Designs are based on Transpower’s current practice.

1.1.2 Building Blocks for AC Substations - Buildings

Generic Buildings Building Blocks Identified A suitable Building building block was designed for each of the following substation types:

1. Major outdoor, 2. Major indoor, 3. Medium outdoor, 4. Small outdoor, 5. Rural outdoor, and 6. Rural indoor.

Specific Buildings Building Blocks Identified Due to the specific nature of the buildings, the Building costs for the following stations were assessed individually.

1. Tiwai 2. Motunui

Generic Buildings: Key Assumptions

No amenities are provided for in the building layout, i.e. no mess room, toilets, or other work space. The control room is a metal clad timber framed structure, while the switchgear room has concrete-filled block-work walls. Concrete slabs on grade are used

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with a false floor using Uni-Strut supports in the control room for panel fixing and cable entry. Switchgear room sizes have been based on the use of 33kV switchgear with dimensions of 1m wide and 2.35m deep. Total switchgear length was based on the panel widths given in Table A1.1. Table A1.1: Panel Widths Panel Type Panel

width (m)Feeder 1 Incomer 1 Bus Section 1 VT per Bus 1 Busbar connection 1

The control room size is based on:

• All panels 600 x 600 x 2200mm high, with 1200mm clearance, front and

rear, of all panels • 3 x 33 kV circuits per protection panel • 2 x 110 kV line circuits per protection panel • 1 x 220 kV line circuit per protection panel (Prot 1 & Prot 2) • 1 x transformer bank per protection • 2 x protection signalling equipment per 220 kV line • 1 x protection signalling equipment per 110 or 66 kV line • 10 x protection signalling equipment per panel • 12 panels per row • No 24 V d.c. system (communications asset)

Unique Buildings: Key Assumptions

The cost estimates have been based on detailed design drawings available in Transpower’s document system. Grades of materials and building services performance levels have been assumed to be average and typical of a standard type of switchgear building. Generally the cost estimates for the building structures include sub-floor cable ducts and normal building services. External and internal finishes such as painted surfaces have been based on assumptions and may not reflect actual finish.

1.1.3 Building Blocks for AC Substations - Power Transformers

Power Transformers Building Blocks Identified

The transformer building blocks chosen are given in Table A1.12.

BB No. = building block reference HV = nominal Voltage of High Voltage winding ID = indoor LV = nominal Voltage of Low Voltage winding TV/mva = nominal Voltage of Tertiary winding / maximum three

phase continuous rating of tertiary winding TY = vector group, as follows:

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A = auto-transformer D-S = delta-star S-S = star-star S-D = star-delta PH = number of phases per unit m = metres – distance from centre bank to protection cabinet MVA = maximum three phase continuous rating of high and low voltage

winding NCT = neutral current transformer OT = On-load tap-changer fitted.

Transformer Infrastructure and Auxiliaries Building Blocks

Transformer infrastructure building blocks were identified as detailed in Table A1.2. Table A1.2: Transformer Infrastructure Building Blocks

No. Description 1 Transformer Infrastructure I (3 phase - 30 m) 2 Transformer Infrastructure II (3 phase - 60 m) 3 Transformer Infrastructure III (3 x 1 phase 60 m) 4 Transformer Infrastructure IV (3 x 1 phase 120 m) 5 Interconnecting bank structure 3 phase 6 Interconnecting bank structure 1 phase (spare) 7 11 kV Cable for Stn Serv Transf 8 22 kV Cable for Stn Serv Transf 9 33 kV Cable for Stn Serv Transf

10 11/0.4 kV, 50 kVA Station services transformer 11 22/0.4 kV, 50 kVA Station services transformer 12 33/0.4 kV, 50 kVA Station services transformer 13 11 kV Earthing transformer 14 22 kV Earthing transformer 15 33 kV Earthing transformer 16 11 kV Zig Zag Earthing Transformer 17 22 kV Zig Zag Earthing Transformer 18 33 kV Zig Zag Earthing Transformer 19 11 kV Surge Arrester (ID) 20 22 kV Surge Arrester (ID) 21 33 kV Surge Arrester (ID) 22 50 kV Surge Arrester 23 66 kV Surge Arrester 24 110 kV Surge Arrester 25 220 kV Surge Arrester 26 11 kV Cable, 5 MVA 27 11 kV Cable, 7.5 MVA 28 11 kV Cable, 10 MVA 29 11 kV Cable, 15 MVA 30 11 kV Cable, 20 MVA 31 11 kV Cable, 30 MVA 32 11 kV Cable, 45 MVA 33 11 kV Cable, 60 MVA

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Table A1.2: Transformer Infrastructure Building Blocks No. Description 34 11 kV Cable, 100 MVA 35 22 kV Cable, 30 MVA 36 22 kV Cable, 50 MVA 37 33 kV Cable, 25 MVA 38 33 kV 10 MVA 39 33 kV 15 MVA 40 33 kV 20 MVA 41 33 kV Cable, 30 MVA 42 33 kV Cable, 50 MVA 43 33 kV Cable, 60 MVA 44 33 kV Cable, 100 MVA 45 33 kV Cable, 120 MVA 46 33 kV Cable, 200 MVA 47 11 kV Cable termination structure 48 22 kV Cable termination structure 49 33 kV Cable termination structure 50 11 kV Structure for delta bus 51 22 kV Structure for delta bus 52 33 kV Structure for delta bus 53 66 kV Structure for delta bus 54 110 kV Structure for delta bus 55 NCT 56 11 kV NCT standard 57 Two winding transformer protection 58 Three winding transformer protection 59 Residual voltage protection 60 Protection, point on wave switching relay 61 220 kV, 6000 A, 2 ohm neutral earthing resistor 62 220 kV, 3000 A, 2 ohm neutral earthing resistor 63 220 kV, 1500 A, 2 ohm neutral earthing resistor 64 220 kV, 750 A, 2 ohm neutral earthing resistor 65 66 kV, 84 ohm neutral earthing resistor 66 66 kV, 168 ohm neutral earthing resistor 67 33 kV, 42 ohm neutral earthing resistor 68 33 kV, 84 ohm neutral earthing resistor 69 22 kV, 28 ohm neutral earthing resistor 70 22 kV, 56 ohm neutral earthing resistor 71 11 kV, 14 ohm neutral earthing resistor 72 11 kV, 28 ohm neutral earthing resistor 73 20 MVA power transformer sound enclosure 74 40 MVA power transformer sound enclosure 75 80 MVA power transformer sound enclosure 76 160 MVA power transformer sound enclosure

Power Transformers: Key Assumptions Distribution (two winding) transformers are equipped with protection having the following characteristics:

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• Differential protection. The valuation assumes a digital relay that does not need interposing current transformers. This relay provides trip circuit supervision for one set of trip coils.

• No test switches or other testing facilities are assumed except for shoring of the current transformer connections when the relay is removed from the case. It is assured that the feeder protections will cover the transformer while the transformer protection relay is being tested.

• Circuit breaker control push buttons are on connection circuit protections. • MVAJ26 relay used for protection 1 (Buch) • MVAJ26 trips into the same coils as the feeder (incomer) protections.

They provide trip circuit supervision.

Interconnecting banks are equipped with protection essentially the same as for distribution transformer protection, with the following enhancements: • Three winding transformer protection relay • Residual voltage protection on the tertiary circuit. • Under impedance protection on the 110 kV and 66 kV circuits.

1.1.4 Building Blocks for AC Substations - Oil Containment

Oil Containment Building Blocks Identified

17 sizes of oil containment building block were identified as shown in Table A1.3. Table A1.3: Oil Containment Building Block Sizes

Oil containment building block No.

Volume (m3)

1 10 2 15 3 18 4 25 5 30 6 35 7 40 8 45 9 50

10 60 11 65 12 70 13 80 14 85 15 90 16 115

Oil Containment: Key Assumptions

Tank sub-grade is adequate for an allowable soil bearing pressure 100 kPa (if this cannot be obtained then over-excavation would be required at further cost) - all backfill is compacted to an allowable soil bearing pressure of 100

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kPa. Batter slope of excavation suits the stability of the material (the quantities used are based on 1 horizontal to 2½ vertical). Backfill around the tank uses imported pit sand or similar approved material (the excavated material is removed from the site). The maximum depth of material over the tank is 300 mm. Depth of water table is within 1 metre of the ground level. There is no allowance for de-watering during construction. The design allows for 2.5 kPa live load over the tank - no truck access over the tank is assumed. Formwork is the method for all concrete work (tray deck to be used as formwork for the roof, and left in place). Pump installation includes a small submersible pump plus electrical accessories, including a high level alarm connected to the area operating centre. Clean water from the pump main is reticulated to either an adjacent open stormwater drain, new soakhole or an existing piped stormwater system (no allowance has been made for soakhole system if needed). Each bund has a separate oil resistant isolating valve.

1.1.5 Building Blocks for AC Substations - Switchgear

Building Blocks for AC Substations - Switchgear

i Switchgear Building Blocks Identified

The switchgear building blocks used are listed in Table A1.14. Gas-insulated switchgear (GIS) proved to be difficult to price on a modular basis, because each GIS installation is inherently unique. Prices from last year’s valuation were used for GIS switchgear. A new term, “connection circuit”, has been introduced to refer to a circuit connecting to a capacitor bank, reactor, HV terminals of an interconnecting transformer, or HV terminals of a supply transformer.

ii Switchgear: Key Assumptions

a) General design parameters The environmental conditions assumed in the design of the switchgear building blocks are given in Table A1.4.

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Table A1.4: Environmental Assumptions

Average temperature 10 oC (winter), 19 oC (summer) Maximum wind velocity 45 m/s. Average isokeraunic level 5 days per year approximately. Mean annual rainfall 500-550 mm. Altitude > 1000 m above sea level Average rain days per year 75 days approximately. Design temperature (Outdoor Summer) 32 oC Design temperature (Outdoor Winter) -5 oC Overhead max continuous conductor temperature

70 oC

Cable max operating temperature 90 oC Short time (short circuit) temperature 250 oC Ground max temperature 20 oC Insulator creepage distance 25mm/kV

The electrical performance characteristics assumed in the design of the switchgear building blocks are given in Table A1.5.

Table A1.5: Switchgear Electrical Performance Characteristics

Nominal voltage Un (kV)

Highest system voltage Um (kV)

Type of system grounding

Rated lightning impulse

withstand -peak (kV)

Rated power

frequency withstand

(kV)

Rated fault current 3-

phase symmetrical (MVA for 3 s)

220 245 Solidly Earthed 950 395 10000 110 123 Not earthed 550 230 5000

66 72.5 Not earthed 325 140 3000 50 52 Not earthed 250 95 3000 33 36 Not earthed 170 70 1500 22 24 Not earthed 125 50 1000 11 12 Solid 28 75 500

Busbar conductors

The main bus is aluminium alloy 6060 T5/6 tube typically sized for mechanical strength as opposed to rating, with flexible jumpers between tube sections. For the transverse bus, flexible connections are predominantly used. Any sections of tube are typically sized for mechanical strength as opposed to rating. For all bus arrangements, the main bus is at a higher level than the transverse bus. For 220 kV, the bus is supported by posts either side of each bay, with flexible jumpers to the next bay, similar to the Haywards substation 220 kV bus arrangement. Tube size used is 200x6 mm. For 110, 66 and 33 kV, the bus itself is a similar arrangement, except that flexible joints are supported on a common post. Each section of tube spans two

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bays, fixed in the middle and sliding at both ends with a flexible jumper. Tube size is 140x8 mm.

Switching Equipment [HV]

Circuit breakers Circuit breakers for 66 kV and above shall be the SF6 type. The circuit breakers shall be capable of an auto-reclose duty cycle of O-(0.3)CO-(3)CO. All circuit breakers shall be the three phase type with a common mechanism, except those associated with capacitor banks and large transformers, which may have point on wave control. For 33 kV and below, indoor metalclad switchgear shall be used. The circuit breakers have the following characteristics:

Item Units 220 kV 110 kV 66 kV 33 kV 22 kV 11 kVRated voltage 245 123 72.5 36 24 12Rated current 3150 2500 2500 2500 2500 2500Short circuit breaking current kA 31.5 25 25 25 25 25Duration of short circuit sec 3 3 3 3 3 3Short circuit making current kA 80 63 63 63 63 63Duty cycle O-t-CO=t'-CO (t/t') sec 0.3/15 0.3/15 0.3/15 0.3/15 0.3/15 0.3/15First pole to clear factor 1.3 1.5 1.5 1.5 1.5 1.5Applicable standard IEC56 IEC56 IEC56 IEC56 IEC56 IEC56

Disconnectors/ Earth Switches For 66 kV and above, stand mounted, manually operated air break disconnectors are used. For some multiple bus arrangements, pantograph disconnectors are used. For 220 kV, earth switches are only provided at each end of transmission circuits for all voltage levels. In all cases, bus earth switches are provided if the earth fault level exceeds 25 kA. For 33 kV and below, disconnection and earthing are achieved within the metalclad switchboard. Item Units 220 kV 110 kV 66 kV 33 kV 22 kV 11 kVRated voltage 245 123 72.5 36 24 12Rated current 2500 2500 2500 2500 2500 2500Short circuit breaking current kA 31.5 25 25 25 25 25Duration of short circuit sec 3 3 3 3 3 3Peak withstand current kA 80 63 63 63 63 63

Measuring equipment [HV]

Current transformers The current transformers generally have protection cores only as the measuring quantities are obtained from the digital relays directly.

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The incomer CTs (33 kV, 22 kV and 11 kV – 2400 A) have one additional core for revenue metering. The current transformers have the following characteristics: Item Units 220 kV 110 kV 66 kV 33 kV 22 kV 11 kVRatio A 2400/1 2400/1 2400/1 2400/1 2400/1 2400/1Primary current cont rating A 2400 2400 2400 2400 2400 2400Secondary current cont rating A 2 2 2 2 2 2No of cores 4 4 4 2 2 2Table ST1 The following are the protection type core characteristics: Item Units Circ Prot Bb ProtProtection core VK V >1500 >1500Protection core resistance ohm <6 <6Protection core Imag mA <25 <25 Table ST1a The following are the revenue metering core characteristics: Item Units RevMetRev Met core class 0.2Rev Met core VA ohm 10Rev Met core fs mA 5 Table ST1b

Voltage transformers The voltage transformers have the following characteristics:

Item Units 220 kV 110 kV 66 kV 33 kV 22 kV 11 kVPrimary voltage kV 127 63.5 38.1 19 12.7 6.35Type CVTSecondary winding voltage V 63.5 63.5 63.5 63.5 63.5 63.5Class 0.2/3P 0.2/3P 0.2/3P 0.2/3P 0.2/3P 0.2/3PRated continuous voltage factor 1.2 1.2 1.2 1.2 1.2 1.2Rated 30 s voltage factor 1.9 1.9 1.9 1.9 1.9 1.9

Magnetic

Metering Revenue metering points are provided at the grid exit points where customers take supply from the Transpower grid. These points are at the incomers (33 kV, 22 kV and 11 kV) of the supply transformers and 220 kV, 110 kV and 66 kV feeder circuits. Each point meters the net supply to the customer; i.e. it is assumed that there are no Transpower incurred energy losses downstream from this point. The station services supplies are taken upstream from the revenue metering points and thus are not metered The revenue metering points are metered by a revenue metering installation compliant with Schedule D1, Part D of the EGRs. Each installation comprises of

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a revenue meter, data logger, instrument transformers (CT and VT), associated wiring, test facilities and an error compensation process. The maximum permitted error of the revenue metering installation shall be ± 0.75%, in accordance with part D of the EGRs. The meter accuracy class is 0.2S to IEC 60687 and the meter operates at 3 phase 110 V, 1 A. It is connected in a 4-wire (3 element) configuration and is capable of metering both active and reactive power flow in either direction. It also includes means of providing real time data (including kW and kvar) to the Transpower RTU. The meter includes a built-in data logger which shall comply with the requirements of the Code of Practice D3, Part D of the EGRs. Revenue metering current transformers have a rated secondary current of 1 A. They comply with the requirements of IEC 60044-1 for accuracy class 0.2 CTs and are dedicated solely to revenue metering. Revenue metering voltage transformers shall have a rated secondary voltage of 110 V, 3 phase and shall comply with the requirements of IEC 60044-2 for accuracy class 0.2 VTs. All instrument transformer wiring and cabling shall run directly from the instrument transformer or associated junction box to the revenue metering cabinet.

1.1.6 Building Blocks for AC Substations - Miscellaneous Plant

Automatic Tap Control

The ATC costs are based on the previous valuations.

220 kV Rangipo Cable

220 kV cables at Rangipo are costed based on the detailed design documentation. The modern equivalent of the oil filled cables is used. The cost of the cable tunnel construction is not included in the cost.

220 kV Wilton Cable

220 kV cables at Wilton are costed based on the detailed design documentation. The cost of the cable ducts is included in the establishment cost.

110 kV Cables at Haywards

110 kV cables at Haywards are costed based on the cable lengths provided by Transpower. The cables are assumed directly buried.

110 kV Mount Maunganui Cable

110 kV cable at Mount Maunganui is costed based on the actual installation costs and estimates for termination structures and cable lengths.

110 kV Kaiwharawhara Cable

The 110 kV cable at Kaiwharawhara costs are based on the previous valuations compensated for inflation.

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Current Limiting Reactors

The costing for current limiting reactors at Addington, Papanui and Bromley is based on the actual reactor supply costs for the project and estimate of the rest based on the detailed design drawings.

Capacitor Cost Capacitor cost is based on firm quotes for supply of several different configurations of capacitors (11 kV to 220 kV and 30 Mvar to 100 Mvar). The construction, installation design and management are estimates based on similar installations.

1.1.7 Building Blocks for AC Transmission Lines

Transmission Lines Building Blocks Identified

Transmission line building blocks were identified as listed in Table A1.6. Transmission Lines: Key Assumptions Structures

Five structure types were adopted: Light Suspension - zero deviation, Heavy Suspension - 5o deviation, Light Strain - 15o deviation, Heavy Strain - 50o deviation, and Dead End - full termination. Where possible, the number of each type of structure was based on a review of actual Transpower lines in representative terrain conditions, and quantities extrapolated to the Building Block length. As the number of different structure types for actual lines do not necessarily match the assumed structure types, some grouping of actual tower numbers was required. Structure numbers for those Blocks not directly matching actual lines were extrapolated or copied from adjacent Building Blocks. Table A1.6 shows the lines used for representative profile information. Table A1.6: Representative Lines Voltage

(kV) Structure* Terrain Conductor Line name Av Span

(m) 66 Dcst 1/wolf ISL-SBK 425 66 Scp 1/coyote STK-UTK 178 110 Dcst 1/goat HAM-WHU A 366 110 Dcst 1/wolf MST-UHT 372 110 Scp Flat 1/wolf GOR-ROX A 355-381 174

Hilly 1/wolf GOR-ROX A, 288-355 174 Mountaino

us Copper HWB-OAM, 160-188 261

220 Dcst Flat 2/zebra CHH-TWZ A, 24-48 463 Hilly HEN-MDN A, 38-61 354 Mountaino

us BPE-WIL A, 317-340 476

Urban HEN-OTA A 45-71 302

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220 Scst Flat 1/goat BUN-HAY B, 37-66 376 Hilly 1/zebra ISL-KIK A, 571-594 301 Urban 2/goat ROX-ISL A, 1060-1084 367 * scp = single-circuit pole

dcp = double-circuit pole dcst = double-circuit steel tower scst = single-circuit steel tower

Actual tower details were investigated to determine actual tower weights and dimensions for the structures, i.e. height to crossarm, crossarm spacing, and base width. Where tower weights were not directly available, they were extrapolated from adjacent known weights using empirically estimated weights as a guide. The empirical formulae used, which are based on the overturning moment (working) and tower height, were by Peterson, and Ryle. In some cases the base width was also empirically determined using the Ryle formula. A factor of 1.65 was used to divide the calculated ultimate loads to give a working load for use in the empirical equations (refer to comments in the section on Foundations for further details of the ultimate loads). Tower heights and therefore weights were further modified to accommodate the required crossarm heights. For Mountainous terrain, the tower heights were modified to allow for conductor sagging into the valleys. Where available, the reviewed tower contracts, and therefore weights were from the Transpower design loading period of 1963-1968, which is considered to be the most optimised set of design criteria for long service lines. For comparison, tower weights for contracts based on the subsequent and more onerous (less optimised) design criteria were investigated. The weights for the later contracts were found to be of the order of 10-20% higher than the adopted weights. Tower weights include bolts and gusset plates, where the bolts account for about 5% of the total weight. For Pole Structures, the relevant octagonal pole length was determined depending upon the configuration of the phases/circuits, the latest Transpower supply contract pole strengths, and the required ground clearance (based on Transpower requirements). The diameter of the pole base was recorded to allow foundation backfill volumes to be calculated. A pole structure code was recorded to allow reference to the pole fitting details which include such things as the number and length of guys, crossarm length and insulator types etc. The total number of poles allows for PI and other multiple pole structures. Crossarm spacing was optimised for the various voltages based on minimum spacing criteria in NZECP-34. The Pole structure heights and quantities for the Light Suspension structures were optimised based on the minimum pole height for the resulting average span length, and preliminary costing comparisons where a smaller number of the taller poles were found to be more economical. In addition, to allow for the difference in the theoretical average span, and the actual average span found with recent projects, the optimised number of Light Suspension structures was increased by 7%, which effectively reduces the average span length. Two Dead End structures were adopted in each Building Block.

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Foundations

The tower foundation loads are determined directly from the conductor diameter and tensions, assumed deviation angles, and the tower height and base width. An ultimate wind pressure (calculated from NZS4203:1992) of 1.1kPa was adopted for Flat terrain, 1.0kPa for Hilly and Urban, and 1.3kPa for Mountainous, while a load factor of 1.2 was applied to the 40% UTS conductor tension. Wind on tower was based on assumed percentages of conductor overturning moments based on values in the empirical weight paper by Ryle, and other experience. The tower wind loading factors varied for the single and double circuit towers. Using average soil properties (based on a geotechnical review of soil maps for NZ), tower bored foundation diameters and lengths were calculated for a range of loads. To record average foundation reinforcement requirements, the foundation dimensions for the Firm Cohesive soil conditions were adopted. The reinforcement was determined using a varying percentage of the foundation volume: 50kg/m3, 60kg/m3 and 70kg/m3 for the suspension, Light Strain, and remaining strain towers respectively. The values are based on foundation design experience. A separate calculation was undertaken to identify the likely longitudinal reinforcement based on an assumption that the main bars account for 80% of the total reinforcement. The longitudinal reinforcement type is only used in the construction costing component, and does not modify the total reinforcement weight. The Pole foundation dimensions are taken from Transpower's current Standard Pole Foundation tables for a Mixed, Medium, Dry/Moist soil. The backfill type is either "excavated", "strengthened", or "concrete". The pole embedment length was taken as the pole length/7 + 0.3m. Conductor The conductor length is calculated from the Average Span, sagged conductor length, taken over the full line length, taking into account the number of sub-conductors and circuits. A wastage allowance of 2.5%, based on previous experience, was adopted for construction requirements. Earthwire

The earthwire length is calculated similarly to the conductor length, except that the earthwire is only present for 1km at each end of the nominated lines. A similar wastage allowance of 2.5% was adopted for construction requirements. Insulator Assemblies

The insulator assemblies were defined separately for the poles and towers, based on current Transpower practice and further optimised where possible. The Lines Building Blocks include a slack span component subsequent to the Dead End tower requirements, suitable for attachment to an overhead gantry or similarly as tie-downs.

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Earthwire Assemblies

The earthwire assembly numbers are split into towers and poles, and suspension and strain. Other Fittings The fitting names for the spacers, conductor and earthwire vibration dampers, conductor mid-span joints, and structure signage are defined similarly to the other fittings. The number of spacers and vibration dampers are based on the standard Transpower requirements for the respective conductor types. The number of mid-span joints is based on the required number of cable drums, but also taking into account the number of strain structures for the Building Block. Each pole structure is assumed to have only one LSD/CPI sign. Miscellaneous

Each building block is taken to be 100km in length. An everyday conductor tension of 20.5% UTS was used to determine the corresponding maximum operating temperature tensions (50oC & 75oC) for each conductor type. Nominal average span lengths of 165m and 375m for the pole and tower lines respectively, based on a review of a number of route profiles, were adopted as the Basic Span to allow representative conductor tensions to be determined. The corresponding number of spans was recorded for comparison to the actual number of spans based on the assumed number of structures. The maximum conductor tension is assumed to be 40% UTS for maximum transverse loading, and is used to determine leg loads and estimate tower weights. Earthwires were assumed to be present for 1km at each end only, for 66kV and above. In addition a single earthwire was adopted except for the single circuit 110kV and all 220kV Building Blocks, where two earthwires were adopted.

The estimated number of structures is the sum of the defined individual structure type numbers, which also gave the estimated average span length. No modification has been made to the conductor tensions where the resulting average span length is different to the Basic Span. The Basic Span tensions were used in conjunction with the average span length, to determine the conductor sag, the sagged conductor length, and the corresponding minimum crossarm heights (both suspension and strain) for flat ground. Construction The number of drums is based on the respective drum lengths.

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The Project Management cost is assumed to be a percentage of the total construction cost, including materials, while the procurement cost is taken as a percentage of the material costs, excluding the conductor. Both values are based on recent line design/construction experience. Design and Transpower Time

The man-hours involved in investigating for the line, designing the structures, foundations and line, are based on extrapolated costs from recent projects converted back to a number of man-hours, as follows: Route Selection: $3k/km (flat & hilly), $2.5k/km (mount.), $10k/km (urban.); Survey: $1.7k/km; Site Investigation: $100/pole site, $700/tower site; Structure Spotting: $1k/km; Tower Design & Testing: $575k/tower building block; Foundation Design: $50/pole site, $500/tower site. Overall management cost is taken as 1% of the construction and material costs. Underground Cable Lines Under ground cable lines owned by Transpower are unique installations not suitable for a building block valuation approach. Actual costs are used to value these lines.

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1.2. Building Block Costs 1.2.1 Costs for AC Substations - Establishment

The cost of each AC Substations - Establishment building block is given Table A1.7

Table A1.7: Establishment Building Block Costs

Type Description Cost (NZ$000)

No. times building

block usedIn Handbook

(Y/N)ARG Argyle (1) 19.32 1 NBEN Benmore AC (1) 2,056.05 1 NCYD Clyde (2) 269.71 1 NHAY Haywards AC (3) 12,561.65 1 NMNI Motunui (1) 865.91 1 NRPO Rangipo (1) 353.32 1 NTWI Tiwai (1) 1,008.46 1 NWIL Wilton (1) 7,066.91 1 NNPK National Park (1) 192.92 1 N

Major

accommodating on average 14x220kV, 19x110kV, 15x33kV bays, roadways, buildings (60000 sq m) 3,184.75 3 Y

Medium

accommodating on average 6x220kV, 6x110kV, 15x33kV bays, roadways, buildings etc. (26,000 sq m) 1,203.07 25 Y

Small15x33kV bays, roadways and buildings (10,000 sq m) 1,072.82 41 Y

Very SmallAccommodating on average 2x66kV, and 6x33kV or 6x11kV bays, roadways etc. 294,611.00 1 N

Ruralaccommodating on average 2x66kV, 6x33/11 bays, roadways and buildings 973.34 86 Y

1.2.2 Costs for AC Substations - Buildings The cost of each AC Substations - Buildings building block is given in Table A1.8. Table A1.8: Building Building Block Costs

Type Description summary Cost (NZ$000)

No. times building

block used

In Handbook

(Y/N)MNI Motunui 827.20 1 NTWI Tiwai 1,807.30 1 N

Major IDFacilities associated with 33/11 kV indoors switchgear and control facilities plus OD equipment (850 sq m) 365.81 8 Y

Major OD

Facilities associated with major outdoor switchyard station with average of 14x220kV, 19x110kV15x33kV bays etc. (525sq m) 175.91 1 Y

Medium OD

Facilities associated with outdoor switchgear station with average of 6x220kV, 6x110kV, 15x33kV bays etc. (375sq m) 143.40 7 Y

Rural ID

Facilities associated with a rural indoor switchgear station with average of 2x66kV, 6x33/11kV bays etc.(60 sq m) 244.86 30 Y

Rural ODFacilities associated with a rural outdoor switchgear station with average of 2x66kV, 4x33/11kV(21 sq m) 112.95 26 Y

Small ODFacilities associated with outdoor switchgear station with average of 6x110kV, 15x33kV bays etc.(300sq m) 121.65 5 Y

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Additional building blocks have been created to cover a full range of control buildings which have no provision for 33kV or 11kV equipment. Building blocks have also been created for buildings to house an indoor switchboard only. These are given in Table A1.9 and A1.10 respectively.

Table A1.9: Substation Control Room Buildings

Building Block ID DescriptionCost

NZ$000

No. Times building block used

In Handboo

k (Y/N)

BC5

Accommodating outdoor switchgear protection, control facilities and support systems for up to 5 x 220 kV or 110 kV or 66 kV circuits. 117.87 23 N

BC10


BC15


BC20


BC30


BC40


Table A1.10: Substation Switchgear Room Buildings

Building Block ID Description Cost NZ$000

No. Times

building block used

In Handbook

(Y/N)

BSK10 Accommodating indoor switchgear for up to 10 x 11 kV bays. 111.43 1 N



BSH5 Accommodating indoor switchgear for up to 5 x 33 kV bays. 150.1 10 N







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1.2.3 Costs for AC Substations - Power Transformers

The cost of each AC Substations - Power Transformer building block is given Table A1.11.

Table A1.11: Power Transformer Building Block Costs

HV LV TV MVA Phases OLTC NER

Tfmer Cost

(NZ$000)

Infra Cost

(NZ$000)

Total Cost

(NZ$000)No Times

Used

In Handbook

(Y/N)220 110 300 3 Y N 2,765 213 2,978 3 N220 110 220 3 Y N 2,753 213 2,966 1 N220 110 200 3 N N 2,615 227 2,843 2 Y220 110 200 3 Y N 2,422 113 2,536 4 Y220 110 200 3 Y Y 2,422 113 2,536 3 N220 110 200 F1 Y N 5,109 1,059 6,167 2 Y220 110 120 3 Y Y 1,901 227 2,128 2 N220 110 100 3 N N 1,731 227 1,959 3 N220 110 100 3 Y N 1,739 113 1,852 4 N220 110 100 F1 Y N 2,758 1,059 3,816 2 N220 110 60 3 Y N 1,525 227 1,752 1 Y220 110 50 3 N N 1,262 227 1,489 1 Y220 110 50 3 N Y 1,262 227 1,489 1 N220 110 50 F1 N N 2,286 1,059 3,344 2 Y220 110 33 85 3 Y Y 1,734 298 1,734 2 N220 110 33 70 3 N N 1,574 285 1,859 1 N220 110 11 200 3 Y N 2,650 273 2,922 3 N220 110 11 200 F1 Y N 5,109 1,059 6,167 1 Y220 66 200 3 Y N 2,810 237 3,047 1 Y220 66 200 3 Y Y 2,876 237 3,113 2 N220 66 100 3 N Y 1,914 276 2,190 2 N220 66 100 3 Y Y 1,966 360 2,326 3 N220 55 18 T1 Y N 791 30 821 1 Y220 55 18 T1 Y Y 857 30 887 3 N220 55 15 T1 Y Y 815 30 845 4 N220 33 200 3 Y N 2,788 490 3,278 2 Y220 33 150 3 Y Y 2,369 422 2,791 7 N220 33 120 3 Y N 1,982 332 2,314 1 N220 33 120 3 Y Y 1,942 332 2,274 6 N220 33 110 3 Y N 2,005 353 2,358 2 N220 33 100 3 N Y 2,028 321 2,349 2 N220 33 100 3 Y N 1,952 321 2,273 7 Y220 33 100 3 Y Y 2,028 321 2,349 4 N220 33 80 3 Y Y 1,617 334 1,951 4 N220 33 50 3 N N 1,341 272 1,613 4 N220 33 50 3 Y N 1,367 272 1,640 2 Y220 33 50 3 Y Y 1,440 272 1,713 6 N220 33 50 F1 N N 2,499 396 2,895 2 Y220 33 40 F1 Y N 3,568 768 4,336 1 N220 33 30 3 N N 1,022 273 1,295 2 N220 33 20 3 N N 888 262 1,151 6 Y220 33 5 3 N N 661 265 925 2 N

95



Tfmer Cost

(NZ$000)

Infra Cost

(NZ$000)

Total Cost

(NZ$000)No Times

Used

In Handbook

(Y/N)220 22 50 3 Y N 1,354 278 1,633 2 Y220 16 240 F1 Y N 5,113 421 5,534 1 Y220 16 240 T1 Y N 3,835 316 4,151 2 Y220 11 100 3 Y Y 2,003 479 2,481 2 N220 11 70 3 Y Y 1,616 405 2,021 2 N220 11 50 3 Y N 1,292 356 1,648 2 N220 11 40 3 Y N 1,163 332 1,495 3 N220 11 12 3 Y N 802 264 1,065 2 Y220 11 10 3 Y N 776 259 1,035 1 Y110 66 50 3 Y N 1,036 116 1,152 3 N110 66 20 F1 N N 1,509 315 1,824 1 Y110 66 11 20 F1 N N 2,093 1,206 3,299 1 N110 50 30 3 N N 731 104 835 2 Y110 33 120 3 N N 1,652 227 1,879 2 N110 33 100 3 N N 1,359 219 1,579 2 N110 33 100 3 Y N 1,415 213 1,628 7 Y110 33 100 F1 N N 2,824 219 3,043 1 N110 33 90 3 Y N 1,332 210 1,542 3 N110 33 80 3 Y N 1,249 189 1,437 1 N110 33 60 3 Y N 1,082 187 1,268 6 Y110 33 50 3 N N 904 181 1,085 8 Y110 33 50 F1 N N 2,038 335 2,373 1 N110 33 50 T1 N N 1,427 240 1,666 1 Y110 33 40 3 N N 815 173 988 4 N110 33 40 3 Y N 915 173 1,088 3 Y110 33 40 3 Y Y 991 173 1,164 2 N110 33 40 F1 N N 1,741 310 2,052 1 Y110 33 30 3 N N 654 162 816 14 N110 33 30 3 Y N 871 162 1,033 3 Y110 33 30 F1 N N 1,572 293 1,865 3 N110 33 30 T1 N N 1,213 219 1,433 3 Y110 33 25 F1 Y N 1,852 239 2,091 1 N110 33 20 3 N N 699 161 860 13 Y110 33 20 3 Y N 748 160 908 3 Y110 33 20 F1 N N 1,420 293 1,712 3 Y110 33 15 3 Y N 673 161 834 2 Y110 33 12.5 3 Y N 686 155 841 2 N110 33 10 3 N N 665 153 818 2 N110 33 11 30 3 N N 777 291 1,068 1 Y

96



Tfmer Cost

(NZ$000)

Infra Cost

(NZ$000)

Total Cost

(NZ$000)No Times

Used

In Handbook

(Y/N)110 22 70 3 Y N 1,338 198 1,536 2 N110 22 50 3 Y N 1,040 154 1,194 1 Y110 11 60 3 Y N 1,083 240 1,323 4 Y110 11 50 3 Y N 984 217 1,201 1 Y110 11 40 3 Y N 879 199 1,079 6 Y110 11 40 3 Y Y 945 199 1,145 2 N110 11 30 3 Y N 774 182 956 4 Y110 11 28 3 N N 708 177 884 1 Y110 11 27 3 Y N 742 177 919 1 Y110 11 25 3 Y N 721 173 895 7 Y110 11 20 3 Y N 689 148 837 5 Y110 11 20 F1 Y N 1,444 290 1,735 1 Y110 11 12.5 3 Y N 590 151 741 2 N110 11 10 3 Y N 564 147 711 11 Y110 11 10 3 Y Y 630 630 2 N110 11 10 F1 N N 1,201 280 1,481 1 N110 11 10 T1 Y N 980 210 1,190 2 Y110 11 5 3 Y N 511 138 649 1 Y110 11 4 3 Y N 514 142 656 2 N110 11 1 3 Y N 456 142 598 1 Y66 33 60 3 Y N 947 166 1,114 2 Y66 33 40 3 Y N 743 164 907 2 Y66 33 40 3 Y Y 819 164 983 2 N66 33 20 3 Y N 539 161 700 2 Y66 33 16 3 Y N 498 160 658 3 N66 33 10 3 Y N 437 159 596 1 Y66 11 70 3 Y N 1,075 187 1,262 2 N66 11 60 3 Y N 978 179 1,157 4 N66 11 30 3 Y N 685 157 841 2 Y66 11 20 3 Y N 587 149 736 3 Y66 11 10 3 Y N 489 142 631 3 Y66 11 1 3 N N 221 140 362 1 Y66 11 1 3 Y N 162 148 311 2 N66 11 0.5 3 Y N 396 135 531 1 Y50 11 12.5 3 Y N 467 142 609 2 N33 11 12.5 3 Y N 467 145 612 2 N33 11 5 3 Y N 345 150 495 5 Y33 11 4 3 Y N 334 150 484 1 N33 11 3 3 Y N 318 144 461 1 N33 11 2 3 N N 127 152 279 2 N11 11 4.5 3 Y N 353 142 495 1 Y

97

1.2.4 Costs for AC Substations - Oil Containment

The cost of each AC Substations - Oil Containment building block is given Table A1.12

Table A1.12: Oil Containment Building Block Costs

Capacity (m3) Description Cost NZ$000No. building blocks used

In Handbook

(Y/N)10 Oil Containment System 68.78 28 Y15 Oil Containment System 75.24 12 Y20 Oil Containment System 76.83 23 N25 Oil Containment System 80.52 6 Y30 Oil Containment System 83.16 6 Y35 Oil Containment System 85.79 11 Y40 Oil Containment System 88.43 22 Y45 Oil Containment System 91.07 2 Y50 Oil Containment System 93.60 5 Y55 Oil Containment System 96.34 1 Y60 Oil Containment System 98.98 2 Y65 Oil Containment System 101.62 1 Y70 Oil Containment System 104.26 3 Y80 Oil Containment System 109.53 2 Y90 Oil Containment System 118.46 2 Y

98

1.2.5 Costs for AC Substations – Switchgear, Metering, Bus Zone Protection The cost of each building block is given in Table A1.13 This table contains a general section followed by a site specific section.

Table A1.13 Switchgear Building Block Costs

Type DescriptionBus Cost

$000CB Cost

$000Infra Cost

$000Prot Cost

$000Total

Cost $000Times used

In Handbook

(Y/N)B01 220 kV 1.5 CB two TL diameter 864.33 747.02 267.52 257.30 2,136.17 11 NB02 220 kV 1.5 CB one TL and one cct diameter 946.99 680.66 267.52 151.04 2.046.21 12 ND00L 220 kV trans line, no bus 146.16 194.73 290.50 122.96 754.35 7 YD01L 220 kV trans line, single bus 224.01 194.73 290.50 126.12 835.37 99 YD02L 220 kV trans line, dual bus 373.87 194.73 290.50 126.12 985.22 84 YD03L 220 kV trans line, triple bus 572.17 194.73 290.50 126.12 1,183.52 3 YD10 220 kV connection cct, no bus 68.23 194.73 75.87 22.96 361.78 5 YD11 220 kV connection cct, single bus 146.08 194.73 75.87 26.12 442.80 75 YD12 220 kV connection cct, dual bus 295.94 194.73 75.87 26.12 592.65 31 YD13 220 kV connection cct, triple bus 494.24 194.73 75.87 26.12 790.96 3 YD141 220 kV connection cct, no cb, single bus 129.44 - 124.07 14.93 268.42 18 ND31 220 kV generator, single bus 146.08 - - 3.16 149.24 66 YD32 220 kV generator, double bus 295.94 - - 3.16 299.10 15 YD41 220 kV line termination bay 88.63 - 20.54 106.25 215.43 2 ND42 220 kV line termination bay, t off, no cb, no bus 143.24 66.36 124.07 106.25 439.93 16 ND43 220 kV line terminVbay, t off, no cb, single bus 218.05 66.36 124.07 106.25 514.74 25 ND50 220 kv bus section 136.45 194.73 80.70 6.32 418.20 28 YD51 220 kV bus coupler, adjacent buses 696.92 194.73 82.06 6.32 980.02 25 YD52 220 kV bus coupler, outside buses 774.78 194.73 82.06 6.32 1,057.88 3 YD53 220 kV bus section disconnector, single 54.61 - 24.33 - 78.94 23 ND54 220 kV bus section disconnector, double 109.22 - 27.74 - 136.96 13 ND59 220 kV bus CVT - 66.36 8.15 - 74.51 16 ND81 220 kV capacitor bank cct, single bus 129.42 230.20 80.07 14.93 454.62 2 ND82 220 kV capacitor bank cct, dual bus 279.75 230.20 133.31 14.93 658.19 9 N

99



$000CB Cost

$000Infra Cost

$000Prot Cost

$000Total

Cost $000Times used

In Handbook

(Y/N)E00L 110 kV transmission line, no bus 108.66 111.34 125.93 57.36 403.29 18 YE01L 110 kV transmission line, single bus 178.96 111.34 125.93 60.52 476.75 187 YE02L 110 kV transmission line, dual bus 370.25 111.34 125.93 60.52 668.04 42 YE10 110 kV connection cct, no bus 50.55 111.34 66.76 22.96 251.62 10 YE11 110 kV connection cct, single bus 120.85 111.34 66.76 26.12 325.08 165 YE12 110 kV connection cct, dual bus 312.15 111.34 66.76 26.12 516.37 16 YE140 110 kV connection cct, no cb, no bus 49.73 - 79.06 14.93 143.72 15 NE141 110 kV connection cct, no cb,single bus 89.93 - 79.06 14.93 183.92 27 NE31 110 kV generator, single bus 120.85 - - 3.16 124.01 17 YE32 110 kV generator, double bus 312.15 - - 3.16 315.31 4 YE41 110 kV line termination bay 72.00 - 14.54 53.13 139.67 5 NE42 110 kV line termination bay, t off, no cb, no bus 121.73 - 79.06 53.13 253.92 96 NE43 110 kV line termin bay, t off, no cb, single bus 161.93 - 79.06 53.13 294.12 75 NE50 110 kV bus section 101.11 111.34 64.65 6.32 283.42 15 YE51 110 kV bus coupler 653.64 111.34 65.65 6.32 836.95 5 YE53 110 kV bus section disconnector, single 49.73 - 17.99 - 67.72 26 NE54 110 kV bus section disconnector,double 99.46 - 1.69 - 101.15 45 NE59 110 kV VT - - 46.11 - 46.11 142 YE81 110 kV capacitor bank cct, single bus 89.93 150.25 52.03 14.93 307.14 4 NE82 110 kV capacitor bank cct, dual bus 194.00 150.25 77.50 14.93 436.67 3 N

100



$000CB Cost

$000Infra Cost

$000Prot Cost

$000Total

Cost $000Times used

In Handbook

(Y/N)F00F 66 kV transmission line, no bus 102.19 116.08 114.16 57.36 389.79 4 YF01F 66 kV transmission line, single bus 163.35 116.08 114.16 60.52 454.11 56 YF021F 66 kV transmission line, dual bus, 3500/2000 A 340.07 116.08 114.16 60.52 630.83 17 YF11 66 kV connection cct, single bus 109.16 116.08 58.44 26.12 309.80 34 YF121 66 kV connection cct, dual bus 3500/2000 A 285.88 116.08 58.44 26.12 486.52 3 YF140 66 kV connection cct, no cb, no bus 46.42 - 76.41 14.93 137.76 12 NF31 66 kV generator, single bus 109.16 - - 3.16 112.33 4 YF41 66 kV line termination bay 68.20 - 14.15 53.13 135.48 3 NF42 66 kV line termination bay, t off, no cb, no bus 114.62 - 76.41 53.13 244.15 18 NF43 66 kV line termination bay, t off, no cb, single bus 151.97 - 76.41 53.13 281.51 9 NF50 66 kV bus section 96.00 116.08 63.81 - 275.90 4 YF511 66 kV bus coupler, 3500 A 613.26 116.08 63.81 - 791.92 2 YF53 66 kV bus section disconnector, single 46.42 - 13.07 - 59.49 4 NF54 66 kV bus section disconnector, double 92.84 - 15.66 - 108.50 10 NF59 66 kV VT - - 38.96 - 38.96 36 YF81 66 kV capacitor bank cct, single bus 83.78 155.49 58.83 14.93 313.02 2 NF821 66 kV capacitor bank cct, dual bus, 3500/2000 A 168.73 155.49 100.92 14.93 440.06 3 NG01L 50 kV transmission line,single bus 161.89 116.08 110.90 57.36 446.23 8 YG11 50 kV connection cct, single bus 107.70 116.08 57.74 22.96 304.48 2 Y

101



$000CB Cost

$000Infra Cost

$000Prot Cost

$000Total

Cost $000Times used

In Handbook

(Y/N)H00 33 kV od feeder, no bus 54.42 89.90 53.94 22.96 221.22 4 YH01 33 kV od feeder, single bus 78.60 89.90 53.94 22.96 245.40 83 YH20 33 kV od incomer, no bus 28.86 96.98 53.94 22.96 202.74 4 YH21 33 kV od incomer, single bus 49.74 96.98 53.94 22.96 223.62 32 YH53 33 kV bus section disconnector, single 23.24 - 10.50 - 33.74 9 NH54 33 kV bus section disconnector,double 46.48 - 11.30 - 57.78 9 NH60 33 kV recloser, pole mounted - 45.21 - - 45.21 18 YH62b 33 kV recloser, substation environmt, single bus 76.00 41.10 43.76 - 160.87 11 NH81 33 kV od capacitor bank cct, single bus 47.03 134.63 43.76 14.93 240.35 1 NK11 11 kv od feeder, single bus - 58.48 - 22.96 81.44 4 YK21 11 kV od incomer, single bus - 71.28 - 22.96 94.25 4 YK40 11 kV capacitor bank cct, interconnector tertiary 12.50 210.20 124.60 31.40 378.70 22 NK50 11 kV od bus section - 67.09 - 22.96 90.05 1 YK61 11 kV recloser, substation environment - 45.94 - - 45.94 11 NH71 33 kV indoor incomer single bus - 69.81 - 22.96 92.77 151 YH72 33 kV id feeder, single bus - 63.81 - 22.96 86.77 77 YH73 33 kV id bus section - 76.61 - 22.96 99.57 76 YH75 33 kV id feeder, single bus, cable tails - 63.81 - 39.26 103.07 364 NJ71 22 kV id incomer, single bus - 61.49 - 22.96 84.45 8 YJ72 22 kV id feeder, single bus - 60.29 - 22.96 83.25 26 YJ73 22 kV id bus section - 64.69 - 22.96 87.65 5 Y

102



$000CB Cost

$000Infra Cost

$000Prot Cost

$000Total

Cost $000Times used

In Handbook

(Y/N)K61 11 kV recloser, substation environment - 45.94 - - 45.94 11 YK715 11 kV 25 kA id incomer, single bus - 50.51 - 22.96 73.47 67 YK717 11 kV 40 kA indoor incomer single bus - 122.61 - 22.96 145.57 12 YK725 11 kV 25 kA id feeder, single bus - 46.51 - 22.96 69.47 283 YK727 11 kV 40 kA indoor feeder single bus - 72.61 - 22.96 95.57 14 YK735 11 kV 25 kA id bus section - 48.11 - 22.96 71.07 41 YK737 11 kV 40 kA indoor bus section - 75.61 - 45.92 121.53 7 NK9 16 kV 40 kA id incomer, single bus - 415.34 - - 415.34 3 NP8e 110 kV revenue metering - - 16.83 27.25 44.08 20 NP8f 66 kV revenue metering - - 15.18 27.25 42.43 29 NP8h 33 kV revenue metering - - 2.98 27.25 30.23 41 NP8k 11 kV revenue metering - - 2.13 27.25 29.38 14 NP8a Indoor revenue metering - - 2.13 27.25 29.38 236 NKIK11 11kV connection to tertiary winding at Kikiwa - 58.00 23.00 14.93 95.93 1 NP41 Busbar protection, 1 zone - - - 111.49 111.49 18 NP42 Busbar protection, 2 zone - - - 130.51 130.51 32 YP43 Busbar protection, 3 zone - - - 177.33 177.33 5 NP44 Busbar protection, 4 zone - - - 210.25 210.25 7 NP45 Busbar protection, 5 zone - - - 243.17 243.17 6 N220 NZR 220kV Railways Traction Supply 295.94 128.52 68.28 26.12 518.86 8 N55 NZR 55kV Railways Traction Supply 59.46 107.99 212.99 85.55 465.99 8 NGIS CYD1 220kV GIS Clyde#1(Bus Section only) 957.96 - - - 957.96 5 NGIS CYD2 220kV GIS Clyde #2 2,040.21 - - - 2,040.21 4 NGIS RPO1 220kV GIS Rangipo #1 (Bus Section only) 591.80 - - - 591.80 1 NGIS RPO2 220kV GIS Rangipo #2 1,549.01 - - - 1,549.01 2 NGIS TWI 220kV GIS Tiwai 1,739.54 - - - 1,739.54 14 NGIS WIL 220kV GIS Wilton 1,703.11 - - - 1,703.11 6 N

103

1.2.6 Costs for AC Substations - Miscellaneous Plant

The cost of each AC Substations - Reactive Power Plant and other miscellaneous building blocks are given Table A1.14.

Table A1.14: Miscellaneous Plant Building Block Costs

Type DescriptionTotal Cost (NZ$000)

No. times building

block used

In Handbook

(Y/N)110KV_CABL_360A 110kV cable 360A 2,406.11 1 N110KV_CABL_525A 110KV cable 525A 1,392.72 1 NACTISL Islington Static Var compensator 6,062.80 1 NATCADD ATC Addington 212.86 1 NATCBRY ATC Bromley 152.96 1 NATCPAP ATC Papanui 178.31 1 NCABLR Cable cost for Rangipo 2,841.15 1 NCABLR_WIL WILTON 220KV CABLE 3,152.27 1 NCAPAC1 Capacitor cost per 1 MVAR 23.83 1 NCAPAC2 Capacitor cost per 2 MVAR 31.66 1 NCAPAC3 Capacitor cost per 3 MVAR 39.49 1 NCAPAC4 Capacitor cost per 4 MVAR 47.32 2 NCAPAC5 Capacitor cost per 5 MVAR 55.15 14 NCAPAC5.1 Capacitor cost per 5.1 MVAR 55.93 4 NCAPAC12 Capacitor cost per 12 MVAR 109.96 4 NCAPAC20 Capacitor cost per 20 MVAR 172.6 1 NCAPAC30 Capacitor cost per 30 MVAR 250.9 10 NCAPAC40 Capacitor cost per 40 MVAR 329.2 3 NCAPAC50 Capacitor cost per 50 MVAR 407.5 4 NCAPAC60 Capacitor cost per 60 MVAR 485.8 4 NCAPAC70 Capacitor cost per 70 MVAR 564.1 2 NCAPAC75 Capacitor cost per 75 MVAR 603.25 2 NCAPAC100 Capacitor cost per 100 MVAR 799 3 NCONDI Condenser cost for Islington 6,490.00 2 NCONDS Condenser Cost for Stoke 5,281.82 1 NMISCH Miscellaneous equipment at Haywards 3,829.41 1 NREACB Reactor cost for Bromley 379.55 1 NREACT_PEN Reactor cost for Penrose 443.99 2 NREACT5 Reactor cost per MVAR 5 112.6 3 NREAFA Fault limiting reactor Addington 115.31 2 NREAFB Fault limiting reactor Bromley 118.01 2 NREAFP Fault limiting reactor Papanui 130.31 4 NREAFW Pseudo Fault Limiting Reactor For Whirinaki 300 1 NSYNBFW Pseudo Synchronous Bus For Whirinaki 100 1 N

104

1.2.7 Costs AC Transmission Lines

The cost of each AC Transmission Line building block is given in Table A1.15.

Table A1.15: Transmission Line Building Block Costs

kV Configuration Rating Conductor Temp.Cost/km

(NZ$000's) No. km

No. of times building

block used

In Handbook

(Y/N)33 dcp 315 1/hyena 50 61.98 20.8 1 Y33 dcp 360 1/coyote 50 66.21 11.9 1 Y33 dcp 525 1/wolf 75 74.4 16.1 2 Y33 scp 220 1/mink 50 37.29 49.3 4 Y33 scp 315 1/hyena 50 41.09 66.4 1 Y33 scp 360 1/coyote 50 43.21 47.1 1 Y50 dcp 220 1/mink 50 58.05 37.2 1 N66 dcp 290 1/mink 75 65.92 224.8 5 Y66 dcp 360 1/coyote 50 77.72 32.9 1 N66 dcp 525 1/wolf 75 90.07 91.1 3 Y66 dcst 315 1/hyena 50 112.14 14 1 Y66 dcst 410 1/hyena 75 114.37 25.4 1 Y66 dcst 525 1/wolf 75 137.48 12.8 1 Y66 dcst 1960 2/zebra 75 318.88 25.8 3 Y66 dcst 640 1/goat 50 170.65 6 1 Y66 scp 220 1/mink 50 40.84 63.2 2 Y66 scp 315 1/hyena 50 44.64 39.4 1 Y66 scp 360 1/coyote 50 46.77 54.2 1 Y66 scp 410 1/hyena 75 44.28 82.9 1 Y

110 dcp 525 1/wolf 75 100.14 52 5 Y110 dcst 315 1/hyena 50 123.14 179.3 5 Y110 dcst 360 1/coyote 50 128.81 297.5 3 Y110 dcst 410 1/hyena 75 125.92 55.3 2 Y110 dcst 525 1/wolf 75 141.18 117.6 10 Y110 dcst 640 1/goat 50 176.57 117.4 3 Y110 dcst 750 1/zebra 50 194.99 184 5 Y110 dcst 840 1/goat 75 180.55 53.6 2 Y110 dcst 980 1/zebra 75 195.41 114.5 2 Y110 dcst 1640 1/chukar 75 273.37 8.8 2 Y110 dcst 1680 2/goat 75 296.05 38.4 2 Y110 dcst 1960 2/zebra 75 324.84 3.7 1 Y110 scp 315 1/hyena 50 51.41 570.5 13 Y110 scp 360 1/coyote 50 53.48 485.2 5 Y110 scp 410 1/hyena 75 53.91 189 8 Y110 scp 525 1/wolf 75 57.02 14 1 Y110 scst 410 1/hyena 75 92.98 15.2 1 Y110 scst 640 1/goat 50 128.46 10.2 1 Y220 dcst 750 1/zebra 50 210.54 353.7 10 Y220 dcst 980 1/zebra 75 212.97 891.9 15 Y220 dcst 1280 2/goat 50 319.92 610.2 7 Y220 dcst 1500 2/zebra 50 353.41 292.9 4 Y220 dcst 1640 1/chukar 75 307.03 235.6 2 Y220 dcst 1680 2/goat 75 324.31 253.4 3 Y220 dcst 1960 2/zebra 75 362.8 528.1 10 Y220 scst 640 1/goat 50 132.34 865.9 6 Y220 scst 750 1/zebra 50 146.96 550.3 6 Y220 scst 980 1/zebra 75 149.87 352.1 4 Y220 scst 1280 2/goat 50 210.85 265.2 1 Y

105

Appendix 2: AC Asset ODRC Calculations and Standing Data 2.1 Calculation of ODRC Values

The replacement costs for each AC network asset building block are listed in Appendix 1. A number of factors, as well as the remaining life effect, are applied to the replacement cost in order to determine the ODRC. The factors are explained further in the following sections of this Appendix. The following calculations are applied to determine the ODRC value for each AC network asset: AC Substation Assets (Building Block Replacement Cost x Interest During Construction Factor x Seismic Factor) / Asset Class Life x Remaining Life AC Transmission Lines (Building Block Replacement Cost x Interest During Construction Factor x Terrain Factor) / Asset Class Life x Remaining Life

Land

The value of land is obtained from Government Valuations. The land value at substations excludes land for houses, or vacant land at substation sites. Land is not depreciated. No seismic, terrain or interest during construction factors are applied to land values in the calculation of the substation valuations.

2.2 Interest During Construction Factors

The IDC factor is determined from Transpower’s long run real post tax cost of capital. This is currently estimated at an annual rate of 6.4%. The IDC adjustment is determined based on the typical time profile for the payment of milestones for construction of a substation or transmission line. The IDC factor is, therefore, a weighted and annualised rate. For substations, this factor is 4.8% per annum, for transmission lines; this factor is 4.0% per annum. The IDC factors for substations and transmission lines are detailed below:

Substations (20 month project)

Month No. of months

to run Milestone payment

(% of total) Interest factor

5 15 20% 1.6 10 10 40% 2.1 15 5 40% 1.1

4.8%

106

Transmission Lines (18 month project)

Month No. of months to run

Milestone payment (% of total)

Interest factor

6 12 40% 2.6 12 6 45% 1.4 18 0 15% -

4.0%

Sample Calculation The calculation of the contribution of the interest during construction in respect of the first milestone payment for substations is as follows: 6.4% x 20% x 15/12 = 1.6%

2.3 Terrain Factors

The value of transmission line assets is dependent upon the terrain over which the transmission line is built. This is reflected in the valuation of each transmission line by assigning a “terrain factor” reflecting the predominant terrain of the line. The terrain factors used have been derived from analysis of a sample of actual Transpower lines. The terrain factors are listed in Table A2.1. Table A2.1: AC Transmission Lines Terrain Factors Terrain Type: Factor Flat terrain 1.00 Hilly terrain 1.07 Mountainous terrain 1.22 Urban terrain 1.15

The terrain factors have been applied to all transmission lines. Table A2.2 shows the length of line each factor has been applied to, by asset class.

Table A2.2: Application of Terrain Factors

Flat Hilly Mountain Urban TotalAsset Class km km km km km220KV_DCST_1280A 199 408 - 3 610 220KV_DCST_1500A 53 235 5 - 293 220KV_DCST_1640A 41 149 46 - 236 220KV_DCST_1680A 69 134 50 - 253 220KV_DCST_1960A 307 175 19 27 528 220KV_DCST_750A 156 195 - 3 354 220KV_DCST_980A 343 397 143 9 892 220KV_SCST_1280A 150 85 30 - 266 220KV_SCST_640A 313 514 39 - 866 220KV_SCST_730A 6 26 - 0 32 220KV_SCST_750A 187 289 70 4 550 220KV_SCST_840A 10 5 25 - 39 220KV_SCST_860A - 33 - 0 33 220KV_SCST_980A 113 228 11 0 352

107

Flat Hilly Mountain Urban TotalAsset Class km km km km km110KV_CABL_360A 1 - - - 1 110KV_CABL_500A 1 - - - 1 110KV_CABL_525A 1 - - - 1 110KV_DCP_315A 329 169 10 8 517 110KV_DCP_360A 29 11 - 1 41 110KV_DCP_410A 83 63 - 8 154 110KV_DCP_525A 20 32 - - 52 110KV_DCST_1640A 9 - - - 9 110KV_DCST_1680A 12 26 - - 38 110KV_DCST_1960A - - - 4 4 110KV_DCST_315A 39 141 - - 179 110KV_DCST_360A 71 227 - - 298 110KV_DCST_410A - 40 15 - 55 110KV_DCST_525A 35 42 - 41 118 110KV_DCST_640A 39 39 39 1 117 110KV_DCST_750A 38 123 - 23 184 110KV_DCST_840A 30 22 - 2 54 110KV_DCST_980A 49 66 - - 115 110KV_SCP_315A 269 286 8 8 571 110KV_SCP_360A 153 311 22 - 485 110KV_SCP_410A 60 122 - 7 189 110KV_SCP_525A 14 - - - 14 110KV_SCP_80A 29 4 - - 33 110KV_SCST_1280A - - 1 4 5 110KV_SCST_410A 11 4 - 0 15 110KV_SCST_640A 10 - - - 10 66KV_DCP_290A 129 86 10 - 225 66KV_DCP_360A 33 - - - 33 66KV_DCP_525A 91 - - - 91 66KV_DCST_1960A 5 - - 21 26 66KV_DCST_315A 14 - - - 14 66KV_DCST_410A 25 - - - 25 66KV_DCST_525A 12 - - 1 13 66KV_DCST_640A 6 - - - 6 66KV_SCP_220A 49 9 5 0 63 66KV_SCP_315A 39 - - - 39 66KV_SCP_360A 44 10 - 0 54 66KV_SCP_410A - 63 20 - 83 50KV_DCP_220A 6 31 - 0 37 33KV_DCP_315A 21 - - - 21 33KV_DCP_360A - 10 - 2 12 33KV_DCP_525A - 16 - - 16 33KV_SCP_220A 29 21 - - 49 33KV_SCP_315A 25 42 - - 66 33KV_SCP_360A 47 - - 1 47 Grand Total 3,850 4,889 567 178 9,484

108

2.4 Seismic Zones The design standard for plant at substations varies to take account of the likely impact of earthquakes. In the valuation, these variations are reflected through the use of seismic factors to adjust the replacement costs depending upon the susceptibility of a particular site to seismic activity. The seismic factors are applied on the basis of location, with New Zealand being divided into three areas and each area being designated as a low, medium or high risk area. The seismic factor reflects the additional cost incurred, over and above that applying in a low risk area, for appropriate seismic strengthening. The seismic factors are listed in Table A2.3 by seismic zone and by type of equipment. Table A2.3: Seismic Zones Equipment Type:

Zone A (high risk)

Zone B (medium risk)

Zone C (low risk)

Establishment 1.14 1.06 1.00 Buildings 1.02 1.01 1.00 Oil Containment 1.14 1.06 1.00 Transformers 1.04 1.02 1.00 Switchgear 1.02 1.01 1.00 Other Plant 1.02 1.01 1.00

109

The seismic zones for the North Island are shown in figure A2.1 and the seismic zones for the South Island are shown in figure A2.2. Figure A2.1 North Island Seismic Zone Map

110

Figure A2.2 South Island Seismic Zone Map

111

2.5 Asset Lives

Each class of asset has an expected economic class life. The lives for AC substations and transmission lines are summarised in the Tables A2.4 and A2.5. Table A 2.4: Substation Assets Class Lives

Profile Descriptionlife

(periods) life (years)ODV_H_BLDG Hvdc Buildings 360 30ODV_H_BR HVDC Bog Roy Electrode 360 30ODV_H_CBL HVDC Submarine Cable 360 30ODV_H_CTS HVDC Cable Termination Stns 360 30ODV_H_MER Mercury Arc Convertors -Pole 1 360 30ODV_H_SYN HVDC Synchronous Condensers 360 30ODV_H_TH HVDC Te Hikowhenua Electrode 360 30ODV_H_THY Thyristor Convertors (Pole 2) 360 30ODV_H_LAND Hvdc Land n/d n/dODV_LAND Substation Land n/d n/dODV_H_LINE HVDC 350 kV Overhead Line 660 55ODV_EASE Lines Easements n/d n/dODV_L_LAND Lines Land n/d n/dODV_ATC Atc 180 15ODV_BZP Bus Zone Protection 180 15ODV_CAPS Capacitors 360 30ODV_CB_AB Air Blast Circuit Breaker 420 35ODV_CB_B11 11kV Bulk Oil Circuit Breaker 660 55ODV_CB_BO Bulk Oil Circuit Breaker 540 45ODV_CB_GIS GIS Circuit Breaker 480 40ODV_CB_MO Minimum Oil Circuit Breaker 300 25ODV_CB_SF6 SF6 Circuit Breaker 420 35ODV_CB_VAC Vacuum Circuit Breaker 480 40ODV_CON Condenser 360 30ODV_MISCH Miscellaneous Equip Ben/Hay 660 55ODV_O_CON Oil Containment 540 45ODV_REA Reactors installed after '70 600 50ODV_REA_70 Reactors Installed prior '70 660 55ODV_RMINFR Revenue Metering - Infra 660 55ODV_RMPROT Revenue Metering - Protection 120 10ODV_SBLDG Buildings 660 55ODV_SG_B SG Bus 660 55ODV_SG_B_G SG Bus GIS 480 40ODV_SG_I SG Infrastructure 660 55ODV_SG_I_G SG Infrastructure GIS 480 40ODV_SG_PT SG Protection 180 15ODV_SUBEST Substation Establishment 660 55ODV_SVC Static Var Convertor 600 50ODV_TF Power Transformers instal >'70 600 50ODV_TF_70 Power Transformers instal <'70 660 55ODV_TF_IN Transformer Infrastructure 660 55

Table A2.5: Transmission Line Assets Class Lives Environment: Class Life Normal 55 Years Coastal 35 Years Clean Inland 70 Years

112

Appendix 3: Security Criteria and Quality of Supply Criteria for Technical Optimisation

3.1 General

At present the security standard applied by Transpower to consumers, Distribution Line Businesses (DLBs), and other large private industrial consumers differs significantly from area to area, but in general follows the (n - 1) criterion, with security to the (n - 2) level only used for a small number of specific industrial consumers. Table A3.1 shows the security guidelines for transmission equipment planning. Moreover, a substantial number of smaller supply points are provided with power through either one transmission line or one transformer; either element controlled by a single circuit breaker will meet just the (n) criterion. In the case of transformers, the (n - 1) criterion is applied where there is a single bank of three single phase units and where there is a fourth (or spare unit) on site. Examination of the existing system indicates that in many instances the (n - 1) criterion is not met. Transpower's projections of load demand are used as a basis for the analysis of the system. The system is tested to determine whether it meets the requirements of the consumers over the next fifteen years and to determine the extent of the over design and overbuild in the network. Loadflows performed in previous years have been revisited in 2004 in order to assess the optimisations. In 2002, voltage stability studies were performed as it was believed that the previous optimised network may not have been stable for N-1 contingencies and hence not able to be implemented in practice. This was found to be the case resulting in the reinstatement of some circuits. In particular the 110 kV circuits in the North Isthmus and central North Island. In planning the power system it is necessary to provide adequate circuit capacity in order to meet the security standards within a fifteen year time frame. For determining the optimum conductor size for the line it is necessary to take account of the increase in losses and the effect of radio/television interference so as to select the most technically suitable and cost-effective conductor. In general, utilities throughout the world provide transmission plans over a five, seven and ten year period to facilitate the integration of new power stations and produce the most cost-effective overall system development. Transmission capacity throughout the system is matched to the predicted power transfers over a fifteen year period, and allows for the operation of power stations under abnormal load conditions. The optimisation criteria used in this updated valuation are detailed later in this appendix.

113

Table A3.1: Security Guidelines for Transmission Equipment Planning

(Reproduced from the ODV Handbook) Load (MW) Basic

Security Transmission Circuits

Busbars Transformers

Less than 10

n

One circuit

One bus or bus section

1 x 3-phase units

(10 to 40, if more than 40 km remote and local generation can limit load shed to 25%)

n

One circuit One bus or bus section

4 x 1-phase or 1 x 3-phase unit, if backed up from alternative supply point

From 10 to 300

n-1

Two circuits

Two busbars or bus sections

7 x 1-phase units or 2 x 3-phase units Firm supply of peak demand using any short term overload capability

More than 300

n-2

Three circuits on at least two routes

One redundant bus or bus section, such that supply is not lost after a single contingency while one bus is out of service for maintenance

7 x 1-phase units or 2 x 3-phase units Firm supply of peak demand using any short term overload capability

More than 600 Loss of station.

Supply into a region should be diversified across more than one major terminal substation

3.2 Load Forecast

The maximum load predictions for the years 2005 and beyond are those contained in Table 11 in Section 5 of the main Valuation Report.

3.3 Generation Scenarios

Optimisation of the transmission system is based upon generation scenarios for 2005 covering maximum, intermediate and minimum load condition. These incorporate abnormal operation of both hydro and thermal power plant. Where a power project has been approved then the effect of the additional generating capacity has been considered in relation to the transmission capacity.

114

3.4 Time Frame for Analysis

The power system will be analysed using the fifteen year forecast which incorporates diversity factors to allow for non-simultaneous occurrence of the maximum load at each substation. If the load conditions exceed the system capability within the fifteen year time frame then the system as built is deemed as optimal for valuation purposes.

3.5 Supply Transformer Optimisation Criteria

All transformers not covered by new investment agreements are subject to optimisation, where over capacity exists relative to the fifteen year peak load flow prediction. The optimisation of existing transformer banks with an MEA is based on the following criteria:

1) Over a fifteen year period, for maximum predicted loads of more than

10 MW, an n-1 security criterion should be satisfied.

2) Over a fifteen year period, for maximum predicted loads of less than 10 MW, an n security criterion should be satisfied unless the customer has indicated that the load is of a continuous nature, in which case N-1 security criterion should be satisfied.

3) Over a fifteen year period, for maximum predicted loads of more than

10 MW, optimal firm capacity shall be the lesser of the existing firm capacity or the maximum predicted MVA demand over the ten year period.

4) Over a fifteen year period, for maximum predicted loads of less than

10 MW if no firm capacity exists currently, the optimal installed capacity shall be the lesser of the existing installed capacity or the maximum predicted MVA demand over the fifteen year period.

5) The size of transformer is adjusted to the nearest standard size

available to Transpower. 6) If existing transformers have OLTCs these are retained. 7) If there exists a spare single phase unit on site, then all single phase

banks capable of using a unit of that size are considered to have firm capacity.

8) All transformer optimisations are subject to all other normal

engineering constraints.

Specific cases are: 1) For fifteen year maximum predicted load of less than 10 MW being

supplied by four single phase units, the optimal arrangement becomes one three phase unit with the optimal installed capacity reduced where necessary, such that the optimal installed capacity does not exceed the maximum predicted MVA demand over a ten year period.

115

2) For fifteen year maximum predicted load of more than 10 MW, currently supplied by one transformer of four single phase units, the optimal arrangement becomes the cheaper of either:

(a) the present arrangement, with reduced capacity where necessary,

such that the optimal installed capacity does not exceed the maximum predicted MVA demand over a fifteen year period.

(b) two three phase units each of capacity equal to the lesser of either

the existing firm capacity or maximum predicted MVA demand over a fifteen year period.

Note: Generally two three phase units are of comparable cost to one

bank of four single phase units of the same capacity. However when the additional circuit breaker, bay, bus work and protection costs are taken into account the three phase option will not always be cheaper. For this reason, each case of this configuration must be considered individually.

3) For ten year maximum predicted loads of more than 10 MW being

supplied by 7 or 8 single phase units (two banks) the banks are optimised to three phase units and the optimal installed capacity reduced where necessary, such that the optimal installed capacity does not exceed the maximum predicted MVA demand over a fifteen year period. Where there are mismatched transformer capacities and the capacity is to be reduced, the mismatch should be reduced as much as possible.

4) For fifteen year maximum predicted loads of more than 10 MW being

supplied by 10 or 11 single phase units (three banks) the optimal arrangement becomes two three phase units and the optimal installed capacity reduced where necessary, such that the optimal installed capacity does not exceed the maximum predicted MVA demand over a fifteen year period.

Where, for other technical reasons, the optimal configuration would be three, three phase units, the optimal arrangement becomes three, three phase units subject to the same limitation on optimal installed capacity. An example would be the case where circuit breakers become the limiting factor and thus three transformers are required.

5) For 3, 4 and 2 (b) where three phase option is cheaper, the value of

the spare one phase unit(s) is evaluated as the difference between the cost of the optimal arrangement as above and the cost of providing a MEA in terms of firm capacity. The MEA will always be of the same number of units as the optimal arrangement.

Where the optimal arrangement is two, three phase units, the MEA for spare valuation will be two, three phase units, each of capacity equal to the lesser of the existing firm capacity or the maximum predicted MVA demand over a fifteen year period. Where the optimal arrangement is three, three phase units, the MEA for spare valuation will be three, three phase units, each of capacity equal to half the lesser of the existing firm capacity or the maximum predicted MVA demand over a fifteen year period.

116

Appendix 4: Optimisation Cases – Single Line Diagrams

117

Figure A4.1:

North Isthm

us Region - A

ctual System

118

Figure A4.2:

North Isthm

us Region - O

ptimised System

119

Figure A4.3:

Auckland R

egion - Actual System

120

Figure A4.4:

Auckland R

egion - Optim

ised System

121

Figure A4.5:

Waikato R


122

Figure A4.6:

Waikato R

egion - Optim

ised System

123

Figure A4.7:

Bay of Plenty R


124

Figure A4.8:

Bay of Plenty R

egion - Optim

ised System

125

Figure A4.9

Central N

orth Island Region - A

ctual System

126

Figure A4.10:

Central N

orth Island Region - O

ptimised System

127

Figure A4.11:

Taranaki Region - A

ctual System

128

Figure A4.12: Taranaki R

egion - Optim

ised System

129

Figure A4.13:

Haw

kes Bay R


130

Figure A4.14:

Haw

kes Bay R

egion - Optim

ised System

131

Figure A4.15:

Wellington R


132

Figure A4.16:

Wellington R

egion - Optim

ised System

133

Figure A4.17:

Nelson-M

arlborough Region - A

ctual System

134

Figure A4.18:

Nelson-M

arlborough Region - O

ptimised

System

135

Figure A4.19:

West C

oast Region - A

ctual System

136

Figure A4.20:

West C

oast Region - O

ptimised System

137

Figure A4.21:

Canterbury R


138

Figure A4.22:

Canterbury R

egion - Optim

ised System

139

Figure A4.23:

South Canterbury R


140

Figure A4.24:

South Canterbury R

egion -Optim

ised System

141

Figure A4.25:

Otago-Southland R

egion -Actual System

142

Figure A4.26: O

tago-Southland Region - O

ptimised System

143

Appendix 5: Refurbished Assets – Detailed Schedule Table A5.1 Refurbished Assets

Asset IDProject

Close Date

Life Adjustment

(Months)

Value Impact

(NZ$000) Asset IDProject

Close Date

Life Adjustment

(Months)

Value Impact

(NZ$000) BRK_SFDA 2004-11-22 14 756.53 RDFI0062 2004-12-16 119 24.27 BOB_OTAA 2004-11-22 72 701.15 MHOP0102 2004-12-16 155 24.04 HEN_MPEA 2004-11-22 16 470.15 MHOP0112 2004-12-16 155 24.04 NPL_SFDA 2004-11-22 27 437.01 IGH_BWRA 2004-11-19 6 23.85 CST_SFDA 2004-11-22 47 424.81 KPUB1052 2004-09-27 91 23.84 HEN_OTAA 2004-11-22 16 380.00 KPUB1072 2004-09-27 91 23.84 AHA_OTIA 2004-11-22 48 337.05 KPUB1092 2004-09-27 91 23.84 PKK_TKRA 2004-05-05 57 329.75 KPUB1102 2004-09-27 91 23.84 INV_MANA 2004-10-28 4 324.40 KPUB1132 2004-09-27 91 23.84 BPE_WRKA 2004-09-27 6 312.03 TMUB0042 2005-03-23 123 23.84 MAN_TWIA 2004-11-19 4 270.22 KPUB1062 2004-09-27 136 23.81 BLN_KIKA 2004-11-19 27 248.20 KPUB1122 2004-09-27 136 23.81 KHD_TKRA 2004-09-27 103 209.82 GNY_TIMA 2004-10-20 4 23.17 ALBESTA 2004-07-22 87 168.11 BRKI0622 2004-09-27 48 22.58 WGN_SFDA 2004-11-19 14 144.99 BRKB0622 2004-09-27 37 22.40 HLY_BZ1 2005-03-23 85 121.55 BRKB0632 2004-09-27 37 22.40 BPEB0648 2005-03-23 86 97.07 TNGTI011 2004-09-27 37 21.78 ALB_HPIA 2004-11-22 10 95.57 TNGTI012 2004-09-27 37 21.78 BRKB0612 2004-09-27 79 89.17 EDGVT012 2005-03-23 275 20.54 CST_NPLA 2004-10-28 17 87.93 HENC1872 2004-09-27 109 20.52 WAITF002 2005-05-19 34 80.73 MPETI003 2005-05-26 121 19.66 ARIB0202 2005-03-23 117 69.47 OWH_DEVA 2004-09-27 7 19.43 ARIB0212 2005-03-23 117 69.47 MPEI0262 2005-05-26 177 18.76 WRK_WHIA 2004-09-27 1 66.02 KAWP0582 2004-10-28 25 18.73 OTATX003 2005-03-23 13 60.16 BRYP0172 2004-12-20 52 18.50 ASH_TIMB 2004-11-29 41 59.93 HAYI0082 2004-11-22 80 16.32 WAIOILC 2005-05-19 384 58.43 PENB0802 2005-02-09 70 16.24 WRKB0192 2004-10-28 155 56.24 MPEB0262 2005-05-26 82 15.74 CPK_WILB 2004-07-27 7 55.30 SFDB0732 2005-05-26 33 15.66 NMAOILC 2004-09-27 281 53.34 WRKB0057 2004-09-27 176 15.57 DARESTA 2004-09-27 34 52.55 WRKB0067 2004-09-27 176 15.57 CMLOILC 2004-10-28 255 49.89 WHI_BZ1 2004-09-27 22 14.57 ARAB0072 2004-11-29 133 47.78 KOEB0102 2004-12-16 51 14.49 GNY_OAMA 2004-10-20 22 45.81 KOEB0162 2004-12-16 51 14.49 BRKI0632 2004-09-27 88 41.41 KOEB0112 2004-12-16 75 14.39 WRKB0108 2004-09-27 36 40.64 HIN_KPOA 2004-11-19 8 14.38 TUI_WRAA 2003-07-01 7 38.16 OTAC0432 2004-10-28 38 14.36 KIK_STKB 2004-10-28 8 37.63 STKC1182 2005-02-09 34 14.15 HAM_WHUA 2005-03-17 3 37.40 BRYP0812 2004-12-16 19 14.09 MPETF002 2004-09-27 35 36.36 ALBK0592 2004-10-20 29 14.09 TRKTF004 2004-10-20 27 35.58 KAIP0072 2004-09-27 39 13.88 MPEC0322 2005-05-26 88 34.23 KAIP0092 2004-09-27 39 13.88 TKA_TIMA 2004-11-19 5 34.20 STK_UTKA 2005-02-09 2 13.80 KAWI0172 2004-12-16 146 29.78 ADDW0112 2004-10-20 88 13.52 RDFI0042 2004-12-16 146 29.78 EDG_WAIB 2004-10-20 4 13.29 WAITF005 2005-05-19 61 28.96 OTAP0552 2005-03-23 18 13.22 RDFI0052 2004-12-16 124 25.29 AHA_DOBA 2004-10-28 3 13.03 RDFI0092 2004-12-16 122 24.88 TRKTI004 2004-10-20 54 12.93 WRKB0077 2004-09-27 277 24.50 OTATI005 2005-03-23 36 12.19

144

Asset IDProject

Close Date

Life Adjustment

(Months)

Value Impact

(NZ$000) Asset IDProject

Close Date

Life Adjustment

(Months)

Value Impact

(NZ$000) RDFI0072 2004-12-16 111 12.00 GORK0282 2005-02-09 13 2.47 RDFI0082 2004-12-16 111 12.00 TRKP2662 2004-10-20 27 3.65 WPWC0242 2005-05-26 92 11.62 TRKP2658 2004-10-20 27 3.65 PENB0758 2005-02-09 53 11.48 TRKP2642 2004-10-20 27 3.65 PENB0798 2005-02-09 53 11.48 TRKP2632 2004-10-20 27 3.65 MTOB1222 2005-03-23 92 11.48 TRKP2622 2004-10-20 27 3.65 MTOB1282 2005-03-23 92 11.48 TRKP2612 2004-10-20 27 3.65 GOR_INVA 2004-10-28 3 11.44 TRKP2602 2004-10-20 27 3.65 MTOB1257 2005-03-23 305 11.26 TIMP0016 2004-10-20 10 1.35 BRYC2002 2004-11-22 21 11.12 TIMP0015 2004-10-20 10 1.35 ADDW0072 2004-10-20 72 11.06 TIMP0014 2004-10-20 10 1.35 DOB_BWRA 2004-11-29 5 10.84 TIMP0006 2004-10-20 10 1.35 KPUB0362 2004-09-27 55 10.66 TIMP0005 2004-10-20 10 1.35 BRY_CP5A 2004-11-22 14 10.33 TIMP0004 2004-10-20 10 1.35 ADDW0092 2004-10-20 67 10.29 STKP0492 2004-10-20 11 2.57 WILTF004 2005-05-26 6 9.86 SPNP1232 2004-10-20 12 1.62 ADDW0082 2004-10-20 63 9.68 SPNP1202 2004-10-20 12 2.77 ALB_SVLA 2004-10-20 2 9.51 SPNP1182 2004-10-20 12 2.77 TIMP0062 2005-03-23 26 9.25 SPNP1172 2004-10-20 12 2.77 HAYI0132 2004-11-22 85 9.19 SPNP1162 2004-10-20 12 2.77 EDGC0222 2005-03-23 23 9.12 SPNP1142 2004-10-20 12 2.77 COL_OTIA 2004-10-20 1 9.02 SPNP1122 2004-10-20 12 2.77 HAYI0202 2004-11-22 42 8.57 PENC0118 2005-05-26 8 1.95 PAPP0202 2004-10-20 55 8.45 PAPP0112 2004-10-20 10 3.56 PAPP0132 2004-10-20 54 8.29 PAPP0102 2004-10-20 9 3.20 SFDI0182 2004-09-27 41 8.28 OTIVT082 2004-10-20 26 1.64 ARIK0152 2005-03-23 33 8.14 OTIVT042 2004-10-20 25 1.58 SFDI0148 2004-09-27 78 8.09 OTAP0232 2005-03-23 10 3.52 SFDI0162 2004-09-27 40 8.08 OTAP0162 2005-03-23 9 3.17 MLGVT012 2005-05-26 108 8.07 OTAP0152 2005-03-23 9 3.17 NSYP1052 2005-05-26 33 7.62 LCH_KINA 2004-09-27 1 1.56 NSYP1092 2005-05-26 33 7.62 KOEB1192 2004-12-16 25 3.12 OTIK0062 2004-07-27 25 7.39 KOEB1152 2004-12-16 25 3.12 HAYI0182 2004-11-22 36 7.34 KOEB1132 2004-12-16 25 3.12 HAYI0192 2004-11-22 36 7.34 ISLP2092 2004-10-20 12 1.62 HAYI0212 2004-11-22 36 7.34 ISLP2082 2004-10-20 12 1.62 BRYP1002 2004-11-22 37 6.83 ISLP2072 2004-10-20 12 1.62 WELB1072 2004-12-16 53 6.61 ISLP1032 2004-10-20 12 2.77 ADDI0042 2004-10-20 36 6.59 ISLP0962 2004-10-20 12 2.77 OTIK0042 2004-07-27 22 6.50 HAYI0122 2004-11-22 19 2.05 WELB1052 2004-12-16 51 6.37 HAYI0102 2004-11-22 19 2.05 TMKP1202 2004-10-20 47 6.35 HAMF2822 2004-05-05 28 2.87 WELI1042 2004-12-16 74 6.34 HAI_MTMA 2004-10-28 1 0.84 HAYI0112 2004-11-22 58 6.27 EDG_KAWA 2004-10-20 2 2.50 OTIK0082 2004-07-27 21 6.20 DOBP1352 2004-10-20 22 3.00 CPK_WILA 2004-07-27 2 6.11 DOBP1332 2004-10-20 22 3.00 BRKC1092 2004-07-22 21 4.77 CPKP2172 2005-05-19 4 0.55 WDVVT002 2005-03-23 63 4.70 ASH_TIMA 2004-11-19 1 1.46 OTAP0092 2005-03-23 13 4.58 ADDW0122 2004-10-20 11 3.91 BPEB1082 2005-03-23 34 4.33 ADDP2812 2005-03-17 12 1.62 MGM_MSTA 2004-10-20 1 4.24 ADDP2802 2005-03-17 26 3.51 HEPP0252 2004-12-16 12 4.23 ADDP2722 2005-03-17 26 3.51 OTAP0302 2005-03-23 12 4.23 ADDP2672 2005-03-17 12 1.62 WELI1082 2004-12-16 47 4.03 ADDP2662 2004-07-27 26 3.51

145

Appendix 6: Specific Asset Values by Location Table A:6.1: AC Transmission Lines: Asset Values by Location

ADJ RC DRC ORC ODRC ODVLocation $000s $000s $000s $000s $000sAddington - Islington A 5,313 2,762 5,313 2,760 2,760 Addington - Islington B 3,422 871 3,422 869 869 Albany - Henderson 2,239 614 2,511 688 688 Albany - Huapai A 5,773 2,224 5,854 2,254 2,254 Albany - Silverdale A 4,697 3,253 4,684 3,246 3,246 Albany - Silverdale B - - 498 290 290 Albany - Silverdale C - - 952 555 555 Arahura - Dobson A 1,909 164 1,909 173 173 Arahura - Otira A 4,634 730 4,486 705 705 Arapuni - Edgecumbe A 6,475 1,069 4,733 782 782 Arapuni - Edgecumbe B 6,550 1,627 4,688 1,164 1,164 Arapuni - Hamilton A 2,580 141 0 0 0 Arapuni - Hamilton B 6,157 336 4,850 254 254 Arapuni - Ongarue A 5,533 678 9 9 9 Arapuni - Ongarue B 9,777 3,378 0 0 0 Arapuni - Pakuranga A 20,905 3,896 20,667 3,853 3,853 Arapuni - Rangitoto A Pseudo - - 4,319 568 568 Aratiatia - Wairakei A 789 272 789 272 272 Ashburton - Timaru A 982 262 1,852 489 489 Ashburton - Timaru B 982 204 0 0 0 Ashley Deviation A 357 61 328 56 56 Ashley - Deviation B 253 130 0 0 0 Ashley - Islington 1,448 1,027 0 0 0 Atiamuri - Tarukenga A 10,168 3,698 10,475 3,809 3,809 Atiamuri - Wairakei A - - 5,924 655 655 Atiamuri - Whakamaru A - - 3,908 643 643 Aviemore - Benmore A 4,100 1,640 4,123 1,649 1,649 Aviemore - Livingstone A 6,240 1,618 7,080 1,835 1,835 Balclutha Deviation A 1,781 615 0 0 0 Balclutha Deviation B Pseudo - - 381 109 109 Benmore - Islington A 61,042 27,324 61,042 27,324 27,324 Benmore - Twizel A 15,389 13,191 15,389 13,188 13,188 Blenheim - Kikiwa A 6,067 910 6,062 910 910 Blenheim - Stoke A 15,449 5,899 15,449 5,892 5,892 Bombay - Meremere A 2,195 200 646 59 59 Bombay - Otahuhu A 4,513 1,078 6,869 1,548 1,548 Brackendale - Hororata A 650 355 1,633 891 891 Bream Bay - Marsden A Pseudo - - 143 123 2- Bream Bay Deviation A 1,283 476 1,023 380 380 Bromley - Islington A 11,009 4,003 10,893 3,961 3,961 Brunswick - Bunnythorpe A 27,720 11,608 27,720 11,603 11,603 Brunswick - Stratford A 22,233 5,707 32,457 8,347 8,347 Brunswick - Stratford B 15,641 1,642 0 0 0

146

Table A:6.1: AC Transmission Lines: Asset Values by LocationADJ RC DRC ORC ODRC ODV

Location $000s $000s $000s $000s $000sBrydone - Deviation A 491 445 492 446 446 Bunnythorpe - Haywards A 17,256 3,063 27,587 4,747 4,747 Bunnythorpe - Haywards B 16,956 2,795 0 0 0 Bunnythorpe - Mangahao A 2,312 754 147 147 147 Bunnythorpe - Mangahao B 2,165 584 0 0 0 Bunnythorpe - Ongarue A 20,269 2,580 11,220 1,428 1,428 Bunnythorpe - Wairakei A 34,323 7,749 34,339 7,752 7,752 Bunnythorpe - Wanganui B 7,987 1,597 6,216 1,239 1,239 Bunnythorpe - Whakamaru A 33,547 6,862 33,881 6,930 6,930 Bunnythorpe - Whakamaru B 33,358 7,278 33,547 7,319 7,319 Bunnythorpe - Wilton A 61,078 28,698 59,501 27,959 27,959 Bunnythorpe - Woodville B 2,992 1,301 3,019 1,312 1,312 Carrington St - EGV - - 1,363 223 223 Carrington St - Huirangi A 2,035 174 1,503 124 124 Carrington St - New Plymouth A 3,818 1,682 2,146 945 945 Carrington St - Stratford A 4,763 1,731 5,650 2,049 2,049 Central Park - Wilton A 872 403 1,332 614 614 Central Park - Wilton B 5,474 873 2,664 426 426 Christchurch - Twizel A 84,525 56,752 84,525 56,752 56,752 Clyde - Roxburgh A 8,374 7,178 8,374 7,178 7,178 Clyde - Twizel A 49,456 42,390 49,456 42,390 42,390 Cobb - Upper Takaka A 1,046 254 752 183 183 Cobb - Upper Takaka B 1,065 213 0 0 0 Coleridge - Brackendale B 2,717 2,614 2,717 2,614 2,614 Coleridge - Otira A 5,980 852 5,980 852 852 Cromwell - Frankton A 5,633 3,380 5,647 3,388 3,388 Cromwell - Clyde - - 1,341 1,045 1,045 Culverden - Kaikoura A 4,267 840 4,232 834 834 Culverden - Waipara 1,806 1,245 1,829 1,261 1,261 Dargaville - Maungatapere A 1,617 353 2,379 1,229 792 Dargaville - Maungatapere B 2,429 2,001 465 465 465 Dobson - Blackwater A 1,431 421 2,419 701 701 Edgecumbe - Kawerau A 743 304 830 339 339 Edgecumbe - Kawerau B 754 238 0 0 0 Edgecumbe - Tarukenga A 15,140 5,918 10,858 4,244 4,244 Edgecumbe - Waiotahi B 1,997 1,092 1,997 1,087 1,087 Fernhill - Redclyffe A 412 217 792 417 417 Fernhill - Redclyffe B 412 172 0 0 0 Fernhill - Woodville A 6,168 3,364 11,720 6,393 6,393 Fernhill - Woodville B 6,013 3,389 0 0 0 Fernhill Deviation A 3,596 2,774 0 0 0 Gisborne - Tokomaru Bay A 7,245 3,557 0 0 0 Gisborne - Tuai A 11,191 3,584 11,191 3,579 3,579 Glenavy - Oamaru A 1,374 389 1,472 408 408 Glenavy - Oamaru B 1,485 432 0 0 0 Glenavy - Timaru A 3,816 555 3,816 551 551 Glenavy - Waitaki A 8,126 1,851 6,999 1,605 1,605

147


Location $000s $000s $000s $000s $000sGlenbrook Deviation A 8,452 3,381 8,527 3,411 3,411 Gore - Halfway Bush A 7,971 1,449 0 0 0 Gore - Invercargill A 1,333 226 2,522 426 426 Gore - Roxburgh A 4,844 851 0 0 0 Gore Deviation - - 443 459 459 Gracefield - Haywards A 6,233 890 2,416 345 345 Hairini - Mt Maunganui A 562 92 562 89 89 Hairini - Mt Maunganui B 516 392 516 392 392 HairiniI - Mt Maunganui BC 1,207 917 1,448 1,101 1,101 Hairini - Tarukenga A 9,112 4,639 8,439 4,296 4,296 Hairini - Tauranga A 566 201 485 169 169 Hairini - Te Matai A 1,004 128 998 127 127 Halfway Bush - Oamaru A 2,626 497 2,122 405 405 Halfway Bush - Oamaru B 2,733 692 0 0 0 Halfway Bush - Roxburgh A 20,895 5,319 0 0 0 Halfway Bush - South Duned 2,954 1,641 3,001 1,667 1,667 Hamilton - Karapiro A 3,668 600 2,762 452 452 Hamilton - Meremere A 4,395 2,139 725 710 710 Hamilton - Meremere B 8,052 439 6,343 328 328 Hamilton - Waihou A 8,320 3,517 8,261 3,489 3,489 Hamilton Deviation A 1,763 1,090 1,863 1,152 1,152 Haywards - Judgeford A 2,261 711 2,202 690 690 Haywards - Khandallah A 980 980 980 980 980 Haywards - Melling A 1,347 115 1,481 122 122 Haywards - Takapu Road A 3,097 265 3,097 256 256 Haywards - Upper Hutt A 3,713 825 1,760 391 391 Henderson - Hepburn Road A 1,458 468 1,560 472 472 Henderson - Huapai A - - 4,620 1,888 1,888 Henderson - Marsden A 47,186 17,945 0 0 0 Henderson - Maungatapere A 19,854 1,635 19,868 1,636 1,636 Henderson - Mt. Roskill A 2,164 774 2,320 824 824 Henderson - Otahuhu A 13,706 5,822 13,706 5,822 5,822 Hepburn Road - Mt. Roskill A 1,633 667 1,766 682 682 Hinuera - Karapiro A 1,244 422 1,165 394 394 Hororata - Islington E 5,528 4,734 5,639 4,826 4,826 Huapai - Marsden A - - 37,945 10,686 10,686 Huirangi - Motunui A 913 572 454 285 285 Huntly - Otahuhu A 30,654 22,386 30,654 22,380 22,380 Huntly - Taumarunui A 59,194 39,821 59,560 40,064 40,064 Huntly - Western Road 143 29 0 0 0 Huntly Deviation A 6,411 4,079 6,683 4,252 4,252 Inangahua - Blackwater A 3,056 445 2,673 933 933 Inangahua - Kikiwa A 5,712 1,212 0 0 0 Inangahua - Kikiwa B 22,233 10,799 20,442 9,929 9,929 Inangahua - Reefton A 2,850 2,843 2,850 2,846 2,846 Inangahua - Waimangaroa 2,955 709 2,755 679 679 Inangahua - Westport B 5,598 4,159 0 0 0 Invercargill - Manapouri A 53,695 28,882 53,695 28,882 28,882 Invercargill - Roxburgh A 21,122 8,961 21,572 9,152 9,152 Invercargill - Roxburgh B 21,021 6,879 21,437 7,016 7,016 Invercargill - Tiwai A 8,085 2,079 8,351 2,147 2,147

148


Location $000s $000s $000s $000s $000sIslington - Kikiwa A 38,437 12,652 38,437 12,930 12,930 Islington - Kikiwa B 57,071 22,081 57,253 21,470 21,470 Islington - Papanui A 3,131 765 33 33 33 Islington - Papanui B 3,097 732 3,097 731 731 Islington - Southbrook A 3,066 419 3,055 419 419 Islington - Springston A 1,959 646 1,959 646 646 Islington Deviation A 1,083 354 1,065 349 349 Kaiapoi - Southbrook A 828 166 494 99 99 Kaikohe - Maungatapere A 7,693 3,637 6,579 3,110 3,110 Kaitawa - Tuai A 1,993 1,082 1,949 1,058 1,058 Kaiwharawhara - Wilton 340 52 367 44 44 Kaiwharawhara - Wilton Cable 1,376 1,151 1,501 1,256 1,256 Karapiro - Te Awamutu A 1,274 475 1,215 453 453 Kawerau - Matahina A 1,480 350 1,050 248 248 Kawerau Deviation A 2,031 1,259 2,031 1,259 1,259 Kensington - Maungatapere A 2,833 1,133 2,021 809 809 Khandallah - Takapu Road A 892 346 0 0 0 Kikiwa - Stoke A 12,237 10,327 12,237 10,327 10,327 Kikiwa - Stoke B 3,105 1,209 3,105 1,206 1,206 Kinleith Deviation A 3,235 1,000 2,583 798 798 Kopu - Waikino A 6,643 3,986 4,531 2,718 2,718 Lichfield - Kinleith A 1,030 229 1,030 229 229 Lichfield - Kinleith B 1,313 215 1,330 218 218 Manapouri - Tiwai A 40,738 19,283 40,738 19,283 19,283 Mangahao - Paekakariki A 3,544 815 0 0 0 Mangahao - Paekakariki B 3,555 818 0 0 0 Mangahao Deviation Pseudo - - 642 250 250 Mangamaire - Masterton A 3,068 195 3,068 298 298 Mangamaire - Woodville A 1,424 544 1,424 544 544 Mangere - Mt. Roskill A 2,418 689 2,640 696 696 Mangere - Otahuhu A 1,686 276 1,686 273 273 Maraetai - Waipapa A 1,502 300 1,443 289 289 Maraetai - Whakamaru A 1,257 69 1,285 69 69 Maraetai - Whakamaru B 1,257 69 1,285 69 69 Marsden - Maungatapere A 9,328 2,643 9,295 2,634 2,634 Masterton - Upper Hutt A 7,439 1,544 5,731 1,189 1,189 Maungatapere - Kaitaia A 2,508 176 30 18 18 Maungatapere - Kaitaia B 3,357 1,119 3,357 1,119 1,119 Meremere - Takanini A 2,126 116 0 0 0 Motunui Deviation A 3,822 1,784 1,383 645 645 Motupipi - Upper Takaka A 855 62 855 62 62 National Park - Retaruke 560 150 407 109 109 New Plymouth - Stratford A 16,145 6,219 9,731 3,750 3,750 North Makarewa 45,963 24,235 45,963 24,234 24,234 Ohaaki - Wairakei A 7,415 3,101 4,925 2,060 2,060 Ohaaki - Wairakei B 33kv line 771 140 772 140 140 Ohakuri - Edgecumbe A 15,093 6,311 15,109 6,318 6,318 Ohau A - Twizel A 1,920 823 1,920 823 823 Okere - Te Matai A 1,566 171 1,566 171 171

149


Location $000s $000s $000s $000s $000sOngarue - Rangitoto A Pseudo - - 2,929 1,012 1,012 Ongarue - Stratford A 5,822 847 0 0 0 Opunaki - Stratford A 5,345 2,332 5,227 2,281 2,281 Ormiston_Whakamaru_A 22,366 22,295 22,366 22,295 22,295 Otahuhu - Pakuranga A 2,858 1,315 1,478 680 680 Otahuhu - Penrose A 1,976 1,400 2,797 1,883 1,883 Otahuhu - Penrose B 6,909 5,719 7,104 5,757 5,757 Otahuhu - Penrose C 3,121 1,190 3,121 1,371 1,371 Otahuhu - Whakamaru A 27,194 4,944 43,264 7,866 7,866 Otahuhu - Whakamaru B 27,181 4,942 0 0 0 Otahuhu - Whakamaru C 65,837 17,014 65,837 17,013 17,013 Oteranga Bay - Haywards A 1,155 1,155 - - - Owhata Deviation A 2,560 1,213 1,177 556 556 Paekakariki - Takapu Road A 2,988 1,003 2,463 827 827 Paekakiriki - Papaparaumu Psdo - - 812 779 779 Pakuranga - Penrose A 1,619 407 2,287 451 451 Penrose - Mt. Roskill A 1,640 508 1,797 557 557 POIHIPI TEE CONNECTION 545 446 376 308 308 Rangipo Deviation A 1,327 917 1,195 826 826 Rangitoto Hills A 1,868 340 1,483 269 269 Reefton 1,129 1,129 1,129 1,129 1,129 Redclyffe - Tuai A 13,671 5,664 20,717 8,583 8,583 Redclyffe - Whirinaki A 8,894 3,812 8,854 3,793 3,793 Rotorua - Tarukenga A 1,684 425 1,443 447 447 Roxburgh - Islington A 54,268 17,831 54,268 17,832 17,832 Roxburgh - Three Mile Hill 35,925 19,630 35,925 19,631 19,631 Southbrook - Waipara A 4,104 703 3,241 556 556 Stoke - Upper Takaka A 2,566 564 4,268 936 936 Stoke - Upper Takaka B 2,685 600 0 0 0 Stratford - Taumarunui A 39,493 20,824 38,924 20,522 20,522 Takapu Road - Wilton A 4,837 415 3,762 310 310 Tangiwai Tee A 2,393 1,871 2,393 1,871 1,871 Tarukenga Deviation A 280 189 114 77 77 Tarukenga Deviation B 687 462 535 360 360 Te Kaha - Waiotahi A 3,086 542 2,985 526 268 Tekapo A - Timaru A 4,514 1,395 4,548 1,402 1,402 Tekapo B Deviation A 865 741 877 752 752 Timaru Deviation A 7,325 3,850 7,265 3,819 3,819 Tuai - Bunnythorpe A 13,524 3,934 0 0 0 Tuai - Wairoa A 4,958 2,459 3,885 1,957 1,957 Te Kowhai Deviation A 936 926 936 930 930 Twizel Deviation A 2,329 1,896 2,329 1,896 1,896 Waihou - Waikino A 4,048 2,061 3,165 1,611 1,611 Waimangaroa - Westport A 1,251 137 2,361 259 259 Poihipi - Whakamaru A Pseudo - - 6,912 1,131 1,131 Wairakei - Poihipi A Pseudo - - 769 108 108 Wairakei - Whakamaru A 8,137 1,245 0 0 0 Wairakei - Whakamaru B 5,621 1,133 32 32 32 Wairakei - Whirinaki A 43,573 30,435 43,689 30,513 30,513 Waitaki Tee A - - 332 123 123 Wanganui - Stratford A 6,217 1,575 6,217 2,121 2,121

Total 2,026,566 847,237 1,837,912 793,752 792,932

150

Table A:6.2: AC Substations: Asset Values by Location

ADJ RC DRC ORC ODRC ODVLocation $000s $000s $000s $000s $000s

Addington 24,441 13,664 19,007 11,645 11,645 Albany 26,278 13,441 23,192 12,171 12,171 Albury 4,863 860 3,872 819 819 Arahura 5,682 1,128 0 0 0 Arapuni 11,041 3,521 7,149 2,865 2,865 Aratiatia Power 2,439 824 2,439 823 823 Argyle 886 273 968 273 273 Arthurs Pass 3,228 1,425 2,265 1,123 1,123 Ashburton 13,500 9,633 12,644 8,953 8,953 Ashley 7,418 3,230 5,464 2,652 2,652 Atiamuri Power 7,488 3,065 5,499 2,756 2,756 Aviemore 5,019 1,510 4,998 1,498 1,498 Balclutha 7,807 4,512 7,964 2,898 2,898 Benmore 30,567 14,892 33,023 14,620 14,620 Berwick 2,526 1,498 4,239 2,431 2,431 Blenheim 8,819 4,926 9,671 5,577 5,577 Bombay 11,362 4,294 19,168 6,082 6,082 Bream Bay - Unmanned 24,407 14,482 16,967 7,175 7,175 Bromley 31,593 11,239 22,537 8,731 8,731 Brunswick 24,176 10,949 12,964 5,374 5,374 Brydone 7,176 5,584 6,620 5,069 5,069 Bunnythorpe 46,178 19,401 40,498 17,959 17,959 Cairnbrae 2,794 1,367 0 0 0 Cambridge 6,344 4,212 6,948 4,311 4,311 Carrington 16,553 4,331 13,169 3,668 3,668 Castle Hill 2,882 1,667 2,370 1,409 1,409 Central Park 19,764 10,717 13,749 9,357 9,357 Clyde 23,581 15,204 14,838 9,081 9,081 Cobb 2,663 529 2,543 516 516 Coleridge 6,847 3,294 4,496 2,433 2,433 Cromwell 10,028 5,707 9,211 5,517 5,517 Culverden 4,057 2,367 3,733 2,197 2,197 Dannyvirke 7,984 2,323 6,025 2,028 2,028 Dargaville 5,132 2,121 4,170 1,910 1,910 Dobson 7,368 5,998 6,893 5,678 5,678 Edendale 7,062 2,159 6,334 1,954 1,954 Edgecumbe 27,428 10,315 14,721 6,312 6,312 Fernhill 10,848 2,404 8,118 1,796 1,796 Frankton 6,473 3,739 6,063 3,507 3,507 Gisborne 17,137 4,621 8,592 2,584 2,584 Glenbrook 22,511 13,177 18,317 10,691 10,691 Gore 8,089 2,944 9,614 5,170 5,170 Gracefield 8,126 3,552 6,836 3,054 3,054 Greymouth 549 315 549 329 329 Greytown 5,421 1,680 6,073 1,618 1,622 Halfway Bush 25,383 7,408 12,715 4,179 4,179 Hamilton 41,293 22,242 34,261 19,089 19,089 Hairini 500 500 500 500 500 Hangatiki 7,804 1,936 6,182 1,531 1,531 Hawera 10,466 5,429 9,406 4,863 4,863 Haywards 66,484 41,282 65,227 40,145 40,145 Henderson 35,094 19,771 29,793 17,206 17,206 Hepburn Road 14,457 8,023 11,922 6,913 6,913 Highbank 41 2 0 0 0 Hikurangi 220 160 91 68 68 Hinuera 7,222 3,434 5,011 2,839 2,839 Hororata 10,641 3,762 7,472 3,204 3,204 Huapai 9,099 8,089 5,648 4,906 4,906 Huirangi 7,234 2,527 6,555 2,371 2,371

151

ADJ RC DRC ORC ODRC ODVLocation $000s $000s $000s $000s $000sHuntly 13,989 6,650 13,779 7,299 7,299 Inangahua 6,980 2,169 6,656 2,077 2,077 Invercargill 35,514 9,983 15,774 4,892 4,892 Islington 90,566 42,687 82,030 38,898 38,898 Kaiapoi 7,033 2,554 5,395 2,093 2,093 Kaikohe 11,501 3,501 9,343 2,400 2,400 Kaikoura 3,173 1,669 3,099 1,610 1,610 Kaitaia 8,924 2,102 5,102 1,690 1,690 Kaiwharawhara 5,090 3,989 4,818 3,795 3,795 Karapiro 5,403 779 3,873 743 743 Kawerau 41,649 18,626 30,672 16,294 16,294 Kensington 6,468 3,853 4,215 2,612 2,612 Khandallah - - 0 0 0 Kikiwa 16,747 6,675 15,660 6,246 6,246 Kinleith 26,895 8,110 16,945 5,690 5,690 Kopu 8,456 3,980 9,292 4,284 4,284 Kumara 31 19 29 17 17 Lichfield 626 437 626 437 437 Linton 9,512 4,885 9,556 4,705 4,705 Livingstone 3,581 1,024 2,400 922 922 Manapouri 8,988 5,962 7,674 4,889 4,889 Mangahao 9,974 2,399 8,213 2,064 2,064 Mangamaire 6,545 3,536 5,855 3,133 3,133 Mangere 13,427 9,231 12,126 8,363 8,363 Maraetai (50kV) 7,591 2,870 6,412 2,500 2,500 Marsden 13,880 4,053 0 0 0 Marton 6,382 3,518 4,622 2,300 2,300 Masterton 8,521 1,639 7,399 1,313 1,313 Matahina 3,270 1,334 3,270 1,323 1,323 Mataroa 6,497 1,814 4,324 1,138 1,138 Maungatapere 16,285 5,525 13,070 4,946 4,946 Maungaturoto 5,107 2,610 6,001 2,669 2,669 Melling 15,203 9,599 10,793 7,001 7,001 Meremere 6,022 877 0 0 0 Motueka 5,688 1,901 6,063 1,535 1,535 Motunui 12,488 6,745 0 0 0 Motupipi 177 102 120 46 46 Moturoa 3,572 1,142 3,215 994 994 Mt Maunganui 12,153 5,072 10,400 4,946 4,946 Mt Roskill 17,272 8,935 14,375 8,682 8,682 Murchison 3,935 616 3,233 674 674 Naseby 6,705 2,506 6,298 2,304 2,304 National Park 3,169 812 1,935 495 495 New Plymouth 16,864 5,445 16,262 5,149 5,149 North Makarewa 22,898 13,392 22,831 13,327 13,327 Oamaru 7,705 3,373 7,004 3,035 3,035 Ohaaki 7,077 4,366 6,746 4,146 4,146 Ohakune 6,899 2,140 3,930 1,118 1,118 Ohakuri 6,595 4,154 5,040 2,760 2,760 Ohau A 4,061 1,800 4,052 1,795 1,795 Ohau B 4,435 2,512 4,435 2,505 2,505 Ohau C 4,435 2,377 4,435 2,371 2,371 Okere 564 170 806 235 235 Oromahoe 59 59 0 0 0 Ongarue 6,036 1,360 4,379 991 991 Opunake 5,773 2,153 4,937 1,671 1,671 Otahuhu 78,248 43,586 61,503 35,033 35,033 Otahuhu Power Switchya 130 61 130 60 60 Otira 6,324 2,337 3,496 814 814 Owhata 7,172 2,364 5,785 2,139 2,139 Pakuranga 16,049 12,639 14,308 11,345 11,345 Palmerston 3,350 347 2,223 365 365 Papanui 17,275 5,053 11,059 3,940 3,940

152

ADJ RC DRC ORC ODRC ODVLocation $000s $000s $000s $000s $000sParaparaumu 7,392 2,738 6,831 2,320 2,320 Pauatahanui 7,082 2,552 6,346 2,237 2,237 Penrose 51,422 29,475 38,453 25,101 25,101 Poihipi 1,960 1,748 2,088 1,797 1,797 Rangipo 8,310 2,665 8,290 2,688 2,688 Redclyffe 22,695 9,712 18,771 8,513 8,513 Robertson Street 294 256 172 150 150 Rotorua 14,374 6,452 11,341 5,014 5,014 Roxburgh 19,972 9,761 13,691 8,516 8,516 Silverdale 6,471 6,017 6,405 5,882 5,882 South Dunedin 12,510 5,915 11,018 5,153 5,153 Southbrook 8,407 4,091 8,409 4,073 4,073 Southdown 3,221 2,552 3,201 2,542 2,542 Springston 6,654 2,570 5,653 2,149 2,149 Stoke 40,406 12,747 35,727 10,600 10,600 Stratford 45,864 17,409 21,630 8,947 8,947 Studholme 6,336 1,307 4,640 1,047 1,047 Takanini 13,362 6,705 11,883 6,093 6,093 Takapu Road 13,478 6,159 11,255 5,281 5,281 Tangiwai 15,830 8,060 13,434 6,735 6,735 Tarukenga 28,018 14,078 21,763 10,584 10,584 Taumarunui 6,515 3,601 7,895 4,076 4,076 Tauranga 13,631 7,881 11,851 6,829 6,829 Te Awamutu 7,569 4,562 6,153 3,809 3,809 Te Kaha 2,336 913 2,011 346 587 Te Kowhai 11,731 11,417 11,731 11,436 11,436 Te Matai 5,456 2,149 5,563 2,177 2,177 Tekapo A 4,627 1,010 3,579 895 895 Tekapo B 3,554 1,824 3,533 1,816 1,816 Temuka 5,970 4,665 5,676 4,396 4,396 Three Mile Hill 8,748 4,944 8,748 4,936 4,936 Timaru 24,370 11,110 16,115 7,772 7,772 Tiwai 28,949 14,050 29,068 14,071 14,071 Tokaanu 13,264 5,180 11,600 4,507 4,507 Tokomaru Bay 3,822 1,269 0 0 0 Tuai 13,695 3,049 7,191 2,433 2,433 Twizel 17,596 7,099 16,413 6,657 6,657 Upper Hutt 9,243 3,122 9,458 3,496 3,496 Upper Takaka 3,060 879 3,060 829 829 Waihou 11,279 2,737 7,438 1,977 1,977 Waikino 8,844 3,058 9,007 2,979 2,979 Waimangaroa 5,911 1,913 0 0 0 Waiotahi 9,628 2,896 10,032 3,802 3,802 Waipapa 1,318 271 1,081 197 197 Waipara 12,319 9,089 10,512 8,077 8,077 Waipawa 9,826 3,830 9,464 4,157 4,157 Wairakei 19,921 12,245 18,502 11,457 11,457 Wairoa 7,179 4,475 4,496 2,536 2,536 Waitaki 18,503 10,741 16,094 9,655 9,655 Wanganui 8,749 2,705 6,392 2,243 2,243 Waverley 4,966 1,116 4,571 726 726 Wellsford 7,943 4,137 5,814 2,467 2,467 Western Road 6,634 1,551 5,206 958 958 Westport 6,507 2,250 5,360 1,804 1,804 Whakamaru 17,080 10,599 16,249 10,268 10,268 Whakatu 10,959 5,480 8,957 4,362 4,362 Whirinaki 16,914 7,694 13,414 6,118 6,118 Wilton 45,708 22,544 41,116 19,545 19,545 Wiri 13,117 8,601 12,140 7,935 7,935 Woodville 7,219 2,049 5,677 1,766 1,766

Total 2,258,132 1,051,517 1,819,482 884,179 884,424

153

Table A:6.3: HVDC Link: Asset Values by Location

ADJ RC DRC ORC ODRC ODVLocation $000s $000s $000s $000s $000s

Benmore - Haywards A 190,410 48,441 190,410 48,441 48,441 Benmore DC 225,893 66,840 210,421 59,619 59,619 Benmore Earth Electrode A 2,711 690 2,711 690 690 Bog Roy Electrode 2,357 1,099 2,357 1,099 1,099 Cook Strait Cable 5 229,199 106,959 229,199 106,959 106,959 Haywards DC 390,451 97,009 320,038 80,001 80,001 Oteranga Bay 19,585 9,140 19,585 9,140 9,140 Oteranga Bay - Haywards A 12,829 4,121 12,829 4,121 4,121 Oteranga Bay - South Makara 2,085 531 2,085 531 531 Te Hikowhenua 7,362 3,437 7,362 3,437 3,437 Te Hikowhenua Deviation A 1,668 453 1,668 453 453

Total 1,084,551 338,719 998,666 314,492 314,492

154

Appendix 7 Existing and Forecast Load Table A7.1 Peak MW by Bus Projected to 2021

Less Forecast Distributed Generation

Peak MW Peak MW BUS ID Name 2006 2021

NORTH ISLAND

NORTH ISTHMUS ALB_33 Albany 33kV 149.9 235.5 ALB_110 Albany 110 (Wairau Rd) 162.4 259.1 BRB Bream Bay 39.9 49.4 DAR Dargaville 9.7 13.3 HEN Henderson 97.9 153.8 HEP Hepburn Rd 132.0 207.3 KEN Kensington 50.1 69.0 KOE Kaikohe 31.1 46.2 KTA Kaitaia 24.7 33.6 MPE Maungatapere 42.7 59.8 MTO Maungaturoto 14.4 19.9 SVL33 Silverdale 61.8 97.0 WEL Wellsford 28.5 44.7

Region Peak After Diversity 786.3 1,201.3 AUCKLAND BOB33 Bombay 33kV 35.8 56.0 BOP110 Bombay 110kV 25.0 39.2 GLNBHP Glenbrook NZ Steel 100.0 100.0 GLNCOU Glenbrook Counties 26.9 42.2 MNG33 Mangere 33kV 85.0 134.5 MNG110 Mangere 110kV 50.2 79.4 MER Meremere 6.7 9.7 OTA Otahuhu 45.0 71.3 PAK Pakuranga 120.2 190.3 PEN22 Penrose 22kV 52.8 83.5 PEN33 Penrose 33kV 264.5 418.8 PEN110 Penrose 110kV 173.3 274.4 ROS22 Mt Roskill 22kV 104.3 165.2 ROS110 Mt Roskill 110kV 168.2 268.4 TAK Takanini 99.4 155.7 WIR Wiri 65.3 103.4

Region Peak After Diversity 1,214.8 1,872.8 WAIKATO CBG Cambridge 31.1 45.6 HAMNZR Hamilton NZR 7.5 11.0 HAM11 Hamilton 11kV 32.8 48.8 HAM33 Hamilton 33kV 78.1 121.2 HIN Hinuera 34.3 43.8 HTI Hangatiki 26.0 31.4 KIN11_1 Kinleith 11kV - 1 32.0 32.0 KIN11_2 Kinleith 11kV - 2 32.0 32.0 KIN11_3 Kinleith 11kV - 3 19.3 19.3 KIN33 Kinleith 33kV 17.2 17.2 KPU Kopu 41.2 52.7 LFD Lichfield 9.9 12.6 OKI Ohaaki 2.9 4.0 TKW Te Kowhai 78.1 121.2 TMU Te Awamutu 28.5 38.9 WES Western Rd 18.4 27.3 WHU Waihou 54.9 70.2 WKO Waikino 28.8 38.0 WRK Wairakei 35.1 59.5 WKM Whakamaru 7.2 8.7

Region Peak After Diversity 508.99 683.64

155

Peak MW Peak MW

BUS ID Name 2006 2021

BAY OF PLENTY EDG Edgecumbe 49.5 64.1 KAWBOP Kawerau BOP 28.3 36.8 KAW_11/T4 Kawerau T4 17.2 17.2 KAW_11/T9 Kawerau T9 17.2 17.2 KAW_11/T6 Kawerau T6 17.2 17.2 KAW_11/T7 Kawerau T7 17.2 17.2 KAW_11/T8 Kawerau T8 17.2 17.2 KAW_11/T11 Kawerau T11 45.4 45.4 KAW_11/T14 Kawerau T14 45.4 45.4 MTM11 Mt Maunganui 11kV 17.9 28.8 MTM33 Mt Maunganui 33kV 35.8 57.7 OWH Owhata 14.0 18.9 ROT11 Rotorua 11kV 31.9 43.0 ROT33 Rotorua 33kV 38.1 51.4 TGA11 Tauranga 11kV 24.3 39.1 TGA33 Tauranga 33kV 53.3 103.5 TRK11 Tarukenga 11kv 8.1 10.9 TKH Te Kaha 1.3 1.6 TMI Te Matai 23.8 38.3 WAI Waiotahi 7.3 9.1


CENTRAL BPENZR Bunnythorpe NZR 6.1 6.1 BPE33 Bunnythorpe 33kV 80.5 107.7 BRK Brunswick 28.4 32.4 DVK Dannevirke 13.5 15.2 LTN Linton 44.5 75.4 MHO Mangahao 32.6 43.8 MGM Mangamaire 10.7 14.4 MTN Marton 13.9 15.8 MTR Mataroa 6.8 7.8 NPK National Park 5.9 6.5 OKN Ohakune 7.5 8.3 ONG Ongarue 7.6 9.4 TKU Tokaanu 9.0 11.1 TNGNZR Tangiwai NZR 7.5 7.5 TNG11 Tangiwai 11kV 49.3 49.3 WDV Woodville 2.8 3.2 WPW Waipawa 19.6 22.7 WGN Wanganui 33.2 37.9


HAWKE'S BAY FHL Fernhill 49.8 66.3 GIS50 Gisborne 50kV 44.9 56.9 RDF Redclyffe 58.5 77.9 TUI Tuai 0.7 0.7 WHI Whirinaki 11 kV Bus A 40.3 40.3 WHI Whirinaki 11 kV Bus B 40.3 40.3 WHI Whirinaki 11 kV Bus C 0.2 0.2 WRA11 Wairoa 11kV 9.4 10.8 WTU Whakatu 78.6 104.6


156

Peak MW Peak MW


TARANAKI CST11 Carrington St 11kV 16.9 23.5 CST33 Carrington St 33kV 32.1 40.7 HWA Hawera 25.6 30.6 HUI Huirangi 13.4 16.1 MNI-1 Motunui - 1 2.6 2.6 MNI-2 Motunui - 2 2.6 2.6 MRA Moturoa 15.9 20.1 OPK Opunake 10.7 12.7 SFD Stratford 34.4 38.9 TMN Taumarunui NZR 10.9 10.9 WVY Waverley 3.7 4.5


WELLINGTON CPK11-1 Central Park 11kV -1 9.0 12.7 CPK11-2 Central Park 11kV -2 9.0 12.7 CPK33-1 Central Park 33kV -1 62.9 89.0 CPK33-2 Central Park 33kV -2 62.9 89.0 GFD Gracefield 52.7 70.1 GYT Greytown 10.6 15.6 HAY11 Haywards 11kV 17.0 23.4 HAY33 Haywards 33kV 13.4 17.9 KWA-1 Kaiwharawhara-1 22.4 31.7 KWA-2 Kaiwharawhara-2 22.4 31.7 MST Masterton 33.7 42.9 MLG11 Melling 11kV 21.9 29.2 MLG33 Melling 33kV 41.4 55.0 PNI Pauatahanui 18.4 24.5 PRM Paraparaumu 60.9 86.7 TKR Takapu Rd 79.8 106.1 UHT Upper Hutt 30.7 40.9 WIL Wilton 75.4 106.6 Region Peak After Diversity 604.2 829.2 SOUTH ISLAND

NELSON/MARLBOROUGH BLN Blenheim 57.9 84.9 KIK Kikiwa 2.9 4.3 MOT Motueka 18.5 27.8 MPI Motupipi 7.0 10.5 STK Stoke 114.6 158.0 Region Peak After Diversity 196.2 278.7 WEST COAST APS Arthur's Pass 0.3 0.5 CLH Castle Hill 0.6 0.9 DOB Dobson 12.2 17.6 GYM Greymouth 11.4 14.1 HKK Hokitika 12.3 16.4 MCH Murchison 2.4 3.7 ORO Orowaiti 13.4 16.4 OTI Otira 0.3 0.3 RFT Reefton 3.6 4.5 WPT Westport 9.3 11.3


157

Peak MW Peak MW


CANTERBURY ADD1101 Addington 11kV -1 24.4 35.0 ADD1102 Addington 11kV -2 45.3 64.9 ADD6601 Addington 66kV -1 66.5 95.2 ADD6602 Addington 66kV -2 66.5 95.2 ASB0331 Ashburton 33 59.8 80.2 ASB0661 Ashburton 66 57.9 77.3 ASY Ashley 11.4 18.5 BRY11 Bromley 11kV 63.1 90.4 BRY6601 Bromley 66kV 91.5 131.1 BRY6602 Heathcote (off BRY66) 22.9 32.8 COL Coleridge 0.4 0.5 CUL Culverden 8.6 14.0 HOR33 Hororata 33kv 22.2 31.8 HOR66 Hororata 66kv 22.0 31.5 ISL33 Islington 33kV 82.7 118.6 ISL6601 Islington 66kV 68.5 98.1 ISL6602 Halswell (off ISL66) 17.1 24.5 KAI Kaiapoi 19.8 26.7 KKA Kaikoura 7.4 11.9 PAP1101 Papanui 11kV-1 33.3 47.8 PAP1102 Papanui 11kV-2 33.3 47.8 PAP66 Papanui 66kV 39.8 57.0 SBK Southbrook 33.9 54.8 SPN Springston 47.3 67.7 WPR Waipara 13.3 21.6


SOUTH CANTERBURY ABY Albury 3.5 6.1 TIM Timaru 60.9 73.8 TKA Tekapo A 2.8 3.6 TMK Temuka 43.1 55.2 TWZ Twizel 4.5 5.3


OTAGO/SOUTHLAND BAL Balclutha 25.9 32.3 BDE Brydone 9.8 12.1 CYD Clyde 6.9 18.2 CML Cromwell 21.2 34.5 EDN Edendale 20.5 25.3 FKN Frankton 42.1 64.9 GOR Gore 31.7 39.1 HWB3301 Halfway Bush -1 48.5 65.5 HWB3302 Halfway Bush -2 84.6 114.1 INV Invercargill 84.4 102.1 NMA North Makarewa 41.9 52.8 NSY Naseby 27.6 36.8 OAM Oamaru 30.9 36.3 PAL Palmerston 5.6 7.0 SDN South Dunedin 66.5 89.8 STU Studholme 13.4 17.1 TWI Tiwai 608.4 608.4 WTK Waitaki 4.4 5.1

Region Peak After Diversity 1,073.7 1,223.1

158

Appendix 8: Glossary of Terms and Abbreviations Table A8.1: Location CodesCode Name Code Name Code NameABY Albury ISL Islington Sub ROS Mt RoskillADD Addington Sub KAI Kaiapoi ROT Rotorua Sub StationAHA Arahura KAW Kawerau ROX RoxburghALB Albany KEN Kensington RPO RangipoANA Arohena KHD Khandallah SBK SouthbrookAPS Arthurs Pass KIK Kikiwa SDN South DunedinARA Aratiatia Power KIN Kinleith SFD StratfordARG Argyle KKA Kaikoura SPN SpringstonARI Arapuni KOE Kaikohe STK StokeASB Ashburton KPO Karapiro STU StudholmeASY Ashley KPU Kopu SVL SilverdaleATI Atiamuri Power KTA Kaitaia SWN SouthdownAVI Aviemore KWA Kaiwharawhara TAK TakaniniBAL Balclutha LFD Lichfield TGA TaurangaBDE Brydone LIV Livingstone TIM TimaruBEN Benmore LTN Linton TKA Tekapo ABLN Blenheim MAN Manapouri TKB Tekapo BBOB Bombay MAT Matahina TKH Te KahaBPE Bunnythorpe Sub MCH Murchison TKR Takapu RoadBRB Bream Bay - Un-manned MDN Marsden TKU TokaanuBRK Brunswick MER Meremere TMH Three Mile HillBRY Bromley MGM Mangamaire TMI Te MataiBWK Berwick MHO Mangahao TMK TemukaCBE Cairnbrae MLG Melling TMN TaumarunuiCBG Cambridge MNG Mangere TMU Te AwamutuCLH Castle Hill MNI Motunui TNG TangiwaiCML Cromwell MOT Motueka TOB Tokomaru BayCOB Cobb MPE Maungatapere S/Stn TPR Unisys HouseCOL Coleridge MPI Motupipi TRK TarukengaCPK Central Park MRA Moturoa TUI TuaiCSM Cashmere MRR Marotiri TWI TiwaiCST Carrington MST Masterton TWZ TwizelCUL Culverden MTI Maraetai (50kV) UHT Upper HuttCYD Clyde MTM Mt Maunganui UTK Upper TakakaDAR Dargaville MTN Marton WAI WaiotahiDOB Dobson MTO Maungaturoto WDV WoodvilleDVK Dannyvirke MTR Mataroa WEL WellsfordEDG Edgecumbe NMA North Makarewa WES Western RoadEDN Edendale NPK National Park WGN WanganuiFHL Fernhill NPL New Plymouth WHI WhirinakiFKN Frankton NSY Naseby WHU WaihouGFD Gracefield OAM Oamaru WIL WiltonGIS Gisborne OHA Ohau A WIR WiriGLN Glenbrook OHB Ohau B WKM WhakamaruGOR Gore OHC Ohau C WKO WaikinoGYM Greymouth OHK Ohakuri WMG WaimangaroaGYT Greytown OKE Okere WPA WaipapaHAI Hairini OKI Ohaaki WPR WaiparaHAM Hamilton Sub OKN Ohakune WPT WestportHAY Haywards Sub Station OME Oromahoe WPW WaipawaHBK Highbank ONG Ongarue WRA WairoaHEN Henderson OPK Opunake WRK WairakeiHEP Hepburn Road OTA Otahuhu WTH WaitahaHHI Hari Hari OTI Otira WTK WaitakiHIN Hinuera OWH Owhata WTN WintonHLY Huntly PAK Pakuranga WTU WhakatuHOR Hororata PAL Palmerston WVY WaverleyHPI Huapai Sub PAP PapanuiHTI Hangatiki PEN PenroseHUI Huirangi PNI PauatahanuiHWA Hawera PPI PoihipiHWB Halfway Bush PRM ParaparaumuIGH Inangahua RDF RedclyffeINV Invercargill RFT Reefton

159

A8.2: Glossary of Abbreviations A ampere AB airblast circuit breaker AC alternating current BO 11 kV bulk oil 11 kV circuit breaker BO bulk oil circuit breaker BSP bulk supply point CABL cable CTs current transformers DB double bus dc double circuit DC direct current DCF discounted cash flow DCSC double circuit single conductor DCST double circuit steel tower DCP double circuit pole DLB Distribution Line Business EF earthquake zone factor EHV extra high voltage ESANZ Electricity Supply Association of New Zealand EV economic value GIS gas insulated switchgear HVDC high voltage direct current (link) ID indoor IDC interest during construction km kilometre kV kilovolt

160

LV low voltage MEA modern equivalent asset MEPL Mott Ewbank Preece Limited MO minimum oil circuit breaker MVA mega volt-amp Mvar megavar (volts amperes reactive) MW mega watt NCT neutral current transformer NIA new investment agreement NPV net present value OD outdoor ODJB outdoor junction box ODRC optimised depreciated replacement cost ODV optimised deprival valuation OFAF oil forced air forced OLTC on load tap changer ONAF oil natural air forced ORC optimised replacement cost PM project management POS point of supply PV present value ROV remotely operated vessel SB single bus sc single circuit SCDC single circuit double conductor SCST single circuit steel tower SCP single circuit pole SF6 sulphur hexafluoride circuit breaker

161

UTS ultimate tensile strength VTJB voltage transformer junction box WACC weighted average cost of capital

appendix 1: ac modern equivalent assets and replacement costs · 77 appendix 1: ac modern...

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