asset management plan update - northpower · 2019-03-29 · asset management plan update 2019 -...

March 2019

Asset Management Plan Update

2019 - 2029

© COPYRIGHT 2019 Northpower Limited. All rights reserved. This document is protected by copyright vested in Northpower Limited (Northpower). Any breach of Northpower’s copyright may be prevented by legal proceedings seeking remedies including injunctions, damages and costs. Any material prepared in breach of Northpower’s copyright must be delivered to Northpower immediately upon request by Northpower.

DISCLAIMER. The information in this document is provided in good-faith and represents Northpower’s opinion as at the date of publication. Northpower does not make any representations, warranties or undertakings either express or implied, about the accuracy or the completeness of the information provided; and the act of making the information available does not constitute any representation, warranty or undertaking, either express or implied. This document does not, and is not intended to; create any legal obligation or duty on Northpower. To the extent permitted by law, no liability (whether in negligence or other tort, by contract, under statute or in equity) is accepted by Northpower by reason of, or in conjunction with, any statement made in this document or by any actual or purported reliance on it by any party. Northpower reserves all rights to alter, in its absolute discretion, any of the information provided in this document.

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Asset Management Plan Update

2019 - 2029Table of Contents

1 Asset Management Plan Update 12 Network Demand and Performance 2

2.1 Network Demand 22.2 Network Performance 32.3 Customer Perspectives 4

3 Changes to our Network Development Plans 63.1 Network Development Plans 63.2 Changes to Forecast CAPEX (Schedule 11a) 63.3 Major CAPEX Projects 2019 7

4 Changes to Life Cycle Asset Management Plans (Maintenance and Renewal) 8

4.1 Life Cycle Asset Management Plan 84.2 Changes to Forecast OPEX (Schedule 11b) 8

5 Changes to Asset Management Practices 95.1 Asset Management Maturity 95.2 Changes in practices 95.3 Network improvement initiatives: 9

Appendix ALoad Forecast 10

Appendix B10 year Network Development Plan 17

Appendix CYear-beginning Information Disclosure Schedules (2019 - 2029) Schedule 11a: Report on Forecast Capital Expenditure 18Schedule 11b: Report on Forecast Operational Expenditure 23Schedule 12a: Report on Asset Condition 24Schedule 12b: Report on Forecast Capacity 26Schedule 12c: Report on Forecast Network Demand 27 Schedule 12d: Report on Forecast Interruptions and Duration 28Schedule 14a: Mandatory Explanatory Notes on Forecast Information 29Schedule 17: Certification for Year-beginning Disclosures 30

Northpower Limited | Asset Management Plan Update 2019-2029 Page 1

Asset Management Plan Update - Section 1

1 Asset Management Plan Update This supplement to our Asset Management Plan published in March 2018 (for the period 2018 - 2028) provides an update to Northpower’s approach to managing its assets and delivering the planned programmes of capital and operational spend, as well as planned maintenance work for the period 1 April 2019 to 31 March 2029.

Northpower’s 2018 Asset Management Plan is available from Northpower’s website at northpower.com/amp. This update should be read in conjunction with that document and outlines how we are managing our Network assets for the efficient delivery of electricity to consumers.

Covered in this update are:

1. Material changes to the network development plans disclosed in the last AMP;

2. Material changes to the lifecycle asset management (maintenance and renewal) plans disclosed in the last AMP;

3. An outline of the reasons for material changes to the previous disclosures in the report on Forecast Capital Expenditure set out in Schedule 11a and Report on Forecast OPEX set out in Schedule 11b; and

4. Changes to Northpower’s asset management practices.

Stakeholder FeedbackNorthpower encourages feedback to enable continued improvement in meeting the needs of its consumers and stakeholders.

Feedback should be addressed to:

Dennis PushenkoAsset ManagerNorthpowerPrivate Bag 9018Whangarei Mail CentreWhangarei 0148

Email: [email protected]

Northpower Limited | Asset Management Plan Update 2019-2029

Section 2 - Network Demand and Performance

2 Network Demand and Performance

2.1 Network Demand

Network demand continues to track to forecast, with emerging technologies not yet having an impact on peak demand.

Peak demand on Northpower’s network for the year ended 31 March 2018 was 166MW (half-hour average) and 172MW (instantaneous). A total of 1,095GWhr of energy was delivered to 58,910 customers.

An updated 10 year load forecast shows an increase (MW instantaneous peak) in line with prior forecasts, as shown in the chart below. A more detailed forecast by zone substation and GXP is provided in Appendix A.

In this update, the two significant distributed generation plants (Wairua hydro station and Trustpower diesel peaking station) with a combined output of 15MW have been separated from the GXP stations to which they are connected, grouped together under generation in order to present forecast loadings with no generation and with maximum generation. The reason for this is that the generation station output at TOSP (time of system peak) is unpredictable and can influence peak demand by as much as 8%.

Growth in maximum demand over the next 10 years is largely dependent on economic activity, however developments in the areas of time of use tariffs, electric vehicle battery charging, PV generation and battery storage systems are expected to have an impact on peak demand towards the end of the planning period. As it is difficult to predict the future net effect of these developments on peak demand, at this stage no specific allowance has been made in the load forecast. We will consider the use of scenario based load forecasting methodologies as part of our next full Asset Management Plan (available 1 April 2020).

Solar PV system connectionsA total of 649 solar PV generation systems were connected to the Northpower network for the year ended 31 March 2018, with a total installed capacity of 2.7MVA (an increase of 145 connections, with capacity of 539 kVA). Based on the information we have, less than 2% of these PV connections also have battery storage. The impact of PV generation on peak demand is currently negligible as it does not coincide with early morning and evening peak demand periods.

Legend

0

50

100

150

200

250

2019 2020 2021 2022 2023 2024 2025 2026 2027 2028 2029

10 Year Load Forecast (MW instantaneous)

Network ADMD (with generation) Network ADMD (no generation)


Network Demand and Performance - Section 2

Consistent with previous forecasts, the below graph shows Northpower’s recorded annual peak demand from 2012 to 2018 as well as the peak demand forecast from 2019 to 2029.

Legend

0

50

100

150

200

250

2012

2013

2014

2015

2016

2017

2018

2019

2020

2021

2022

2023

2024

2025

2026

2027

2028

2029

Historical and forecast peak demand (grid)2012-2018 actual; 2019 -2029 Forecast

2.2 Network Performance

Network performance remains consistent with prior years.

Northpower’s network performance, as measured in unplanned SAIDI minutes, has remained reasonably consistent over the last 10 years, barring adverse weather events, against an internal target of not more than 90 unplanned SAIDI minutes a year.

Legend

0

50

100

150

200

250

300

350

2009 2010 2011 2012 2013 2014 2015 2016 2017 2018

Total Excluding Adverse Weather Target

SAIDI (unplanned interruptions) FY09 -FY18


As shown below defective equipment accounted for 13% of our interruptions in FY18 (and 20% of SAIDI minutes), a level consistent with prior years’ performance.

Legend

0%

5%

10%

15%

20%

25%

30%

35%

Adverse

Environmen

t

Adverse

Wea

ther

Defecti

ve Equipmen

t

Human Erro

r

Lightning

Third Part

y

Interfer

ence

Unknown/O

ther

Vegeta

tion

Wild

life

Causes of unplanned interruptions FY18

% of customer minutes % of customers interrupted

With these factors and current understanding of asset condition, we are satisfied that the level of investment on asset replacement is sufficient to maintain current levels of service.

2.3 Customer Perspectives

Customer satisfaction with network performance remains strong.

Customer Satisfaction Survey

The annual survey of 400 Northpower consumers carried out in March 2018 highlighted continuing high satisfaction with Northpower and an improvement for the year ending March 2018, relative to the prior year. This was reflected in improvements in scores for reputation, communications and core service delivery.

Measured on a scale of 1 to 10, 83% of commercial customers and 88% of residential customers said they were very satisfied with Northpower (giving a score of 8 to 10), a favourable increase on the results of last year.

ResidentialCommercial

2018(%8-10)

2017 79% 83%

83% 88%

Commercial Residential

2017 Whangarei Kaipara Urban Rural

83% 86% 85% 83% -

74% 75% 87% 76% -

79% 84% 80% 82% -

79% 80% 78% 82% -

77% 77% 83% 80% -

74% 78% 83% 78% -

- 73% 88% 75% -

Performance measurement: Core services, Commercial customers (1)(2)(3)

’

28%

41%

36%

8%

8%

8%

86%

80%

83%

79%

79%

80%

77%

Overall reliability of power supply

Minimising the number of outages

How quickly the power is restored when there is an outage

Embracing technology to improve their service

Being quick to respond to issues

Their focus on maintaining the lines

Their focus on continued investment in their network

Commercial

Performance (% 8-10)Impact

NCI

Small sample for rural commercial, n=14, data not shown.


75% 84% 79% 84% 80%

76% 77% 81% 78% 75%

77% 83% 84% 83% 86%

78% 83% 83% 86% 73%

77% 77% 80% 77% 80%

71% 81% 82% 83% 74%

66% 72% 71% 71% 76%

77% 80% 81% 80% 83%

76% 80% 74% 80% 77%

Performance measurement: Image and reputation, Residential customers (1)(2)(3)(4) Residential

54%

32%

27%

22%

15%

2%

1%

1%

83%

78%

84%

83%

77%

81%

72%

80%

79%

Overall image and reputation

Focus on delivering quality services

Trusted to do the right things for the community

Being highly professional

Their commercial performance

Being progressive, positive and up with the times

Caring about the environment

Caring about the local Northland community

Having strong leadership

Impact

NCI

Commercial customers evaluate Northpower’s performance well on the major drivers of services, including the key driver, ‘minimising outages

Residential customers also have a positive view of Northpower’s reputation and in particular, evaluate performance highly on the two key drivers: focus on quality and trust

Performance (% 8-10)

NOTES:1. Sample: 2017 Total commercial n=100; 2018 Total commercial n= 100, Commercial urban n=86, Commercial rural n=14, Commercial Whangarei n=64, Commercial Kaipara n=372. CS1. For these next few questions I’d like you to think about the services that Northpower provides. Again, we’ll use a 1-10 scale where 1 means ‘Extremely poor’ and 10 means ‘Excellent’. So how would you rate Northpower for...3. NCI: No current impact

NOTES:1. Sample: 2017 Total residential n=300; 2018 Total Residential n= 300, Residential urban n=221, Residential rural n=79; Whangarei n=161, Kaipara n=1392. IR1. For the next few questions I’d like you to think about Northpower’s image and reputation. Using a 1-10 scale where 1 means ‘Extremely poor’ and 10 means ‘Excellent’, how would you rate Northpower for each of the following?3. IR9. And when you think about all of these things, the quality of their service, their leadership, vision, how they contribute to the community and the trust you have in them, overall how would you rate the image and reputation of Northpower?4. NCI: No current impact

Overall Customer Satisfaction

Section 2 - Network Demand and Performance


Our customers’ view on Northpower’s delivery against core services indicated that we were meeting expectations, as illustrated in the charts below.

Residential Customers:


2018(%8-10)

2017 79% 83%

83% 88%



83% 86% 85% 83% -

74% 75% 87% 76% -

79% 84% 80% 82% -

79% 80% 78% 82% -

77% 77% 83% 80% -

74% 78% 83% 78% -

- 73% 88% 75% -


’

28%

41%

36%

8%

8%

8%

86%

80%

83%

79%

79%

80%

77%








Commercial


NCI



75% 84% 79% 84% 80%

76% 77% 81% 78% 75%

77% 83% 84% 83% 86%

78% 83% 83% 86% 73%

77% 77% 80% 77% 80%

71% 81% 82% 83% 74%

66% 72% 71% 71% 76%

77% 80% 81% 80% 83%

76% 80% 74% 80% 77%


54%

32%

27%

22%

15%

2%

1%

1%

83%

78%

84%

83%

77%

81%

72%

80%

79%










Impact

NCI






Commercial Customers:


2018(%8-10)

2017 79% 83%

83% 88%



83% 86% 85% 83% -

74% 75% 87% 76% -

79% 84% 80% 82% -

79% 80% 78% 82% -

77% 77% 83% 80% -

74% 78% 83% 78% -

- 73% 88% 75% -


’

28%

41%

36%

8%

8%

8%

86%

80%

83%

79%

79%

80%

77%








Commercial


NCI



75% 84% 79% 84% 80%

76% 77% 81% 78% 75%

77% 83% 84% 83% 86%

78% 83% 83% 86% 73%

77% 77% 80% 77% 80%

71% 81% 82% 83% 74%

66% 72% 71% 71% 76%

77% 80% 81% 80% 83%

76% 80% 74% 80% 77%


54%

32%

27%

22%

15%

2%

1%

1%

83%

78%

84%

83%

77%

81%

72%

80%

79%










Impact

NCI






This feedback validates our current approach to asset management, including targeting reliability improvements such as improvements in vegetation management effectiveness and efficiency, our defect identification, classification and remediation process and asset replacement programme. Also see Section 5.3 of this document for other Network initiatives.

Network Demand and Performance - Section 2


3 Changes to our Network Development Plans

3.1 Network Development Plans

There are no material changes to our network development plans to those disclosed in our 2018 Asset Management Plan.

Our modelling suggests that continued residential development in the Mangawhai area may result in faster than average load growth with potential capacity constraint. Current peak load is 7.5MW and with higher than normal incremental load growth, the two 5MVA transformers at Mangawhai zone substation may reach their firm capacity in FY28. In addition to the capacity constraint at Mangawhai substation, the projected load increase may require an increase in security of supply whereby the single 33kV sub-transmission line supplying Mangawhai will likely require duplication to comply with Network planning guidelines (duplication of transformer and sub transmission lines assets generally required where the connected total peak load exceeds 5MVA).

We will be examining a range of traditional network augmentation and non-network development options to relieve those constraints, including consulting with relevant stakeholders, and our preferred investment option will be reflected in our next full Asset Management Plan (available 1 April 2020).

Our 10 year network development plan can be found in Appendix B.

3.2 Changes to Forecast CAPEX (Schedule 11a)

Forecast CAPEX expenditure for the updated planning period is $200M (constant prices), unchanged from the 2018 AMP forecast CAPEX expenditure.

Our 10 year capital expenditure forecast is shown below.

Legend

$0

$2

$4

$6

$8

$10

$12

$14

$16

$18

$20

$22

$24

FY20 FY21 FY22 FY23 FY24 FY25 FY26 FY27 FY28 FY29

Mill

ions

CAPEX Forecast (FY20-FY29) - Constant Prices

System Growth

Asset Relocations

$0

$2

$4

$6

$8

$10

$12

$14

$16

$18

$20

$22

$24

$26

$28


Mill

ions

OPEX Forecast (FY20-FY29) - Constant Prices

Service interrruptions and emergencies

Asset Replacement & Renewal

Consumer Connection

Reliability, Safety and Environment

Non-Network Assets

Business support

Asset replacement and renewal

Vegetation management

Systems operations and network support

Routine and corrective maintenance and inspection

A copy of our Schedule 11a disclosure – Report on forecast capital expenditure is also provided in Appendix C.

Section 3 - Changes to the Network Development Plan


3.3 Major CAPEX Projects 2019

The major projects below have been completed or progressed in FY19.

SYSTEM GROWTH

Onerahi substation Upgrade to substation transformers to meet increasing capacity requirements due to population growth.($1.8M) - 60% completion

Maunu substation Construction of new substation to meet increasing capacity demands due to population growth. Provides enhanced back-feeding capacity to strengthen network resilience and n-1 supply to the Whangarei base hospital.

($3.2M) - Stage 1 completed – Design and Procurement

RELIABILITY IMPROVEMENTS

Maungatapere substation Installation of a new transformer to ensure continued n-1 security and reliability.

($1M) - 80% completed

Kioreroa Sub-transmission circuit Construction of a second sub-transmission circuit to provide a reliable supply to the Kioreroa industrial area.($1.5M) - 60% completed

Overhead conductor replacement Assessment and replacement of overhead conductor in poor condition to ensure continuing reliable and safe supply. ($0.9M) - 30km of conductor replaced

Whangarei south 11kV switchboard replacement Replacement of end of life switchgear.

($1.8M) - 30% completed

Ngunguru transformer upgrade Replacement of an end of life 3.75MVA transformer with a new 5MVA unit to meet increased capacity requirements.($0.7M) - 30% completed

Section 3 - Changes to the Network Development Plan Changes to the Network Development Plan - Section 3


4 Changes to Life Cycle Asset Management Plans (Maintenance and Renewal)

4.1 Life Cycle Asset Management Plan

There are no material changes to Northpower’s maintenance and renewal plans as disclosed in our 2018 Asset Management Plan.

4.2 Changes to Forecast OPEX (Schedule 11b)

Forecast OPEX expenditure for the planning period is $248M (FY19 NZ Dollars) reflecting targeted investments in key service areas.

The new forecast is $17M above the figures showed in the 2018 AMP and reflects an increase in the cost of proposed work over the 10 years of $4.1M and investment in business support costs of $13.3M for the same period.

Legend

$0

$2

$4

$6

$8

$10

$12

$14

$16

$18

$20

$22

$24


Mill

ions

CAPEX Forecast (FY20-FY29) - Constant Prices

System Growth

Asset Relocations

$0

$2

$4

$6

$8

$10

$12

$14

$16

$18

$20

$22

$24

$26

$28


Mill

ions

OPEX Forecast (FY20-FY29) - Constant Prices

Service interrruptions and emergencies

Asset Replacement & Renewal

Consumer Connection

Reliability, Safety and Environment

Non-Network Assets

Business support

Asset replacement and renewal

Vegetation management

Systems operations and network support

Routine and corrective maintenance and inspection

The increase in business support costs are aimed at increasing our capability in strategic initiatives and ensuring Northpower network is meeting internal and external stakeholder expectations. The areas of investment include:

Health, Safety, Quality and Environment

Investment in capability to meet Network obligations as a PCBU, to support public safety strategy, ensure safety inputs at the planning and design stages of network projects and to support safety auditing.

Customer Services Provision of enhanced customer services to meet customer expectations, particularly in respect of network connections and contestability of network services. Increased capability to support structured and meaningful engagement with customers and stakeholders to enable the network to best meet long-term customer needs.

Asset Management Maturity Support the adoption of risk based asset management for asset portfolios and network as a whole.

Project Delivery Implementation of centralised project management methodology supported by software solutions.

Network Operations Improvement in operational performance and resiliency through ADMS implementation, response & contingency plan development and enhancement of operational procedures and outage management.

A copy of the Schedule 11b disclosure is also provided in Appendix C.

Section 4 - Changes to the Life Cycle Asset Management Plan


5 Changes to Asset Management Practices

Northpower is expecting to make significant enhancements to its asset management practices over the next two to five years.

5.1 Asset Management MaturityNorthpower is committed to adopting a modern asset management approach whereby investment decisions are made based on the combination of asset health and criticality. This is consistent with our long-term aim to reflect an asset management approach consistent with ISO 55000:2016.

Our anticipated predictive asset management model will provide more automated work programming options for asset and network risk management investments. We expect to complete the asset risk categorisation by 2022 and integrate this into asset investment decisions by 2025.

5.2 Changes in practicesNorthpower is evolving its approach to applying asset health and criticality assessments to inform investment replacement decisions and some changes in this respect have been made in the last 12 months. This work is ongoing and explained below.

Asset Health Indices Former Grade Indices (G1-G4) have been reviewed and translated to the new Health Index scale.

Asset Health Indices (H1-H5) have been applied for all major network installations. The adopted approach takes into consideration the age of the asset compared to the Standard Life Values (ODV), empirical evidence of typical asset performance based on recorded defects and faults and major maintenance or refurbishment applied to the assets.

Northpower is undertaking asset specific analysis of the available condition data and refinement of the data requirements followed by further calibration of Health Index categories. This will assist in identifying assets that are likely to fail first and replacement programs will be adjusted accordingly.

Asset Criticality Work is underway on defining asset criticality. All assets have been categorised by their Failure Modes and Failure Causes, followed by analysis of Failure Consequences (Effects) and risk Controls (FaMECA).

Risks associated with the specifics of asset aging, location and modes of operation have been estimated and these values are applied in the asset registers.

Assets with particularly high exposure to safety, reliability or environmental risks are set with highest criticality. When this work is completed, the asset criticality assessments will assist the prioritisation of work in the delivery planning process.

5.3 Network improvement initiatives: Over the next two to three years the following network improvement projects are being advanced to improve reliability and prepare the network for the impact of emerging technologies.

• Review and improvement of maintenance standards and improvement of maintenance efficiency.

• Installation of remote control switches, reclosers and sectionalisers as well as improvement of telemetry and automation in areas with higher impact on reliability to support reliability improvements.

• Implementation of an ADMS (Advanced Distribution Management System) to improve system security, enhance safety controls, improve operational outcomes and provide a pathway for increased visibility of the low voltage network.

Section 4 - Changes to the Life Cycle Asset Management Plan Changes to Asset Management Practices - Section 5


Appendix A - Load ForecastN

OR

THPO

WER

10 Y

EAR

PEA

K

LOA

D F

OR

ECA

ST

01

23

45

67

89

10N

otes

(MW

inst

anta

neou

s)20

1920

2020

2120

2220

2320

2420

2520

2620

2720

2820

29

Ken

sing

ton

65.9

66.9

67.1

68.1

69.2

70.3

71.4

72.5

73.6

74.8

75.9

Ale

xand

er S

tree

t 11k

V15

.315

.515

.215

.415

.515

.715

.816

.016

.116

.316

.5In

202

1, so

me

load

will

be

tran

sfer

red

to n

ew M

aunu

zo

ne s

ubst

atio

n

Hik

uran

gi 11

kV6.

56.

66.

76.

87.

07.1

7.3

7.4

7.6

7.7

7.9

Kam

o 11

kV11

.912

.212

.512

.813

.113

.413

.814

.114

.514

.815

.2

Ngu

ngur

u 11

kV3.

43.

53.

63.

63.

73.

83.

93.

94.

04.

14.

2

One

rahi

11kV

8.3

8.3

8.4

8.5

8.6

8.7

8.8

8.9

8.9

9.0

9.1

Paru

a B

ay 11

kV3.

43.

53.

63.

63.

73.

83.

93.

94.

04.

14.

2

Tiki

pung

a 11

kV15

.916

.116

.316

.616

.817

.117

.317

.617

.918

.118

.4

Kau

ri [In

dust

ry 1

] 33k

V7.

97.

98.

08.

18.

28.

38.

38.

48.

58.

68.

7

Bre

am B

ay (n

o TP

gen

erat

ion)

55.4

56.7

57.0

60.3

60.6

61.0

61.4

61.8

62.1

62.5

62.9

Bre

am B

ay [i

ndus

try

2] 3

3kV

4.7

4.7

4.8

4.8

4.9

4.9

5.0

5.0

5.1

5.1

5.2

Bre

am B

ay [i

ndus

try

3] 3

3kV

41.0

42.0

42.0

45.0

45.0

45.0

45.0

45.0

45.0

45.0

45.0

Exp

ecte

d sp

ot lo

ad in

crea

se

in 2

022

Bre

am B

ay 11

kV4.

74.

85.

05.

15.

35.

45.

65.

75.

96.

16.

3

Rua

kaka

11kV

7.17.

27.

47.

57.

74.

95.

05.

15.

25.

35.

4In

202

4, s

ome

load

will

be

tran

sfer

red

to n

ew W

aipu

zon

e su

bsta

tion

Wai

pu 11

kV [p

lann

ed 2

024]

3.0

3.1

3.1

3.2

3.2

3.3

Plan

ned

new

sub

stat

ion

Mau

ngat

aper

e (n

o W

PS g

ener

atio

n)

45.5

45.9

46.7

47.1

47.6

48.1

48.6

49.1

49.6

50.1

50.7

Mau

ngat

aper

e [in

dust

ry 4

] 33k

V2.

22.

22.

22.

22.

22.

22.

22.

22.

22.

22.

2

Mau

ngat

aper

e [in

dust

ry 5

] 33k

V16

.016

.016

.016

.016

.016

.016

.016

.016

.016

.016

.0

Mau

ngat

aper

e 11

kV

7.2

7.3

6.1

6.2

6.2

6.3

6.3

6.4

6.5

6.5

6.6

In 2

021,

som

e lo

ad w

ill b

e tr

ansf

erre

d to

new

Mau

nu

zone

sub

stat

ion


Load Forecast - Appendix AN

OR

THPO

WER

10 Y

EAR

PEA

K

LOA

D F

OR

ECA

ST

01

23

45

67

89

10N

otes

(MW

inst

anta

neou

s)20

1920

2020

2120

2220

2320

2420

2520

2620

2720

2820

29

Kio

rero

a 11

kV11

.512

.813

.113

.313

.613

.914

.114

.414

.715

.015

.3In

202

0, s

ome

load

will

be

tran

sfer

red

from

Wha

ngar

ei

Sou

th to

Kio

rero

a zo

ne

subs

tatio

n

Poro

ti 11

kV3.

13.

13.

13.

23.

23.

23.

23.

33.

33.

33.

4

Mau

nu 11

kV [p

lann

ed 2

019]

2.7

2.8

2.9

3.0

3.0

3.1

3.2

3.3

3.4

Plan

ned

new

sub

stat

ion

Wha

ngar

ei S

outh

11kV

12.2

11.3

10.4

10.5

10.6

10.7

10.8

10.9

11.0

11.2

11.3

In 2

020

and

2021

som

e lo

ad

will

be

tran

sfer

red

to K

iore

roa

& M

aunu

zon

e su

bsta

tions

Dar

gavi

lle12

.412

.512

.712

.913

.113

.313

.513

.713

.914

.114

.3

Dar

gavi

lle 11

kV12

.412

.512

.712

.913

.113

.313

.513

.713

.914

.114

.3

Mau

ngat

urot

o

19.1

19.4

19.7

20.0

20.4

20.7

21.1

21.4

21.8

22.2

22.6

Mau

ngat

urot

o 11

kV

2.6

2.6

2.6

2.6

2.7

2.7

2.7

2.7

2.8

2.8

2.8

Mau

ngat

urot

o [in

dust

ry 6

] 11k

V4.

54.

54.

54.

54.

54.

54.

54.

54.

54.

54.

5

Rua

wai

11kV

3.1

3.1

3.1

3.2

3.2

3.2

3.2

3.3

3.3

3.3

3.4

Kai

wak

a 11

kV2.

12.

12.

22.

22.

32.

32.

32.

42.

42.

52.

5

Man

gaw

hai 1

1kV

7.6

7.9

8.1

8.3

8.6

8.9

9.1

9.4

9.7

10.0

10.3

Mar

eret

u 11

kV2.

92.

93.

03.

03.

13.

13.

23.

23.

23.

33.

3

Net

wor

k A

DM

D (n

o ge

nera

tion

)18

7.9

190.

919

2.6

197.

619

9.8

202.

220

4.6

207.

020

9.5

212.

021

4.5

Ave

rage

incr

ease

: 1.5

% p

a

Gen

erat

ion

(at T

OS

P)-3

.6-3

.6-3

.6-3

.6-3

.6-3

.6-3

.6-3

.6-3

.6-3

.6-3

.6

Wai

rua

PS (M

aung

atap

ere

GX

P) 3

3kV

-3.6

-3.6

-3.6

-3.6

-3.6

-3.6

-3.6

-3.6

-3.6

-3.6

-3.6

Ass

umed

sta

tion

outp

ut a

t TO

SP

Trus

tpow

er P

S (B

ream

Bay

GX

P) 11

kV

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

0.0

Ass

umed

sta

tion

outp

ut a

t TO

SP

Net

wor

k A

DM

D (w

ith

gene

rati

on)

184.

318

7.3

189.

019

4.0

196.

219

8.6

201.

020

3.4

205.

920

8.4

210.

9A

vera

ge in

crea

se: 1

.5%

pa


NO

RTH

POW

ER E

DB

10

YEA

R C

APE

X P

LAN

($0

00)

con

stan

t pri

ce1

23

45

67

89

10

WS

PRO

JEC

T TI

TLE

EXPE

ND

ITU

RE

CAT

EGO

RY

FY20

FY21

FY22

FY23

FY24

FY25

FY26

FY27

FY28

FY29

6108

Tran

sfor

mer

Acq

uisi

tion

Cos

tC

onsu

mer

Con

nect

ions

1,040

1,040

1,040

1,040

1,040

1,040

1,040

1,040

1,040

1,040

6109

Tran

sfor

mer

Cre

dits

from

Upg

rade

sC

onsu

mer

Con

nect

ions

-130

-130

-130

-130

-130

-130

-130

-130

-130

-130

6463

Rip

ple

rela

y pu

rcha

ses

Con

sum

er C

onne

ctio

ns85

8585

8585

8585

8585

8561

07C

apita

l con

trib

utio

ns (C

usto

mer

)C

onsu

mer

Con

nect

ions

2,90

02,

500

2,50

02,

500

2,50

02,

500

2,50

02,

500

2,50

02,

500

610

6C

apita

l con

trib

utio

ns (N

etw

ork)

Con

sum

er C

onne

ctio

ns50

030

030

030

030

030

030

030

030

030

0To

tal

Con

sum

er C

onne

ctio

ns4,

395

3,79

53,

795

3,79

53,

795

3,79

53,

795

3,79

53,

795

3,79

561

98Po

wer

Fac

tor I

mpr

ovem

ent

Sys

tem

Gro

wth

00

108

00

011

70

010

064

49Po

wer

Fac

tor M

onito

ring

11kV

Fee

ders

Sys

tem

Gro

wth

082

00

00

00

00

6401

Min

or c

apita

l exp

endi

ture

(sys

tem

gro

wth

)S

yste

m G

row

th75

7575

7575

7575

7575

7564

30D

istr

ibut

ion

Tran

sfor

mer

& L

V F

eede

r O

ptim

isat

ion

Sys

tem

Gro

wth

5050

5050

5050

5050

5050

6461

Mau

nu Z

one

Sub

stat

ion

Sys

tem

Gro

wth

3,35

00

00

00

00

00

6479

Wai

pu Z

one

Sub

stat

ion

Sys

tem

Gro

wth

00

00

3,30

00

00

00

6480

Bre

am B

ay S

econ

d 10

MVA

Tra

nsfo

rmer

Sys

tem

Gro

wth

00

00

600

1,20

00

00

064

81B

ream

Bay

New

11kV

Fee

der

Sys

tem

Gro

wth

00

00

00

00

00

6603

One

rahi

tran

sfor

mer

upg

rade

(2x1

0MVA

)S

yste

m G

row

th15

00

00

00

00

00

6489

Ken

sing

ton-

Kam

o Th

ird C

ircui

tS

yste

m G

row

th0

00

00

01,0

00

1,00

01,9

00

065

95D

istr

ibut

ion

feed

er v

olta

ge s

uppo

rtS

yste

m G

row

th0

019

00

200

00

250

025

065

51La

nd P

urch

ases

(fut

ure

subs

tatio

ns W

aipu

, H

elen

a B

ay)

Sys

tem

Gro

wth

00

400

050

00

500

00

0

6573

EV

Cha

rgin

g S

tatio

nsS

yste

m G

row

th0

00

00

00

00

066

11M

aung

atap

ere

tran

sfor

mer

upg

rade

(ex

One

rahi

)S

yste

m G

row

th0

00

00

00

00

0

6612

Ken

sing

ton

subs

tatio

n 3

3/11

kV

tran

sfor

mer

Sys

tem

Gro

wth

020

01,5

00

2,0

00

00

00

00

****

Rua

wai

and

Pap

aroa

fibr

e ba

ckha

ul

Sys

tem

Gro

wth

01,3

00

00

00

00

00

Tota

lS

yste

m G

row

th3,

625

1,707

2,32

32,

125

4,72

51,

325

1,742

1,37

52,

025

475

6402

Min

or c

apita

l exp

endi

ture

(rel

ocat

ion)

Ass

et R

eloc

atio

ns55

5555

5555

5555

5555

5565

40R

oadi

ng w

orks

ass

et re

loca

tions

Ass

et R

eloc

atio

ns10

050

5050

5050

5050

5050

6613

Ove

rhea

d to

und

ergr

ound

con

vers

ion

Ass

et R

eloc

atio

ns0

250

250

250

250

250

250

250

250

250

6614

Gro

und

mou

ntin

g of

2/4

pol

e di

strib

utio

n tr

ansf

orm

ers

Ass

et R

eloc

atio

ns10

015

015

015

015

015

015

015

015

015

0

Tota

lA

sset

Rel

ocat

ions

255

505

505

505

505

505

505

505

505

505

Appendix B – 10 year Network Development Plan


NO

RTH

POW

ER E

DB

10

YEA

R C

APE

X P

LAN

($0

00)

con

stan

t pri

ce1

23

45

67

89

10

WS

PRO

JEC

T TI

TLE

EXPE

ND

ITU

RE

CAT

EGO

RY

FY20

FY21

FY22

FY23

FY24

FY25

FY26

FY27

FY28

FY29

6274

RTU

Rep

lace

men

ts (Z

one

subs

tatio

ns)

Ass

et R

epla

cem

ent &

Ren

ewal

150

00

00

150

150

500

5065

96R

emot

e sw

itch

RTU

and

com

ms

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

00

060

6060

600

060

6598

Rip

ple

inje

ctio

n pl

ant r

epla

cem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

010

010

010

010

00

00

00

6599

Bat

tery

ban

k an

d ba

tter

y ch

arge

r upg

rade

sA

sset

Rep

lace

men

t & R

enew

al0

500

500

500

500

5063

93Po

wer

tran

sfor

mer

refu

rbis

hmen

tA

sset

Rep

lace

men

t & R

enew

al0

00

110

00

00

125

066

01M

icro

wav

e ra

dio

term

inal

(Airm

ux) l

ink

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

100

00

00

00

00

0

6531

Ahi

kiw

i Vol

tage

regu

lato

r rep

lace

men

tA

sset

Rep

lace

men

t & R

enew

al11

00

00

00

00

00

6396

Prot

ectio

n R

elay

Upg

rade

sA

sset

Rep

lace

men

t & R

enew

al10

010

010

012

012

013

013

013

014

013

063

9733

kV C

T an

d V

T re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

080

090

090

010

00

6494

Ngu

ngur

u tr

ansf

orm

er u

pgra

de to

5M

VAA

sset

Rep

lace

men

t & R

enew

al60

00

00

00

00

00

6483

Paru

a B

ay tr

ansf

orm

er u

pgra

de to

5M

VA

Ass

et R

epla

cem

ent &

Ren

ewal

025

030

00

00

00

00

6501

Kai

wak

a 11

kV S

witc

hboa

rd re

plac

emen

t A

sset

Rep

lace

men

t & R

enew

al0

500

1,30

00

00

00

00

6502

Rua

wai

11kV

Sw

itchb

oard

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

00

500

1,30

00

00

00

065

03H

ikur

angi

11kV

Sw

itchb

oard

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

400

1,50

00

00

00

00

065

04

Wha

ngar

ei S

outh

11kV

Sw

itchb

oard

re

plac

emen

tA

sset

Rep

lace

men

t & R

enew

al1,1

00

00

00

00

00

0

6505

Ngu

ngur

u 11

kV S

witc

hboa

rd re

plac

emen

tA

sset

Rep

lace

men

t & R

enew

al0

01,0

4530

00

00

00

065

06

Poro

ti 11

kV S

witc

hboa

rd re

plac

emen

tA

sset

Rep

lace

men

t & R

enew

al0

1,00

055

00

00

00

00

6507

Tap

Cha

nger

Con

trol

ler U

pgra

des

Ass

et R

epla

cem

ent &

Ren

ewal

060

060

00

600

060

6510

Mau

ngat

aper

e 11

0/33

kV T

rans

form

er

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

00

00

00

1,925

1,925

00

6512

Ken

sing

ton

110/

33kV

Tra

nsfo

rmer

re

plac

emen

tA

sset

Rep

lace

men

t & R

enew

al0

00

00

2,69

32,

630

00

0

6522

Abb

ey S

yste

m C

omm

s U

pgra

deA

sset

Rep

lace

men

t & R

enew

al0

00

00

00

00

066

00

SC

AD

A s

yste

m h

ardw

are

and

soft

war

e re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

00

300

00

120

00

0

6529

Mau

ngat

urot

o 11

kV S

witc

hboa

rd

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

00

00

500

1,20

90

00

0

6530

Wha

ngar

ei H

ospi

tal 1

1kV

Sw

itchb

oard

re

plac

emen

tA

sset

Rep

lace

men

t & R

enew

al0

00

00

00

00

0

6597

Sec

urity

sys

tem

s re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

00

075

7575

750

065

32C

hip

Mill

Tra

nsfo

rmer

Rep

lace

men

tA

sset

Rep

lace

men

t & R

enew

al0

00

065

00

00

00

6533

Hik

uran

gi T

rans

form

er re

plac

emen

ts

Ass

et R

epla

cem

ent &

Ren

ewal

400

1,50

00

00

00

00

065

34Po

roti

Tran

sfor

mer

Rep

lace

men

tA

sset

Rep

lace

men

t & R

enew

al0

00

065

00

00

00

6605

Rua

kaka

T2

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

00

00

00

065

00

0

10 year Network Development Plan - Appendix BAppendix B – 10 year Network Development Plan


NO

RTH

POW

ER E

DB

10

YEA

R C

APE

X P

LAN

($0

00)

con

stan

t pri

ce1

23

45

67

89

10

WS

PRO

JEC

T TI

TLE

EXPE

ND

ITU

RE

CAT

EGO

RY

FY20

FY21

FY22

FY23

FY24

FY25

FY26

FY27

FY28

FY29

660

6W

hang

arei

Sou

th tr

ansf

orm

er

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

00

00

00

060

01,4

00

0

6536

Mau

ngat

urot

o Tr

ansf

orm

er R

epla

cem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

00

090

090

00

00

00

6586

Rec

lose

r rep

lace

men

tsA

sset

Rep

lace

men

t & R

enew

al0

650

650

650

650

6565

87Lo

ng &

Cra

wfo

rd G

MS

repl

acem

ent

Rel

ocat

ed to

Ass

et

Rep

lace

men

t & R

enew

al fr

om

RS

E

200

100

100

100

100

100

010

00

0

6588

Rec

lose

r con

trol

ler u

pgra

des

Ass

et R

epla

cem

ent &

Ren

ewal

00

050

00

050

010

6583

Com

mun

icat

ions

Sys

tem

Upg

rade

sR

eloc

ated

to A

sset

R

epla

cem

ent &

Ren

ewal

from

R

SE

355

010

00

00

100

00

100

6616

RT

Net

wor

k D

MR

Tie

r II u

pgra

deA

sset

Rep

lace

men

t & R

enew

al0

150

00

00

00

00

6617

Ana

logu

e U

HF

poin

t to

poin

t lin

k di

gita

l up

grad

eA

sset

Rep

lace

men

t & R

enew

al0

00

00

00

00

0

6618

Ken

sing

ton

subs

tatio

n 33

kV s

witc

hboa

rd

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

055

02,

450

00

00

00

0

6620

Dis

trib

utio

n su

bsta

tion

LV p

anel

upg

rade

sA

sset

Rep

lace

men

t & R

enew

al0

3535

3535

3535

3535

3566

21N

etw

ork

stra

tegi

c sp

ares

Ass

et R

epla

cem

ent &

Ren

ewal

00

5550

060

00

650

6622

Pole

EO

L re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al20

020

030

030

050

050

050

050

050

050

066

23S

ubtr

ansm

issi

on li

ne c

ondu

ctor

EO

L re

plac

emen

tA

sset

Rep

lace

men

t & R

enew

al50

020

020

020

020

030

030

030

050

01,0

00

6624

Dis

trib

utio

n lin

e co

nduc

tor E

OL

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

1,00

01,

200

1,20

01,4

00

1,40

01,6

00

1,30

01,7

00

1,80

01,8

00

6625

Low

vol

tage

line

con

duct

or E

OL

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

250

200

200

200

200

200

250

250

250

250

6626

Ove

rhea

d sw

itch

EOL

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

5050

6060

6070

7070

8080

6627

Low

vol

tage

ser

vice

con

nect

ion

EOL

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

5060

6070

7080

8080

8080

6628

Dis

trib

utio

n tr

ansf

orm

er E

OL

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

100

100

100

130

130

150

150

150

200

200

6629

Sub

tran

smis

sion

oil

cabl

e EO

L re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

00

1,50

00

00

01,5

00

2,50

0

6630

Dis

trib

utio

n ca

ble

EOL

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

2020

3030

3040

4050

5050

6631

Low

vol

tage

cab

le E

OL

repl

acem

ents

Ass

et R

epla

cem

ent &

Ren

ewal

2020

3030

3040

4050

5050

6632

Rip

ple

rela

y EO

L re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

2030

3040

4040

5050

50



NO

RTH

POW

ER E

DB

10

YEA

R C

APE

X P

LAN

($0

00)

con

stan

t pri

ce1

23

45

67

89

10

WS

PRO

JEC

T TI

TLE

EXPE

ND

ITU

RE

CAT

EGO

RY

FY20

FY21

FY22

FY23

FY24

FY25

FY26

FY27

FY28

FY29

6633

33kV

Circ

uit B

reak

er E

OL

repl

acem

ent

Ass

et R

epla

cem

ent &

Ren

ewal

00

00

100

00

011

00

6634

Zone

sub

stat

ion

build

ings

EO

L up

grad

esA

sset

Rep

lace

men

t & R

enew

al0

400

00

043

00

045

00

6635

Zone

sub

stat

ion

outd

oor s

witc

h EO

L re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

00

500

00

600

0

6636

Zone

sub

stat

ion

outd

oor s

truc

ture

EO

L re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

00

100

00

011

00

0

6637

Cap

acito

r ban

k EO

L re

plac

emen

tsA

sset

Rep

lace

men

t & R

enew

al0

015

00

200

025

066

38M

inor

CA

PEX

(ass

et re

plac

emen

t & re

new

al)

Ass

et R

epla

cem

ent &

Ren

ewal

7575

7575

7575

7575

7575

Sub

tota

l (Pr

ojec

ts)

5,78

08,

505

9,01

57,

775

6,11

58,

172

8,22

07,

175

7,58

57,

195

950

0C

orre

ctiv

e C

APE

X -

BAT

T B

atte

ry S

yste

ms

Ass

et R

epla

cem

ent &

Ren

ewal

55

55

55

55

55

9501

Cor

rect

ive

CA

PEX

- C

ON

D D

istr

ibut

ion

Con

duct

or

Ass

et R

epla

cem

ent &

Ren

ewal

350

350

350

350

350

350

350

350

350

350

9502

Cor

rect

ive

CA

PEX

- D

EA

R D

istr

ibut

ion

Ear

thin

gA

sset

Rep

lace

men

t & R

enew

al20

020

020

020

020

020

020

020

020

020

0

9503

Cor

rect

ive

CA

PEX

- G

MS

U G

roun

d m

ount

ed d

istr

ibut

ion

subs

tatio

nA

sset

Rep

lace

men

t & R

enew

al20

020

020

020

020

020

020

020

020

020

0

950

4C

orre

ctiv

e C

APE

X -

MA

NY

Ass

et R

epla

cem

ent &

Ren

ewal

2121

2121

2121

2121

2121

950

6C

orre

ctiv

e C

APE

X -

OH

LN D

istr

ibut

ion

over

head

line

Ass

et R

epla

cem

ent &

Ren

ewal

1,570

1,570

1,570

1,570

1,650

1,650

1,650

1,650

1,650

1,650

9507

Cor

rect

ive

CA

PEX

- O

HS

W D

istr

ibut

ion

over

head

sw

itch

Ass

et R

epla

cem

ent &

Ren

ewal

100

100

100

100

100

100

100

100

100

100

9508

Cor

rect

ive

CA

PEX

- PI

LL D

istr

ibut

ion

Pilla

rsA

sset

Rep

lace

men

t & R

enew

al15

015

015

015

015

015

015

015

015

015

095

09C

orre

ctiv

e C

APE

X -

POLE

Pol

esA

sset

Rep

lace

men

t & R

enew

al35

035

035

035

035

035

035

035

035

035

095

10C

orre

ctiv

e C

APE

X -

PRO

T Pr

otec

tion

rela

ysA

sset

Rep

lace

men

t & R

enew

al5

55

55

55

55

595

11C

orre

ctiv

e C

APE

X -

RIP

P R

ippl

e pl

ant

Ass

et R

epla

cem

ent &

Ren

ewal

55

55

55

55

55

9512

Cor

rect

ive

CA

PEX

- U

CA

B D

istr

ibut

ion

cabl

esA

sset

Rep

lace

men

t & R

enew

al20

2020

2020

2020

2020

20

9513

Cor

rect

ive

CA

PEX

- X

AR

M D

istr

ibut

ion

cros

sarm

Ass

et R

epla

cem

ent &

Ren

ewal

1,30

01,3

00

1,30

01,3

00

1,30

01,4

00

1,40

01,4

00

1,40

01,4

00

9514

Cor

rect

ive

CA

PEX

- ZS

BG

Zon

e su

bsta

tion

build

ings

Ass

et R

epla

cem

ent &

Ren

ewal

55

55

55

55

55

9515

Cor

rect

ive

CA

PEX

- ZS

TX

Zon

e su

bsta

tion

tran

sfor

mer

sA

sset

Rep

lace

men

t & R

enew

al15

1515

1515

1515

1515

15

9516

Cor

rect

ive

CA

PEX

- C

APA

Cap

acito

r ban

ksA

sset

Rep

lace

men

t & R

enew

al2

22

22

22

22

2



NO

RTH

POW

ER E

DB

10

YEA

R C

APE

X P

LAN

($0

00)

con

stan

t pri

ce1

23

45

67

89

10

WS

PRO

JEC

T TI

TLE

EXPE

ND

ITU

RE

CAT

EGO

RY

FY20

FY21

FY22

FY23

FY24

FY25

FY26

FY27

FY28

FY29

9517

Cor

rect

ive

CA

PEX

- C

OM

M

Com

mun

icat

ion

netw

ork

Ass

et R

epla

cem

ent &

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1010

1010

1010

1010

1010

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Cor

rect

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CA

PEX

- O

ILC

Dis

trib

utio

n oi

l ca

bles

Ass

et R

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cem

ent &

Ren

ewal

22

55

55

55

55

9519

Cor

rect

ive

CA

PEX

- A

REG

Vol

tage

re

gula

tors

Ass

et R

epla

cem

ent &

Ren

ewal

1515

1515

1515

1515

1515

9520

Cor

rect

ive

CA

PEX

- S

CA

B S

ubtr

ansm

isio

n ca

bles

Ass

et R

epla

cem

ent &

Ren

ewal

55

55

55

55

55

9521

Cor

rect

ive

CA

PEX

- ZS

EA

Zon

e su

bsta

tion

eart

hing

Ass

et R

epla

cem

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Ren

ewal

55

55

55

55

55

9523

Cor

rect

ive

CA

PEX

- ZS

UB

Zon

e su

bsta

tion

Ass

et R

epla

cem

ent &

Ren

ewal

55

55

55

55

55

9524

Cor

rect

ive

CA

PEX

- S

CD

A S

CA

DA

sys

tem

Ass

et R

epla

cem

ent &

Ren

ewal

66

66

66

66

66

9525

Cor

rect

ive

CA

PEX

- O

STR

Zon

e su

bsta

tion

outd

oor s

truc

ture

Ass

et R

epla

cem

ent &

Ren

ewal

1010

1010

1010

1010

1010

Sub

tota

l (Fo

llow

up

mai

nten

ance

)A

sset

Rep

lace

men

t &

Rene

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4,35

64,

356

4,35

94,

359

4,43

94,

539

4,53

94,

539

4,53

94,

539

Tota

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Rep

lace

men

t &

Rene

wal

10,13

612

,861

13,3

7412

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10,5

5412

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12,7

5911

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12,12

411

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6348

New

Rec

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rsR

elia

bilit

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afet

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viro

nmen

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450

050

00

550

064

72W

hang

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Sou

th 3

3kV

T -

Sta

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Rel

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lity,

Saf

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Envi

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ent

300

00

00

00

00

064

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Wha

ngar

ei C

ity a

dditi

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11kV

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U’s

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elia

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t0

050

00

056

00

065

81Pr

ovis

ion

for fi

bre

Rel

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lity,

Saf

ety,

Envi

ronm

ent

6060

5050

5050

5050

5050

6370

Zone

Sub

stat

ions

Ris

k M

itiga

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Rel

iabi

lity,

Saf

ety,

Envi

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134

150

00

00

00

00

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Zone

Sub

stat

ions

Sec

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Impr

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Saf

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6575

00

750

00

00

640

4C

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s fo

r rem

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cont

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f mot

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hes

Rel

iabi

lity,

Saf

ety,

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ent

00

00

00

00

00

6425

11kV

feed

er b

acks

topp

ing

impr

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lity,

Saf

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ronm

ent

00

085

00

900

010

066

07D

istr

ibut

ion

feed

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uto-

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gR

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bilit

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viro

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00

00

00

00

064

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SU

B M

DI M

eter

s (C

BD

)R

elia

bilit

y, S

afet

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065

00

00

00

00

6435

Min

or c

apita

l exp

endi

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(rel

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lity,

safe

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envi

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lity,

Saf

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100

100

100

100

100

100

100

100

100

6447

AC

/DC

Pan

el U

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Rel

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lity,

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00

00

00

00

00

6497

Wha

kapa

ra F

eede

r Exp

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Lin

e to

H

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Saf

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ronm

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030

00

00

00

00

0

6519

Faul

t Pas

sage

Indi

cato

rsR

elia

bilit

y, S

afet

y, En

viro

nmen

t0

00

00

00

00

065

37M

aung

atur

oto

33kV

Circ

uit S

epar

atio

nR

elia

bilit

y, S

afet

y, En

viro

nmen

t0

00

00

00

00

065

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unic

atio

ns N

etw

ork

Sec

urity

Im

prov

emen

tsR

elia

bilit

y, S

afet

y, En

viro

nmen

t0

050

00

060

00

60



NO

RTH

POW

ER E

DB

10

YEA

R C

APE

X P

LAN

($0

00)

con

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t pri

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23

45

67

89

10

WS

PRO

JEC

T TI

TLE

EXPE

ND

ITU

RE

CAT

EGO

RY

FY20

FY21

FY22

FY23

FY24

FY25

FY26

FY27

FY28

FY29

6565

Zone

Sub

stat

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Neu

tral

Ear

thin

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esis

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Rel

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100

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105

00

0

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Bus

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rc F

lash

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lity,

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00

00

00

00

6591

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A c

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s tr

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reR

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bilit

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t0

00

00

00

00

065

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emot

e st

atio

n S

CA

DA

mon

itorin

gR

elia

bilit

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00

00

00

00

00

6639

SM

AR

T D

istr

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syst

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mon

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bilit

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viro

nmen

t0

5010

010

010

00

00

00

****

Poro

ti Tr

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2 (n

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00

00

00

00

060

066

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form

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2 (n

ew p

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Rel

iabi

lity,

Saf

ety,

Envi

ronm

ent

00

600

00

00

00

066

41K

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Tran

sfor

mer

T2

(new

pur

chas

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elia

bilit

y, S

afet

y, En

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nmen

t0

00

700

00

00

00

6642

Ngu

ngur

u Tr

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orm

er T

2 (e

x H

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)R

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bilit

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afet

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t0

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300

00

00

00

6643

Mar

eret

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00

060

00

00

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Relia

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afet

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Envi

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1,109

970

980

1,43

537

575

046

120

515

091

0

6443

Net

wor

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rate

gic

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00

00

400

00

065

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esea

rch

and

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men

t (co

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Ass

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3030

3030

3050

5050

8050

6569

Aer

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mag

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(GIS

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Ass

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00

400

00

500

050

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Engi

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hard

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Non

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sset

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550

00

5565

74U

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Ass

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00

00

00

00

160

6577

Uni

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roje

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olla

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Non

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sset

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00

00

00

00

065

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Dev

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t (ne

w

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Non

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k A

sset

s50

5050

5060

7080

8590

100

6571

AM

S (W

AS

P re

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so

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050

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00

00

00

6525

AD

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Man

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1,045

00

00

00

0

6644

Min

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(non

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sets

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Ass

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2525

2525

2525

2525

525

6645

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Ass

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2,41

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1,190

605

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240

205

160

191

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Tota

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21,9

3122

,152

22,16

720

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20,4

6919

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19,4

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18,7

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--

--

--

--

--

-17

Oth

er re

liabi

lity,

safe

ty a

nd e

nviro

nmen

t40

0 30

9 43

3 54

16

5 14

0 57

18

1 59

61

62

18

Tota

l rel

iabi

lity,

safe

ty a

nd e

nviro

nmen

t2,

193

1,10

9 1,

024

1,05

5 1,

575

420

856

537

243

182

1,12

5 19

Expe

nditu

re o

n ne

twor

k as

sets

18,2

06

19,5

20

20,9

30

22,5

73

21,9

44

22,3

40

21,7

95

22,4

35

20,9

03

22,5

39

21,5

31

20Ex

pend

iture

on

non-

netw

ork

asse

ts60

1 2,

411

2,44

1 1,

281

664

577

274

239

190

231

346

21Ex

pend

iture

on

asse

ts18

,807

21

,931

23

,371

23

,854

22

,608

22

,917

22

,069

22

,674

21

,093

22

,770

21

,877

22 23pl

usCo

st o

f fin

anci

ng99

10

9 10

8 11

3 11

0 11

6 10

3 10

6 99

10

8 10

2 24

less

Valu

e of

cap

ital c

ontr

ibut

ions

2,50

0 2,

900

2,63

7 2,

690

2,74

4 2,

799

2,85

5 2,

912

2,97

0 3,

030

3,09

0 25

plus

Valu

e of

ves

ted

asse

ts-

--

--

--

--

--

26 27Ca

pita

l exp

endi

ture

fore

cast

16,4

06

19,1

40

20,8

42

21,2

77

19,9

74

20,2

34

19,3

17

19,8

68

18,2

22

19,8

48

18,8

89

28 29As

sets

com

miss

ione

d15

,002

17

,509

19

,074

19

,470

18

,276

18

,508

17

,677

18

,182

16

,673

18

,161

17

,284

30Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

CY+6

CY+7

CY+8

CY+9

CY+1

0

31fo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

431

Mar

25

31 M

ar 2

631

Mar

27

31 M

ar 2

831

Mar

29

32$0

00 (i

n co

nsta

nt p

rices

)33

Con

sum

er c

onne

ctio

n3,

795

4,39

5 3,

795

3,79

5 3,

795

3,79

5 3,

795

3,79

5 3,

795

3,79

5 3,

795

34 S

yste

m g

row

th3,

613

3,62

5 1,

707

2,32

3 2,

125

4,72

5 1,

325

1,74

2 1,

375

2,02

5 47

5 35

Ass

et re

plac

emen

t and

rene

wal

8,40

1 10

,136

12

,861

13

,374

12

,134

10

,554

12

,711

12

,759

11

,714

12

,124

11

,734

36

Ass

et re

loca

tions

205

255

505

505

505

505

505

505

505

505

505

37Re

liabi

lity,

safe

ty a

nd e

nviro

nmen

t:38

Qua

lity

of su

pply

1,79

3 80

0 56

0 93

0 1,

285

250

700

306

155

100

860

39Le

gisla

tive

and

regu

lato

ry-

--

--

--

--

--

40O

ther

relia

bilit

y, sa

fety

and

env

ironm

ent

400

309

410

50

150

125

50

155

50

50

50

41To

tal r

elia

bilit

y, sa

fety

and

env

ironm

ent

2,19

3 1,

109

970

980

1,43

5 37

5 75

0 46

1 20

5 15

0 91

0 42

Expe

nditu

re o

n ne

twor

k as

sets

18,2

07

19,5

20

19,8

38

20,9

77

19,9

94

19,9

54

19,0

86

19,2

62

17,5

94

18,5

99

17,4

19

43Ex

pend

iture

on

non-

netw

ork

asse

ts60

1 2,

411

2,31

4 1,

190

605

515

240

205

160

191

280

44Ex

pend

iture

on

asse

ts18

,808

21

,931

22

,152

22

,167

20

,599

20

,469

19

,326

19

,467

17

,754

18

,790

17

,699

45 46Su

bcom

pone

nts o

f exp

endi

ture

on

asse

ts (w

here

kno

wn)

47En

ergy

effi

cien

cy a

nd d

eman

d sid

e m

anag

emen

t, re

duct

ion

of e

nerg

y lo

sses

48O

verh

ead

to u

nder

grou

nd c

onve

rsio

n49

Rese

arch

and

dev

elop

men

t50

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of fo

reca

st e

xpen

ditu

re o

n as

sets

for t

he c

urre

nt d

isclo

sure

yea

r and

a 1

0 ye

ar p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP.

The

fore

cast

is to

be

expr

esse

d in

bot

h co

nsta

nt p

rice

and

nom

inal

dol

lar t

erm

s. A

lso re

quire

d is

a fo

reca

st

of th

e va

lue

of c

omm

issio

ned

asse

ts (i

.e.,

the

valu

e of

RAB

add

ition

s)

EDBs

mus

t pro

vide

exp

lana

tory

com

men

t on

the

diffe

renc

e be

twee

n co

nsta

nt p

rice

and

nom

inal

dol

lar f

orec

asts

of e

xpen

ditu

re o

n as

sets

in S

ched

ule

14a

(Man

dato

ry E

xpla

nato

ry N

otes

).Th

is in

form

atio

n is

not p

art o

f aud

ited

disc

losu

re in

form

atio

n.

Appendix C



Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)5

S11a

.Cap

ex F

orec

ast

Com

pany

Nam

eAM

P Pl

anni

ng P

erio

d

SCHE

DULE

11a

: REP

ORT

ON

FO

RECA

ST C

APIT

AL E

XPEN

DITU

RE

sch

ref

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of fo

reca

st e

xpen

ditu

re o

n as

sets

for t

he c

urre

nt d

isclo

sure

yea

r and

a 1

0 ye

ar p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP.

The

fore

cast

is to

be

expr

esse

d in

bot

h co

nsta

nt p

rice

and

nom

inal

dol

lar t

erm

s. A

lso re

quire

d is

a fo

reca

st

of th

e va

lue

of c

omm

issio

ned

asse

ts (i

.e.,

the

valu

e of

RAB

add

ition

s)

EDBs

mus

t pro

vide

exp

lana

tory

com

men

t on

the

diffe

renc

e be

twee

n co

nsta

nt p

rice

and

nom

inal

dol

lar f

orec

asts

of e

xpen

ditu

re o

n as

sets

in S

ched

ule

14a

(Man

dato

ry E

xpla

nato

ry N

otes

).Th

is in

form

atio

n is

not p

art o

f aud

ited

disc

losu

re in

form

atio

n.

51Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

CY+6

CY+7

CY+8

CY+9

CY+1

052

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

31 M

ar 2

531

Mar

26

31 M

ar 2

731

Mar

28

31 M

ar 2

953

Diffe

renc

e be

twee

n no

min

al a

nd c

onst

ant p

rice

fore

cast

s$0

00

54 C

onsu

mer

con

nect

ion

--

209

289

370

454

539

625

714

804

896

55 S

yste

m g

row

th-

-94

17

7 20

7 56

5 18

8 28

7 25

9 42

9 11

2 56

Ass

et re

plac

emen

t and

rene

wal

(1)

-70

7 1,

017

1,18

4 1,

262

1,80

4 2,

102

2,20

3 2,

568

2,77

0 57

Ass

et re

loca

tions

--

28

38

49

60

72

83

95

107

119

58Re

liabi

lity,

safe

ty a

nd e

nviro

nmen

t:59

Qua

lity

of su

pply

--

31

71

125

30

99

50

29

21

203

60Le

gisla

tive

and

regu

lato

ry-

--

--

--

--

--

61O

ther

relia

bilit

y, sa

fety

and

env

ironm

ent

--

23

4 15

15

7

26

9 11

12

62

Tota

l rel

iabi

lity,

safe

ty a

nd e

nviro

nmen

t-

-54

75

14

0 45

10

6 76

38

32

21

5 63

Expe

nditu

re o

n ne

twor

k as

sets

(1)

-1,

092

1,59

6 1,

950

2,38

6 2,

709

3,17

3 3,

309

3,94

0 4,

112

64Ex

pend

iture

on

non-

netw

ork

asse

ts-

-12

7 91

59

62

34

34

30

40

66

65

Expe

nditu

re o

n as

sets

(1)

-1,

219

1,68

7 2,

009

2,44

8 2,

743

3,20

7 3,

339

3,98

0 4,

178

66 67CY

+1CY

+2CY

+3CY

+4CY

+5

6811

a(ii)

: Con

sum

er C

onne

ctio

nfo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

4

69Co

nsum

er ty

pes d

efin

ed b

y ED

B*$0

00 (i

n co

nsta

nt p

rices

)

70Tr

ansf

orm

er A

cqui

sitio

n Co

st1,

040

1,04

0 1,

040

1,04

0 1,

040

1,04

0 71

Tran

sfor

mer

Cre

dits

from

Upg

rade

s(1

30)

(130

)(1

30)

(130

)(1

30)

(130

)72

Ripp

le re

lay

purc

hase

s85

85

85

85

85

85

73

Capi

tal c

ontr

ibut

ions

(Cus

tom

er)

2,50

0 2,

900

2,50

0 2,

500

2,50

0 2,

500

74Ca

pita

l con

trib

utio

ns (N

etw

ork)

300

500

300

300

300

300

75

*inc

lude

add

ition

al ro

ws i

f nee

ded

76Co

nsum

er c

onne

ctio

n ex

pend

iture

3,79

5 4,

395

3,79

5 3,

795

3,79

5 3,

795

77le

ssCa

pita

l con

trib

utio

ns fu

ndin

g co

nsum

er c

onne

ctio

n2,

500

2,90

0 2,

500

2,50

0 2,

500

2,50

0 78

Cons

umer

con

nect

ion

less

cap

ital c

ontr

ibut

ions

1,29

5 1,

495

1,29

5 1,

295

1,29

5 1,

295

7911

a(iii

): Sy

stem

Gro

wth

80Su

btra

nsm

issio

n-

--

--

-81

Zone

subs

tatio

ns2,

888

3,50

0 28

2 1,

900

2,00

0 4,

400

82Di

strib

utio

n an

d LV

line

s15

5 75

75

18

3 75

75

83

Dist

ribut

ion

and

LV c

able

s35

0 -

--

--

84Di

strib

utio

n su

bsta

tions

and

tran

sfor

mer

s50

50

50

50

50

50

85

Dist

ribut

ion

switc

hgea

r-

--

--

-86

Oth

er n

etw

ork

asse

ts17

0 -

1,30

0 19

0 -

200

87Sy

stem

gro

wth

exp

endi

ture

3,61

3 3,

625

1,70

7 2,

323

2,12

5 4,

725

88le

ssCa

pita

l con

trib

utio

ns fu

ndin

g sy

stem

gro

wth

--

--

--

89Sy

stem

gro

wth

less

cap

ital c

ontr

ibut

ions

3,61

3 3,

625

1,70

7 2,

323

2,12

5 4,

725

90 91Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

92fo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

4

9311

a(iv

): As

set R

epla

cem

ent a

nd R

enew

al$0

00 (i

n co

nsta

nt p

rices

)

Curr

ent Y

ear C

Y

Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)6

S11a

.Cap

ex F

orec

ast

Com

pany

Nam

eAM

P Pl

anni

ng P

erio

d

SCHE

DULE

11a

: REP

ORT

ON

FO

RECA

ST C

APIT

AL E

XPEN

DITU

RE

sch

ref

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of fo

reca

st e

xpen

ditu

re o

n as

sets

for t

he c

urre

nt d

isclo

sure

yea

r and

a 1

0 ye

ar p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP.

The

fore

cast

is to

be

expr

esse

d in

bot

h co

nsta

nt p

rice

and

nom

inal

dol

lar t

erm

s. A

lso re

quire

d is

a fo

reca

st

of th

e va

lue

of c

omm

issio

ned

asse

ts (i

.e.,

the

valu

e of

RAB

add

ition

s)

EDBs

mus

t pro

vide

exp

lana

tory

com

men

t on

the

diffe

renc

e be

twee

n co

nsta

nt p

rice

and

nom

inal

dol

lar f

orec

asts

of e

xpen

ditu

re o

n as

sets

in S

ched

ule

14a

(Man

dato

ry E

xpla

nato

ry N

otes

).Th

is in

form

atio

n is

not p

art o

f aud

ited

disc

losu

re in

form

atio

n.

94Su

btra

nsm

issio

n50

5 50

5 20

5 20

5 1,

705

205

95Zo

ne su

bsta

tions

1,21

5 2,

805

5,98

5 6,

410

3,07

5 3,

105

96Di

strib

utio

n an

d LV

line

s5,

018

5,16

8 5,

328

5,44

3 5,

638

5,91

8 97

Dist

ribut

ion

and

LV c

able

s19

2 21

2 21

2 23

5 23

5 23

5 98

Dist

ribut

ion

subs

tatio

ns a

nd tr

ansf

orm

ers

615

425

315

315

345

345

99Di

strib

utio

n sw

itchg

ear

485

550

550

495

610

495

100

Oth

er n

etw

ork

asse

ts37

1 47

1 26

6 27

1 52

6 25

1 10

1As

set r

epla

cem

ent a

nd re

new

al e

xpen

ditu

re8,

401

10,1

36

12,8

61

13,3

74

12,1

34

10,5

54

102

less

Capi

tal c

ontr

ibut

ions

fund

ing

asse

t rep

lace

men

t and

rene

wal

--

--

--

103

Asse

t rep

lace

men

t and

rene

wal

less

cap

ital c

ontr

ibut

ions

8,40

1 10

,136

12

,861

13

,374

12

,134

10

,554

104

105

Curr

ent Y

ear C

YCY

+1CY

+2CY

+3CY

+4CY

+5

106

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

107

11a(

v): A

sset

Rel

ocat

ions

108

Proj

ect o

r pro

gram

me*

$000

(in

cons

tant

pric

es)

109

Min

or c

apita

l exp

endi

ture

(rel

ocat

ion)

55

55

55

55

55

55

110

Road

ing

wor

ks a

sset

relo

catio

ns50

10

0 50

50

50

50

11

1O

verh

ead

to u

nder

grou

nd c

onve

rsio

n-

-25

0 25

0 25

0 25

0 11

2Gr

ound

mou

ntin

g of

2/4

pol

e di

strib

utio

n tr

ansf

orm

ers

100

100

150

150

150

150

114

*inc

lude

add

ition

al ro

ws i

f nee

ded

115

All o

ther

pro

ject

or p

rogr

amm

es -

asse

t rel

ocat

ions

--

--

--

116

Asse

t rel

ocat

ions

exp

endi

ture

205

255

505

505

505

505

117

less

Capi

tal c

ontr

ibut

ions

fund

ing

asse

t rel

ocat

ions

--

--

--

118

Asse

t rel

ocat

ions

less

cap

ital c

ontr

ibut

ions

205

255

505

505

505

505

119

120

Curr

ent Y

ear C

YCY

+1CY

+2CY

+3CY

+4CY

+5

121

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

122

11a(

vi):

Qua

lity

of S

uppl

y12

3Pr

ojec

t or p

rogr

amm

e*$0

00 (i

n co

nsta

nt p

rices

)12

4N

ew R

eclo

sers

45

-45

-

-50

12

5W

hang

arei

Sou

th 3

3kV

T - S

tage

270

0 30

0 -

--

-12

6W

hang

arei

City

add

ition

al 1

1kV

RMU

's 50

-

-50

-

-Co

mm

s for

rem

ote

cont

rol o

f mot

orise

d sw

itche

s17

5 -

--

--

11kV

feed

er b

acks

topp

ing

impr

ovem

ents

--

--

85

-Di

strib

utio

n fe

eder

aut

o-re

clos

ing

25

--

--

-DS

UB

MDI

Met

ers (

CBD)

65

100

65

--

-M

inor

cap

ital e

xpen

ditu

re (r

elia

bilit

y, sa

fety

, env

ironm

ent)

100

100

100

100

100

100

AC/D

C Pa

nel U

pgra

des

50

--

--

-W

haka

para

Fee

der E

xpre

ss L

ine

to H

ikur

angi

250

-30

0 -

--

Faul

t Pas

sage

Indi

cato

rs75

-

--

--

Mau

ngat

urot

o 33

kV C

ircui

t Sep

arat

ion

258

--

--

-Co

mm

unic

atio

ns N

etw

ork

Secu

rity

Impr

ovem

ents

--

-50

-

-Re

mot

e st

atio

n SC

ADA

mon

itorin

g-

300

--

--

SMAR

T Di

strib

utio

n sy

stem

(loa

d m

onito

ring)

--

50

100

100

100

Poro

ti Tr

ansf

orm

er T

2 (n

ew p

urch

ase)

--

--

--


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)7

S11a

.Cap

ex F

orec

ast

Com

pany

Nam

eAM

P Pl

anni

ng P

erio

d

SCHE

DULE

11a

: REP

ORT

ON

FO

RECA

ST C

APIT

AL E

XPEN

DITU

RE

sch

ref

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of fo

reca

st e

xpen

ditu

re o

n as

sets

for t

he c

urre

nt d

isclo

sure

yea

r and

a 1

0 ye

ar p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP.

The

fore

cast

is to

be

expr

esse

d in

bot

h co

nsta

nt p

rice

and

nom

inal

dol

lar t

erm

s. A

lso re

quire

d is

a fo

reca

st

of th

e va

lue

of c

omm

issio

ned

asse

ts (i

.e.,

the

valu

e of

RAB

add

ition

s)

EDBs

mus

t pro

vide

exp

lana

tory

com

men

t on

the

diffe

renc

e be

twee

n co

nsta

nt p

rice

and

nom

inal

dol

lar f

orec

asts

of e

xpen

ditu

re o

n as

sets

in S

ched

ule

14a

(Man

dato

ry E

xpla

nato

ry N

otes

).Th

is in

form

atio

n is

not p

art o

f aud

ited

disc

losu

re in

form

atio

n.

Ruaw

ai T

rans

form

er T

2 (n

ew p

urch

ase)

--

-60

0 -

-12

7Ka

iwak

a Tr

ansf

orm

er T

2 (n

ew p

urch

ase)

--

--

700

-12

8N

gung

uru

Tran

sfor

mer

T2

(ex

Hiku

rang

i)-

--

30

300

-12

9*i

nclu

de a

dditi

onal

row

s if n

eede

d13

0Al

l oth

er p

roje

cts o

r pro

gram

mes

- qu

ality

of s

uppl

y-

--

--

-13

1Q

ualit

y of

supp

ly e

xpen

ditu

re1,

793

800

560

930

1,28

5 25

0 13

2le

ssCa

pita

l con

trib

utio

ns fu

ndin

g qu

ality

of s

uppl

y-

--

--

-13

3Q

ualit

y of

supp

ly le

ss c

apita

l con

trib

utio

ns1,

793

800

560

930

1,28

5 25

0

134

135

Curr

ent Y

ear C

YCY

+1CY

+2CY

+3CY

+4CY

+5

136

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

137

11a(

vii):

Leg

isla

tive

and

Regu

lato

ry13

8Pr

ojec

t or p

rogr

amm

e*$0

00 (i

n co

nsta

nt p

rices

)13

914

314

4*i

nclu

de a

dditi

onal

row

s if n

eede

d14

5Al

l oth

er p

roje

cts o

r pro

gram

mes

- le

gisla

tive

and

regu

lato

ry14

6Le

gisl

ativ

e an

d re

gula

tory

exp

endi

ture

--

--

--

147

less

Capi

tal c

ontr

ibut

ions

fund

ing

legi

slativ

e an

d re

gula

tory

148

Legi

slat

ive

and

regu

lato

ry le

ss c

apita

l con

trib

utio

ns-

--

--

-

149

150

Curr

ent Y

ear C

YCY

+1CY

+2CY

+3CY

+4CY

+5

151

11a(

viii)

: Oth

er R

elia

bilit

y, S

afet

y an

d En

viro

nmen

tfo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

4

152

Proj

ect o

r pro

gram

me*

$000

(in

cons

tant

pric

es)

153

Prov

ision

for f

ibre

60

60

60

50

50

50

154

Zone

Sub

stat

ions

Risk

Miti

gatio

n10

0 13

4 15

0 -

--

155

Zone

Sub

stat

ions

Sec

urity

Impr

ovem

ent

65

65

75

--

75

156

Zone

Sub

stat

ion

Neu

tral

Ear

thin

g Re

sisto

rs12

5 -

125

-10

0 -

157

Busb

ar A

rc F

lash

Pro

tect

ion

50

50

--

--

158

*inc

lude

add

ition

al ro

ws i

f nee

ded

159

All o

ther

pro

ject

s or p

rogr

amm

es -

othe

r rel

iabi

lity,

safe

ty a

nd e

nviro

nmen

t-

--

--

-16

0O

ther

relia

bilit

y, sa

fety

and

env

ironm

ent e

xpen

ditu

re40

0 30

9 41

0 50

15

0 12

5 16

1le

ssCa

pita

l con

trib

utio

ns fu

ndin

g ot

her r

elia

bilit

y, sa

fety

and

env

ironm

ent

--

--

--

162

Oth

er re

liabi

lity,

safe

ty a

nd e

nviro

nmen

t les

s cap

ital c

ontr

ibut

ions

400

309

410

50

150

125

163

164

Curr

ent Y

ear C

YCY

+1CY

+2CY

+3CY

+4CY

+5

165

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

166

11a(

ix):

Non

-Net

wor

k As

sets

167

Rout

ine

expe

nditu

re16

8Pr

ojec

t or p

rogr

amm

e*$0

00 (i

n co

nsta

nt p

rices

)16

917

317

4*i

nclu

de a

dditi

onal

row

s if n

eede

d17

5Al

l oth

er p

roje

cts o

r pro

gram

mes

- ro

utin

e ex

pend

iture


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)8

S11a

.Cap

ex F

orec

ast

Com

pany

Nam

eAM

P Pl

anni

ng P

erio

d

SCHE

DULE

11a

: REP

ORT

ON

FO

RECA

ST C

APIT

AL E

XPEN

DITU

RE

sch

ref

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of fo

reca

st e

xpen

ditu

re o

n as

sets

for t

he c

urre

nt d

isclo

sure

yea

r and

a 1

0 ye

ar p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP.

The

fore

cast

is to

be

expr

esse

d in

bot

h co

nsta

nt p

rice

and

nom

inal

dol

lar t

erm

s. A

lso re

quire

d is

a fo

reca

st

of th

e va

lue

of c

omm

issio

ned

asse

ts (i

.e.,

the

valu

e of

RAB

add

ition

s)

EDBs

mus

t pro

vide

exp

lana

tory

com

men

t on

the

diffe

renc

e be

twee

n co

nsta

nt p

rice

and

nom

inal

dol

lar f

orec

asts

of e

xpen

ditu

re o

n as

sets

in S

ched

ule

14a

(Man

dato

ry E

xpla

nato

ry N

otes

).Th

is in

form

atio

n is

not p

art o

f aud

ited

disc

losu

re in

form

atio

n.

176

Rout

ine

expe

nditu

re-

--

--

-

177

Atyp

ical

exp

endi

ture

178

Proj

ect o

r pro

gram

me*

179

Net

wor

k st

rate

gic

spar

e st

ore

50

--

--

-Re

sear

ch a

nd D

evel

opm

ent (

com

pone

nt te

stin

g)30

30

30

30

30

30

Ae

rial I

mag

ery

(GIS

)-

--

40

--

Engi

neer

ing

hard

war

e/So

ftw

are

--

50

--

-U

AV A

sset

Insp

ectio

n Pl

atfo

rm30

-

--

--

Uni

vers

ity P

roje

ct C

olla

bora

tion

16

--

--

-Re

sear

ch a

nd D

evel

opm

ent (

new

tech

nolo

gy)

50

50

50

50

50

60

180

AMS

(WAS

P re

plac

emen

t and

CBR

M so

ftw

are)

300

-40

0 -

500

400

181

ADM

S (A

dvan

ced

Dist

ribut

ion

Man

agem

ent S

yste

m)

50

2,20

6 1,

659

1,04

5 -

-18

2M

inor

cap

ital e

xpen

ditu

re (n

on-n

etw

ork

asse

ts)

25

25

25

25

25

25

183

Low

vol

tage

net

wor

k op

erat

iona

l man

agem

ent s

yste

m

50

100

100

--

-18

4*i

nclu

de a

dditi

onal

row

s if n

eede

d18

5Al

l oth

er p

roje

cts o

r pro

gram

mes

- at

ypic

al e

xpen

ditu

re-

--

--

-18

6At

ypic

al e

xpen

ditu

re60

1 2,

411

2,31

4 1,

190

605

515

187

188

Expe

nditu

re o

n no

n-ne

twor

k as

sets

601

2,41

1 2,

314

1,19

0 60

5 51

5


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)9

S11b

.Ope

x Fo

reca

st

Com

pany

Nam

eAM

P Pl

anni

ng P

erio

d

SCHE

DULE

11b

: REP

ORT

ON

FO

RECA

ST O

PERA

TIO

NAL

EXP

ENDI

TURE

sch

ref

7Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

CY+6

CY+7

CY+8

CY+9

CY+1

08

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

31 M

ar 2

531

Mar

26

31 M

ar 2

731

Mar

28

31 M

ar 2

9

9O

pera

tiona

l Exp

endi

ture

For

ecas

t$0

00 (i

n no

min

al d

olla

rs)

10Se

rvic

e in

terr

uptio

ns a

nd e

mer

genc

ies

2,07

0 2,

066

2,10

8 2,

150

2,19

3 2,

237

2,28

1 2,

327

2,37

3 2,

421

2,46

9 11

Vege

tatio

n m

anag

emen

t2,

300

2,36

9 2,

416

2,46

5 2,

514

2,56

4 2,

616

2,66

8 2,

721

2,77

6 2,

831

12Ro

utin

e an

d co

rrec

tive

mai

nten

ance

and

insp

ectio

n2,

957

2,86

4 2,

921

2,98

0 3,

039

3,10

0 3,

162

3,22

5 3,

290

3,35

6 3,

423

13As

set r

epla

cem

ent a

nd re

new

al2,

586

2,66

1 2,

714

2,76

8 2,

824

2,88

0 2,

938

2,99

7 3,

057

3,11

8 3,

180

14N

etw

ork

Ope

x9,

913

9,96

0 10

,159

10

,363

10

,570

10

,781

10

,997

11

,217

11

,441

11

,671

11

,903

15Sy

stem

ope

ratio

ns a

nd n

etw

ork

supp

ort

3,02

5 3,

071

3,13

2 3,

367

3,43

4 3,

503

3,57

3 3,

644

3,71

7 3,

791

3,86

7 16

Busin

ess s

uppo

rt11

,131

12

,293

12

,539

12

,961

13

,220

13

,485

13

,754

14

,030

14

,310

14

,596

14

,888

17

Non

-net

wor

k op

ex14

,156

15

,364

15

,671

16

,328

16

,654

16

,988

17

,327

17

,674

18

,027

18

,387

18

,755

18

Ope

ratio

nal e

xpen

ditu

re24

,069

25

,324

25

,830

26

,691

27

,224

27

,769

28

,324

28

,891

29

,468

30

,058

30

,658

19Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

CY+6

CY+7

CY+8

CY+9

CY+1

020

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

31 M

ar 2

531

Mar

26

31 M

ar 2

731

Mar

28

31 M

ar 2

9

21$0

00 (i

n co

nsta

nt p

rices

)22

Serv

ice

inte

rrup

tions

and

em

erge

ncie

s2,

070

2,00

6 2,

006

2,00

6 2,

006

2,00

6 2,

006

2,00

6 2,

006

2,00

6 2,

006

23Ve

geta

tion

man

agem

ent

2,30

0 2,

300

2,30

0 2,

300

2,30

0 2,

300

2,30

0 2,

300

2,30

0 2,

300

2,30

0 24

Rout

ine

and

corr

ectiv

e m

aint

enan

ce a

nd in

spec

tion

2,95

7 2,

780

2,78

0 2,

780

2,78

0 2,

780

2,78

0 2,

780

2,78

0 2,

780

2,78

0 25

Asse

t rep

lace

men

t and

rene

wal

2,58

6 2,

583

2,58

3 2,

583

2,58

3 2,

583

2,58

3 2,

583

2,58

3 2,

583

2,58

3 26

Net

wor

k O

pex

9,91

3 9,

669

9,66

9 9,

669

9,66

9 9,

669

9,66

9 9,

669

9,66

9 9,

669

9,66

9

27Sy

stem

ope

ratio

ns a

nd n

etw

ork

supp

ort

3,02

5 2,

982

2,98

2 3,

142

3,14

2 3,

142

3,14

2 3,

142

3,14

2 3,

142

3,14

2 28

Busin

ess s

uppo

rt11

,131

11

,935

11

,935

12

,095

12

,095

12

,095

12

,095

12

,095

12

,095

12

,095

12

,095

29

Non

-net

wor

k op

ex14

,156

14

,917

14

,917

15

,237

15

,237

15

,237

15

,237

15

,237

15

,237

15

,237

15

,237

30

Ope

ratio

nal e

xpen

ditu

re24

,069

24

,586

24

,586

24

,906

24

,906

24

,906

24

,906

24

,906

24

,906

24

,906

24

,906

31Su

bcom

pone

nts o

f ope

ratio

nal e

xpen

ditu

re (w

here

kno

wn)

32 33 34Di

rect

bill

ing*

35Re

sear

ch a

nd D

evel

opm

ent

36In

sura

nce

37*

Dire

ct b

illin

g ex

pend

iture

by

supp

liers

that

dire

ct b

ill th

e m

ajor

ity o

f the

ir co

nsum

ers

38 39Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

CY+6

CY+7

CY+8

CY+9

CY+1

040

for y

ear e

nded

31 M

ar 1

931

Mar

20

31 M

ar 2

131

Mar

22

31 M

ar 2

331

Mar

24

31 M

ar 2

531

Mar

26

31 M

ar 2

731

Mar

28

31 M

ar 2

9

41Di

ffer

ence

bet

wee

n no

min

al a

nd re

al fo

reca

sts

$000

42Se

rvic

e in

terr

uptio

ns a

nd e

mer

genc

ies

-60

10

2 14

4 18

7 23

1 27

5 32

1 36

7 41

5 46

3 43

Vege

tatio

n m

anag

emen

t-

69

116

165

214

264

316

368

421

476

531

44Ro

utin

e an

d co

rrec

tive

mai

nten

ance

and

insp

ectio

n-

84

141

200

259

320

382

445

510

576

643

45As

set r

epla

cem

ent a

nd re

new

al-

78

131

185

241

297

355

414

474

535

597

46N

etw

ork

Ope

x-

291

490

694

901

1,11

2 1,

328

1,54

8 1,

772

2,00

2 2,

234

47Sy

stem

ope

ratio

ns a

nd n

etw

ork

supp

ort

-89

15

0 22

5 29

2 36

1 43

1 50

2 57

5 64

9 72

5 48

Busin

ess s

uppo

rt-

358

604

866

1,12

5 1,

390

1,65

9 1,

935

2,21

5 2,

501

2,79

3 49

Non

-net

wor

k op

ex-

447

754

1,09

1 1,

417

1,75

1 2,

090

2,43

7 2,

790

3,15

0 3,

518

50O

pera

tiona

l exp

endi

ture

-73

8 1,

244

1,78

5 2,

318

2,86

3 3,

418

3,98

5 4,

562

5,15

2 5,

752

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of fo

reca

st o

pera

tiona

l exp

endi

ture

for t

he d

isclo

sure

yea

r and

a 1

0 ye

ar p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP.

The

fore

cast

is to

be

expr

esse

d in

bot

h co

nsta

nt p

rice

and

nom

inal

dol

lar t

erm

s.

EDBs

mus

t pro

vide

exp

lana

tory

com

men

t on

the

diffe

renc

e be

twee

n co

nsta

nt p

rice

and

nom

inal

dol

lar o

pera

tiona

l exp

endi

ture

fore

cast

s in

Sche

dule

14a

(Man

dato

ry E

xpla

nato

ry N

otes

).Th

is in

form

atio

n is

not p

art o

f aud

ited

disc

losu

re in

form

atio

n.

Ener

gy e

ffici

ency

and

dem

and

side

man

agem

ent,

redu

ctio

n of

en

ergy

loss

es


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)10

S12a

.Ass

et C

ondi

tion

Com

pany

Nam

e

AMP

Plan

ning

Per

iod

SCHE

DULE

12a

: REP

ORT

ON

ASS

ET C

ON

DITI

ON

sch

ref

7 8 9

Volta

geAs

set c

ateg

ory

Asse

t cla

ssU

nits

H1H2

H3H4

H5G

rade

un

know

nDa

ta a

ccur

acy

(1–4

)

10Al

lO

verh

ead

Lin

eCo

ncre

te p

oles

/ st

eel s

truc

ture

No.

1.60

%

2.30

%

39.8

0%

51.6

0%

4.70

%

-2

2.40

%

11Al

lO

verh

ead

Lin

eW

ood

pole

sN

o.12

.00%

5.

80%

41

.20%

40

.30%

0.

70%

-

217

.00%

12

All

Ove

rhea

d L

ine

Oth

er p

ole

type

sN

o.28

.00%

18

.00%

39

.00%

14

.00%

1.

00%

-

228

.80%

13

HVSu

btra

nsm

issio

n Li

neSu

btra

nsm

issio

n O

H up

to 6

6kV

cond

ucto

rkm

-24

.60%

44

.60%

30

.80%

-

-3

13.6

0%

14HV

Subt

rans

miss

ion

Line

Subt

rans

miss

ion

OH

110k

V+ c

ondu

ctor

km-

-99

.70%

0.

30%

-

-4

-15

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

up to

66k

V (X

LPE)

km-

-5.

30%

94

.70%

-

-3

-16

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

up to

66k

V (O

il pr

essu

rised

)km

--

98.9

0%

1.10

%

--

425

.00%

17

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

up to

66k

V (G

as p

ress

urise

d)km

--

--

--

N/A

-18

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

up to

66k

V (P

ILC)

km-

--

100.

00%

-

-4

-19

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

110k

V+ (X

LPE)

km-

--

100.

00%

-

-4

-20

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

110k

V+ (O

il pr

essu

rised

)km

--

--

--

N/A

-21

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

110k

V+ (G

as P

ress

urise

d)km

--

--

--

N/A

-22

HVSu

btra

nsm

issio

n Ca

ble

Subt

rans

miss

ion

UG

110k

V+ (P

ILC)

km-

--

--

-N

/A-

23HV

Subt

rans

miss

ion

Cabl

eSu

btra

nsm

issio

n su

bmar

ine

cabl

ekm

--

-10

0.00

%

--

4-

24HV

Zone

subs

tatio

n Bu

ildin

gs

Zone

subs

tatio

ns u

p to

66k

VN

o.-

5.00

%

35.0

0%

60.0

0%

--

45.

00%

25

HVZo

ne su

bsta

tion

Build

ings

Zo

ne su

bsta

tions

110

kV+

No.

--

-10

0.00

%

--

4-

26HV

Zone

subs

tatio

n sw

itchg

ear

22/3

3kV

CB (I

ndoo

r)N

o.-

-63

.30%

36

.70%

-

-4

-27

HVZo

ne su

bsta

tion

switc

hgea

r 22

/33k

V CB

(Out

door

)N

o.-

-13

.60%

78

.00%

8.

40%

-

45.

00%

28

HVZo

ne su

bsta

tion

switc

hgea

r 33

kV S

witc

h (G

roun

d M

ount

ed)

No.

--

-10

0.00

%

--

4-

29HV

Zone

subs

tatio

n sw

itchg

ear

33kV

Sw

itch

(Pol

e M

ount

ed)

No.

58.0

0%

42.0

0%

--

2-

30HV

Zone

subs

tatio

n sw

itchg

ear

33kV

RM

UN

o.-

--

100.

00%

-

-4

-31

HVZo

ne su

bsta

tion

switc

hgea

r 50

/66/

110k

V CB

(Ind

oor)

No.

--

--

--

N/A

-32

HVZo

ne su

bsta

tion

switc

hgea

r 50

/66/

110k

V CB

(Out

door

)N

o.-

-60

.00%

40

.00%

-

-2

-33

HVZo

ne su

bsta

tion

switc

hgea

r 3.

3/6.

6/11

/22k

V CB

(gro

und

mou

nted

) N

o.11

.70%

1.

40%

32

.40%

54

.50%

-

-4

30.0

0%

34HV

Zone

subs

tatio

n sw

itchg

ear

3.3/

6.6/

11/2

2kV

CB (p

ole

mou

nted

) N

o.-

--

--

-4

-35 36 37 38

Volta

geAs

set c

ateg

ory

Asse

t cla

ssU

nits

H1H2

H3H4

H5G

rade

un

know

nDa

ta a

ccur

acy

(1–4

)

39HV

Zone

Sub

stat

ion

Tran

sfor

mer

Zo

ne S

ubst

atio

n Tr

ansf

orm

ers

No.

-5.

10%

59

.00%

30

.80%

5.

10%

-

410

.00%

Asse

t con

ditio

n at

star

t of p

lann

ing

perio

d (p

erce

ntag

e of

uni

ts b

y gr

ade)

% o

f ass

et

fore

cast

to b

e re

plac

ed in

ne

xt 5

yea

rs

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9 % o

f ass

et

fore

cast

to b

e re

plac

ed in

ne

xt 5

yea

rs

Asse

t con

ditio

n at

star

t of p

lann

ing

perio

d (p

erce

ntag

e of

uni

ts b

y gr

ade)

This

sche

dule

requ

ires a

bre

akdo

wn

of a

sset

con

ditio

n by

ass

et c

lass

as a

t the

star

t of t

he fo

reca

st y

ear.

The

data

acc

urac

y as

sess

men

t rel

ates

to th

e pe

rcen

tage

val

ues d

isclo

sed

in th

e as

set c

ondi

tion

colu

mns

. Also

requ

ired

is a

fore

cast

of t

he p

erce

ntag

e of

uni

ts

to b

e re

plac

ed in

the

next

5 y

ears

. All

info

rmat

ion

shou

ld b

e co

nsist

ent w

ith th

e in

form

atio

n pr

ovid

ed in

the

AMP

and

the

expe

nditu

re o

n as

sets

fore

cast

in S

ched

ule

11a.

All

units

rela

ting

to c

able

and

line

ass

ets,

that

are

exp

ress

ed in

km

, ref

er to

circ

uit l

engt

hs.


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)11

S12a

.Ass

et C

ondi

tion

Com

pany

Nam

e

AMP

Plan

ning

Per

iod

SCHE

DULE

12a

: REP

ORT

ON

ASS

ET C

ON

DITI

ON

sch

ref

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

bre

akdo

wn

of a

sset

con

ditio

n by

ass

et c

lass

as a

t the

star

t of t

he fo

reca

st y

ear.

The

data

acc

urac

y as

sess

men

t rel

ates

to th

e pe

rcen

tage

val

ues d

isclo

sed

in th

e as

set c

ondi

tion

colu

mns

. Also

requ

ired

is a

fore

cast

of t

he p

erce

ntag

e of

uni

ts

to b

e re

plac

ed in

the

next

5 y

ears

. All

info

rmat

ion

shou

ld b

e co

nsist

ent w

ith th

e in

form

atio

n pr

ovid

ed in

the

AMP

and

the

expe

nditu

re o

n as

sets

fore

cast

in S

ched

ule

11a.

All

units

rela

ting

to c

able

and

line

ass

ets,

that

are

exp

ress

ed in

km

, ref

er to

circ

uit l

engt

hs.

40HV

Dist

ribut

ion

Line

Dist

ribut

ion

OH

Ope

n W

ire C

ondu

ctor

km2.

20%

2.

00%

37

.90%

52

.90%

5.

00%

-

22.

90%

41

HVDi

strib

utio

n Li

neDi

strib

utio

n O

H Ae

rial C

able

Con

duct

orkm

--

--

--

N/A

-42

HVDi

strib

utio

n Li

neSW

ER c

ondu

ctor

km-

--

--

-N

/A-

43HV

Dist

ribut

ion

Cabl

eDi

strib

utio

n U

G XL

PE o

r PVC

km0.

50%

0.

10%

4.

20%

88

.20%

7.

00%

-

30.

70%

44

HVDi

strib

utio

n Ca

ble

Dist

ribut

ion

UG

PILC

km24

.10%

72

.80%

3.

10%

-

21.

00%

45

HVDi

strib

utio

n Ca

ble

Dist

ribut

ion

Subm

arin

e Ca

ble

km-

-10

0.00

%

--

-1

-46

HVDi

strib

utio

n sw

itchg

ear

3.3/

6.6/

11/2

2kV

CB (p

ole

mou

nted

) - re

clos

ers a

nd se

ctio

nalis

ers

No.

--

93.3

0%

6.70

%

-4

10.0

0%

47HV

Dist

ribut

ion

switc

hgea

r 3.

3/6.

6/11

/22k

V CB

(Ind

oor)

No.

--

--

--

N/A

-48

HVDi

strib

utio

n sw

itchg

ear

3.3/

6.6/

11/2

2kV

Switc

hes a

nd fu

ses (

pole

mou

nted

)N

o.3.

40%

1.

40%

23

.50%

67

.80%

3.

90%

-

23.

90%

49

HVDi

strib

utio

n sw

itchg

ear

3.3/

6.6/

11/2

2kV

Switc

h (g

roun

d m

ount

ed) -

exc

ept R

MU

No.

17.2

0%

48.3

0%

34.5

0%

--

-3

45.0

0%

50HV

Dist

ribut

ion

switc

hgea

r 3.

3/6.

6/11

/22k

V RM

UN

o.-

0.50

%

9.10

%

80.8

0%

9.60

%

-4

7.00

%

51HV

Dist

ribut

ion

Tran

sfor

mer

Pole

Mou

nted

Tra

nsfo

rmer

No.

7.00

%

3.30

%

19.0

0%

63.7

0%

7.00

%

-3

7.70

%

52HV

Dist

ribut

ion

Tran

sfor

mer

Grou

nd M

ount

ed T

rans

form

erN

o.1.

90%

5.

70%

23

.00%

62

.10%

7.

30%

-

31.

80%

53

HVDi

strib

utio

n Tr

ansf

orm

er

Volta

ge re

gula

tors

No.

--

20.0

0%

50.0

0%

30.0

0%

-4

10.0

0%

54HV

Dist

ribut

ion

Subs

tatio

nsGr

ound

Mou

nted

Sub

stat

ion

Hous

ing

No.

12.7

0%

8.50

%

27.1

0%

50.0

0%

1.70

%

-4

12.7

0%

55LV

LV L

ine

LV O

H Co

nduc

tor

km1.

00%

1.

90%

41

.10%

52

.40%

3.

60%

-

41.

50%

56

LVLV

Cab

leLV

UG

Cabl

ekm

--

10.7

0%

78.2

0%

11.1

0%

-2

0.10

%

57LV

LV S

tree

tligh

ting

LV O

H/U

G St

reet

light

circ

uit

km9.

50%

3.

40%

52

.50%

32

.20%

2.

40%

-

29.

40%

58

LVCo

nnec

tions

OH/

UG

cons

umer

serv

ice

conn

ectio

nsN

o.-

--

20.1

0%

79.9

0%

-2

7.00

%

59Al

lPr

otec

tion

Prot

ectio

n re

lays

(ele

ctro

mec

hani

cal,

solid

stat

e an

d nu

mer

ic)

No.

2.10

%

0.30

%

21.1

0%

68.7

0%

7.80

%

-2

15.0

0%

60Al

lSC

ADA

and

com

mun

icat

ions

SCAD

A an

d co

mm

unic

atio

ns e

quip

men

t ope

ratin

g as

a si

ngle

syst

emLo

t-

100.

00%

-

--

-4

100.

00%

61

All

Capa

cito

r Ban

ksCa

paci

tors

incl

udin

g co

ntro

lsN

o.-

--

96.6

0%

3.40

%

-4

5.00

%

62Al

lLo

ad C

ontr

olCe

ntra

lised

pla

ntLo

t33

.30%

33

.30%

16

.70%

16

.70%

-

-4

41.7

0%

63Al

lLo

ad C

ontr

olRe

lays

No.

26.4

0%

9.90

%

36.5

0%

26.6

0%

0.60

%

-3

28.8

0%

64Al

lCi

vils

Cabl

e Tu

nnel

skm

--

--

--

N/A

-


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)12

S12b

.Cap

acity

For

ecas

t

Com

pany

Nam

eN

orth

pow

er L

tdAM

P Pl

anni

ng P

erio

d 1

Apr

il 20

19 –

31

Mar

ch 2

029

SCHE

DULE

12b

: REP

ORT

ON

FO

RECA

ST C

APAC

ITY

sch

ref

712

b(i):

Sys

tem

Gro

wth

- Zo

ne S

ubst

atio

ns

8

Exist

ing

Zone

Sub

stat

ions

Curr

ent P

eak

Load

(MVA

)

Inst

alle

d Fi

rm

Capa

city

(MVA

)

Secu

rity

of S

uppl

y Cl

assi

ficat

ion

(typ

e)Tr

ansf

er C

apac

ity(M

VA)

Util

isat

ion

of

Inst

alle

d Fi

rm

Capa

city

%

Inst

alle

d Fi

rm

Capa

city

+5

year

s(M

VA)

Util

isat

ion

of

Inst

alle

d Fi

rm

Capa

city

+ 5

yrs

%

Inst

alle

d Fi

rm C

apac

ity

Cons

trai

nt +

5 ye

ars

(cau

se)

Expl

anat

ion

9Al

exan

der S

tree

t15

15

N

-15

100%

15

10

4%

No

cons

trai

nt w

ithin

+5

year

sLo

ad tr

ansf

er to

new

Mau

nu S

ubst

atio

n

10Br

eam

Bay

5 -

N2

--

-N

o co

nstr

aint

with

in +

5 ye

ars

11Da

rgav

ille

12

15

N-1

3 80

%

15

88%

N

o co

nstr

aint

with

in +

5 ye

ars

12Hi

kura

ngi

6 5

N-1

2 12

4%

10

71%

N

o co

nstr

aint

with

in +

5 ye

ars

New

tran

sfor

mer

s

13Ka

iwak

a2

-N

2 -

--

No

cons

trai

nt w

ithin

+5

year

s

14Ka

mo

11

15

N-1

3 75

%

15

89%

N

o co

nstr

aint

with

in +

5 ye

ars

15Ki

orer

oa11

20

N

-12

56%

20

69

%

No

cons

trai

nt w

ithin

+5

year

s

16M

anga

wha

i7

-N

1 -

--

No

cons

trai

nt w

ithin

+5

year

s

17M

arer

etu

3 -

N2

--

-N

o co

nstr

aint

with

in +

5 ye

ars

18M

aung

atap

ere

7 10

N

-13

71%

10

63

%

No

cons

trai

nt w

ithin

+5

year

sLo

ad tr

ansf

er to

new

Mau

nu S

ubst

atio

n

19M

aung

atur

oto

7 8

N-1

2 93

%

8 96

%

No

cons

trai

nt w

ithin

+5

year

s

20N

gung

uru

3 -

N2

--

-N

o co

nstr

aint

with

in +

5 ye

ars

21O

nera

hi8

15

N-1

2 54

%

15

58%

N

o co

nstr

aint

with

in +

5 ye

ars

22Pa

rua

Bay

3 -

N2

--

-N

o co

nstr

aint

with

in +

5 ye

ars

23Po

roti

3 -

N3

--

-N

o co

nstr

aint

with

in +

5 ye

ars

24Ru

akak

a7

10

N-1

2 68

%

10

49%

N

o co

nstr

aint

with

in +

5 ye

ars

Load

tran

sfer

to W

aipu

25Ru

awai

3 -

N2

--

-N

o co

nstr

aint

with

in +

5 ye

ars

26Ti

kipu

nga

15

20

N-1

4 77

%

20

85%

N

o co

nstr

aint

with

in +

5 ye

ars

27W

hang

arei

Sou

th12

10

N

-14

120%

10

10

7%

No

cons

trai

nt w

ithin

+5

year

sLo

ad tr

ansf

er to

Kio

rero

a an

d ne

w M

aunu

Sub

stat

ion

29¹

Exte

nd fo

reca

st c

apac

ity ta

ble

as n

eces

sary

to d

isclo

se a

ll ca

paci

ty b

y ea

ch zo

ne su

bsta

tion

This

sche

dule

requ

ires a

bre

akdo

wn

of c

urre

nt a

nd fo

reca

st c

apac

ity a

nd u

tilisa

tion

for e

ach

zone

subs

tatio

n an

d cu

rren

t dist

ribut

ion

tran

sfor

mer

cap

acity

. The

dat

a pr

ovid

ed sh

ould

be

cons

isten

t with

the

info

rmat

ion

prov

ided

in th

e AM

P. In

form

atio

n pr

ovid

ed in

this

tabl

e sh

ould

rela

te to

the

oper

atio

n of

the

netw

ork

in it

s nor

mal

stea

dy st

ate

conf

igur

atio

n.


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)13

S12c

.Dem

and

Fore

cast

Com

pany

Nam

e

AMP

Plan

ning

Per

iod

SCHE

DULE

12C

: REP

ORT

ON

FO

RECA

ST N

ETW

ORK

DEM

AND

sch

ref

712

c(i):

Con

sum

er C

onne

ctio

ns8

Num

ber o

f ICP

s con

nect

ed in

yea

r by

cons

umer

type

9Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

10fo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

4

11Co

nsum

er ty

pes d

efin

ed b

y ED

B*12

Very

larg

e in

dust

rial

--

--

--

13Co

mm

erci

al a

nd In

dust

rial (

dem

and

base

d N

D9)

1 1

1 1

1 1

14M

ass m

arke

t 98

8 1,

008

1,02

8 1,

049

1,07

0 1,

091

15 16 17Co

nnec

tions

tota

l98

9 1,

009

1,02

9 1,

050

1,07

1 1,

092

18*i

nclu

de a

dditi

onal

row

s if n

eede

d19

Dis

trib

uted

gen

erat

ion

20N

umbe

r of c

onne

ctio

ns20

0 25

0 30

0 30

0 30

0 30

0 21

Capa

city

of d

istrib

uted

gen

erat

ion

inst

alle

d in

yea

r (M

VA)

1 1

1 1

1 1

2212

c(ii)

Sys

tem

Dem

and

23Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

24M

axim

um c

oinc

iden

t sys

tem

dem

and

(MW

)fo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

4

25GX

P de

man

d18

8 19

1 19

3 19

8 20

0 20

2 26

plus

Dist

ribut

ed g

ener

atio

n ou

tput

at H

V an

d ab

ove

4 4

4 4

4 4

27M

axim

um c

oinc

iden

t sys

tem

dem

and

192

195

196

201

203

206

28le

ssN

et tr

ansf

ers t

o (fr

om) o

ther

EDB

s at H

V an

d ab

ove

29De

man

d on

syst

em fo

r sup

ply

to c

onsu

mer

s' co

nnec

tion

poin

ts19

2 19

5 19

6 20

1 20

3 20

6

30El

ectr

icity

vol

umes

car

ried

(GW

h)31

Elec

tric

ity su

pplie

d fr

om G

XPs

1,11

7 1,

141

1,16

5 1,

189

1,21

3 1,

237

32le

ssEl

ectr

icity

exp

orts

to G

XPs

--

--

--

33pl

usEl

ectr

icity

supp

lied

from

dist

ribut

ed g

ener

atio

n22

22

22

22

22

22

34

less

Net

ele

ctric

ity su

pplie

d to

(fro

m) o

ther

EDB

s-

--

--

-35

Elec

tric

ity e

nter

ing

syst

em fo

r sup

ply

to IC

Ps1,

139

1,16

3 1,

187

1,21

1 1,

235

1,25

9 36

less

Tota

l ene

rgy

deliv

ered

to IC

Ps1,

092

1,11

4 1,

137

1,15

9 1,

182

1,20

6 37

Loss

es47

49

50

52

53

54

38 39

Load

fact

or68

%

68%

69

%

69%

69

%

70%

40

Loss

ratio

4.1%

4.

2%

4.2%

4.

3%

4.3%

4.

3%

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

Num

ber o

f con

nect

ions

This

sche

dule

requ

ires a

fore

cast

of n

ew c

onne

ctio

ns (b

y co

nsum

er ty

pe),

peak

dem

and

and

ener

gy v

olum

es fo

r the

disc

losu

re y

ear a

nd a

5 y

ear p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP

as

wel

l as t

he a

ssum

ptio

ns u

sed

in d

evel

opin

g th

e ex

pend

iture

fore

cast

s in

Sche

dule

11a

and

Sch

edul

e 11

b an

d th

e ca

paci

ty a

nd u

tilisa

tion

fore

cast

s in

Sche

dule

12b

.


Appendix C


Com

mer

ce C

omm

issio

n In

form

atio

n Di

sclo

sure

Tem

plat

e

Appe

ndix

C -

Year

-beg

inni

ng In

form

atio

n Di

sclo

sure

Sch

edul

es (2

019

- 202

9)14

S12d

.Rel

iabi

lity

Fore

cast

Com

pany

Nam

eAM

P Pl

anni

ng P

erio

dN

etw

ork

/ Sub

-net

wor

k N

ame

SCHE

DULE

12d

: REP

ORT

FO

RECA

ST IN

TERR

UPT

ION

S AN

D DU

RATI

ON

sch

ref

8Cu

rren

t Yea

r CY

CY+1

CY+2

CY+3

CY+4

CY+5

9fo

r yea

r end

ed31

Mar

19

31 M

ar 2

031

Mar

21

31 M

ar 2

231

Mar

23

31 M

ar 2

410

SAID

I11

Clas

s B (p

lann

ed in

terr

uptio

ns o

n th

e ne

twor

k)95

.0

80.0

80

.0

80.0

80

.0

80.0

12

Clas

s C (u

npla

nned

inte

rrup

tions

on

the

netw

ork)

90.0

90

.0

90.0

90

.0

90.0

90

.0

13SA

IFI

14Cl

ass B

(pla

nned

inte

rrup

tions

on

the

netw

ork)

0.30

0.

25

0.25

0.

25

0.25

0.

25

15Cl

ass C

(unp

lann

ed in

terr

uptio

ns o

n th

e ne

twor

k)2.

00

2.25

2.

25

2.25

2.

25

2.25

Nor

thpo

wer

Ltd

1 A

pril

2019

– 3

1 M

arch

202

9

This

sche

dule

requ

ires a

fore

cast

of S

AIFI

and

SAI

DI fo

r disc

losu

re a

nd a

5 y

ear p

lann

ing

perio

d. T

he fo

reca

sts s

houl

d be

con

siste

nt w

ith th

e su

ppor

ting

info

rmat

ion

set o

ut in

the

AMP

as w

ell a

s the

ass

umed

impa

ct o

f pla

nned

and

un

plan

ned

SAIF

I and

SAI

DI o

n th

e ex

pend

iture

s for

ecas

t pro

vide

d in

Sch

edul

e 11

a an

d Sc

hedu

le 1

1b.


Appendix C


Electricity Distribution Information Disclosure Determination 2012 – (consolidated in 2015)

1. This Schedule requires EDBs to provide explanatory notes to reports prepared in accordance with clause 2.6.6.

2. This Schedule is mandatory-EDBs must provide the explanatory comment specified below, in accordance with clause 2.7.2. This information is not part of the audited disclosure information, and so is not subject to the assurance requirements specified in section 2.8.

Commentary on difference between nominal and constant price capital expenditure forecasts (Schedule 11a)

3. In the box below, comment on the difference between nominal and constant price capital expenditure for the disclosure year and 10 year planning period, as disclosed in Schedule 11a.

Box 1: Commentary on difference between nominal and constant price capital expenditure forecasts The difference between nominal and constant prices is based on application of an escalation factor, using economic forecasts provided by the New Zealand Institute of Economic Research.

Commentary on difference between nominal and constant price capital expenditure forecasts (Schedule 11b)

4. In the box below, comment on the difference between nominal and constant price operational expenditure for the disclosure year and 10 year planning period, as disclosed in Schedule 11b.

Box 2: Commentary on difference between nominal and constant price operational expenditure forecasts The difference between nominal and constant prices is based on application of an escalation factor, using economic forecasts provided by the New Zealand Institute of Economic Research.

Schedule 14a: Mandatory Explanatory Notes on Forecast Information

Appendix C


Clause 2.9.1

We, Laurence Kubick and Phillip Hutchings, being directors of Northpower Limited certify that, having made all reasonable enquiry, to the best of our knowledge:

a) The following attached information of Northpower Limited prepared for the purposes of clauses 2.6.1, 2.6.6 and 2.7.2 of the Electricity Distribution Information Disclosure Determination 2012 in all material respects complies with that determination.

b) The prospective financial or non-financial information included in the attached information has been measured on a basis consistent with regulatory requirements or recognised industry standards.

c) The forecasts in Schedules 11a, 11b, 12a, 12b, 12c and 12d are based on objective and reasonable assumptions which both align with Northpower Limited’s corporate vision and strategy and are documented in retained records.

Director Director

Date: 27/03/2019 Date: 27/03/2019

Schedule 17: Certification for Year-beginning Disclosures(Asset Management Plan and Forecast Information)

Appendix C

Head Office:Northpower Ltd28 Mt Pleasant Road,Raumanga, Whangarei 0110,New Zealand

Postal Address:Northpower LtdPrivate Bag 9018,Whangarei Mail Centre 0148,New Zealand

Ph: 09 430 1803Fax: 09 430 1804Email: [email protected]: northpower.com

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