The following table summarises the network company price changes advised to Simply Energy by each network supplier.
If you know what part of the country you are in, you can find your local network at https://www.ena.org.nz/lines-company-map/
If you know your ICP number or physical address you can find your network at https://www.ea.govt.nz/consumers/your-power-data-in-your-hands/my-meter/ (see Network)
Please Note: Some networks may not have published their 1 April 2026 pricing yet. Email us at solutions@simplyenergy.co.nz if you’d like more details – we’re happy to help.
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NETWORK CODE |
NETWORK NAME |
AVERAGE % CHANGE |
SUMMARY OF PRICE CHANGES |
NETWORK WEBSITE FOR FURTHER INFORMATION |
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ALPE |
Alpine Energy Ltd |
6.6% |
Alpine Energy is maintaining a cost-reflective distribution pricing model in line with the distribution pricing principles and guidelines issued by the Electricity Authority. Incorporating the transition to DPP4 and adjustments for inflation, our revenue from delivery prices for standard connections in 2026/27 has increased by 6.56% compared to 2024/25. This increase fully complies with the price-setting regulations under the Electricity Distribution Services Default Price-Quality Determination 2025. From 1 April 2026, Alpine Energy will provide a credit of $0.03 per kWh to eligible customers who inject electricity between 6.30am – 9.00am and 4.30pm and 9.00pm. The price categories eligible for the negative injection prices are: LOW, 015, 030 & 045. Alpine Energy wish to draw your attention to the increase in daily fixed price for LOW consumer groups to $0.90 per day (from $0.75 per day currently) as part of the government’s phase-out of the Low Fixed Charge Regulations. To ensure that the increase does not unduly impact these consumer groups, we have continued to not allocate any fixed prices for the pass-through and transmission prices to these consumer groups. |
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BUEL |
Buller Electricity Ltd |
0.1% |
Buller Electricity Limited (BEL) has signalled an average price increase of 0.1% across all customers on its network. This comprises an estimated 0.2% increase for Residential Low Users, and an estimated 0.1% increase for Large Industrial customers. All other customer groups have an estimated 0.0% price change impact. Residential Low User Fixed Charge BEL has increased the Fixed Daily Charge for Low User Residential Price Category (Price Category Code – RLU) from $0.75/Day to $0.90/Day for 2026/27. AMD Based Pricing & Chargeable Capacity Assessment BEL made a decision to implement Anytime Maximum Demand (AMD) based pricing for Non Residential connections from 1 April 2021. A key part of their implementation of AMD based pricing is an AMD assessment process undertaken as determined and assessed in September/October for the year ending 31st August. This is the first step in BEL's annual pricing setting process which leads onto Price Category and Chargeable Capacity assignment, price setting, pricing notifications to Retailers, Registry updates effective 1st April, and billing from the start of the next financial year. The majority of Price Category & Chargeable Capacity assignments are being rolled over from the 2025/26 financial year and will therefore remain unchanged in 2026/27. BEL is willing to undertake AMD assessment and Chargeable Capacity assignment for specific ICP’s if the Retailer or consumer provides suitable half-hour data (preferably in the EIEP3 format). |
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CHBP |
Centralines |
8.5% |
Centralines’ distribution prices are set to increase by an average of 8.5%. Distribution prices are increasing mainly because the network needs ongoing investment to stay reliable, and transmission costs are rising under the Commerce Commission’s price path. Centralines have built in efficiencies that have reduced the increases customers would otherwise see.
The following pricing structure changes will be implemented from 1 April 2026:
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CKHK |
Wellington Electricity Lines Ltd |
14.3% |
Overall
Residential
Commercial
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COUP |
Counties Energy Ltd |
5.3% |
Counties Energy is increasing lines prices by 5.3% on average from 1 April 2026. The 5.3% is made up of a 22% increase in Counties Energy’s Transpower charges on 1 April 2026 and just a 3.0% CPI increase in Counties Energy’s distribution component of the lines charge. |
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DUNE |
Aurora Energy |
21.0% |
Price-setting context Aurora Energy has set prices based on the Commerce Commission’s Electricity Distribution Services Default Price-Quality Path (Aurora transition) Amendment Determination 2025 (DPP4) that was published on 25 November 2025. The Determination applies from 1 April 2026 and reflects Aurora’s transition into DPP4 settings. DPP4 has a higher starting price, as it reflects the higher OPEX and CAPEX allowances approved by the Commerce Commission in its final DPP4 decision. The Determination allows Aurora to increase total revenue by 19.2% for the year commencing 1 April 2026. This includes a 15.4% increase in distribution recoveries and pass-through costs, plus an increase of 3.8% increase attributable to higher transmission charges. These changes are fully detailed in the updated version of Aurora Energy’s Pricing Methodology that will be published in March 2026. Distribution Service Charges Overall, these changes result in an average price increase of 21.0% (including 3.8% for transmission costs). The following changes will apply from 1 April 2026:
ToU differentials From 1 April 2026, Aurora Energy are further refining the strength of their ‘opt-in’ ToU price signals. The refinements mean that the prices will more closely reflect the estimated Long-Run Marginal Cost (LRMC) for each pricing area. The ToU differentials for each of the pricing areas that will be applied from 1 April 2026 are:
Negative Tariffs and CPD Export Solution From 1 April 2026, Aurora will also introduce negative tariffs for residential customers who export during winter peak periods, in line with the Authority’s Taskforce 2A decision. The negative tariff is a network pricing mechanism where Aurora pays eligible residential customers for exporting to the grid during peak winter periods, to provide an incentive to support the network when it is most constrained. Customers will be rewarded for exporting during winter peak periods based on 50% of the LRMC price differential between peak and off-peak per the following:
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EASH |
Electricity Ashburton |
8.2% |
Network charges will increase an average of 8% from 1 April to cover the rising costs of operating and maintaining a safe and reliable network across Mid Canterbury. The increase also includes a pass-through of Transpower charges, which will also increase from 1 April. Customers can find out more information on network pricing, including EA Networks pricing-reform, plan options (including off-peak choices) and tools to help right size your capacity, visit [eanetworks.co.nz/network-pricing]. |
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EAST |
Firstlight Network Ltd |
10.9% |
Firstlight’s charges will increase from 1 April 2026 by 10.9% with varying movements across the pricing categories. Transmission charges show a 19.7% increase, while distribution charges are increasing by 9.5%. Due to the ongoing LFC regulation phase out, low user domestic customers will be seeing a 20% increase in their daily fixed charges (increase of 15c from 75c to 90c). As a result of the higher revenue requirements and the changes in LFC regulation, two thirds of domestic customers (all LFC consumers) will see higher than average distribution prices increase, i.e. 12.1%. Standard residential customers will see an average price increase of 8.2%. An updated cost of service allocation methodology in 2022 is continuing to drive mixed rate movements for commercial and industrial customers. The new rebate for generation on connections 50kVA or less will apply in peak times from 1 May to 30 September inclusive. |
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ELEC |
Electra Limited |
15.0% |
From 1 April 2026 line charges will increase for most users. Given the ongoing challenging economic conditions and high cost of living, Electra have not made this decision lightly. Electra are acutely aware of the impact that increases in their line charges have on the community and the affordability challenges households face. The new prices will allow Electra to provide customers with a safe and reliable supply of electricity and to ensure their network remains sustainable over the long term. The need to increase lines revenue is reflects an 17% increase in pass-through costs and 66% increase in the annual discount payment. Overall, the lines component of the average bill is increasing by 15% compared to the figure published last year. |
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ELIN |
Electricity Invercargill |
9.0% |
Electricity Invercargill Limited (EIL) is regulated by the Default Price Path (DPP), this year is the second year following the reset year for the DPP (DPP4). DPP4 allows EIL to increase it’s overall revenue by 9.65% this year. As a result of the uplift in allowable revenues, EIL is to increase its line charges for the residential and general customer groups by an average of 9%. The overall increase incorporates a 17.2% increase in Transmission costs. Whilst the average price increase is as stated above, there will be variations in the line charge changes by load groups. Low Fixed Charge Regulations Phase Out The 2025/26 year represents the fifth and final year of the mandated phase out of the Low Fixed Charge Regulations. All networks will therefore increase daily fixed charges accordingly. Within Electricity Invercargill Limited and The Power Company Limited, a differential in fixed charges will remain in place to reflect the benefits of controlled load arrangements. Distributed Generation Rebate Tariff The Electricity Authority has introduced new Code requirements obligating distributors to introduce negative tariffs for residential and small business customers who export electricity during network peak periods. The negative injection tariff applies to residential and small business customers (≤45 kVA) with an approved network application. Small business is defined as those customers with a connection capacity of up to 45 kVA, with injection volumes required to be submitted in half-hourly format. |
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HAWK |
Unison Networks |
11.5% |
Overall change in revenue
Key structural changes
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HEDL |
Horizon Networks |
6.4% |
With effect from 1 April 2026, Horizon Networks will increase line revenue attributed to consumers (excluding major customers), by 6.4%. This is a total of the weighted average price changes across the various consumer groups. The prices charged by Horizon Networks are regulated by the Commerce Commission (“Commission”) and have been set in accordance with the Commission’s Electricity Distribution Services Default Price-Quality Path Determination 2025. The Commission has provided further information explaining the impacts of the Electricity Distribution Services Default Price-Quality Path Determination 2025 which can be located at https://comcom.govt.nz/electricity-charges. |
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LINE |
The Lines Company |
Not advised |
Every five years, the Commerce Commission sets revenue limits for price-quality regulated lines companies, like The Lines Company [TLC], and the minimum quality standards they must maintain. The period for 2025-2030 (DPP4) was set in November 2024 and is reflected in TLC prices from 1 April 2026. While the industry has seen relatively consistent levels of investment and stable costs in the past, factors like inflation and high interest rates have driven costs higher. Much of New Zealand’s electricity grid was built last century and needs renewing to remain reliable and resilient. The sector is also undergoing significant change as it responds to increasing demand from the transition to a cleaner and more renewable energy future. The increased level of investment is needed to ensure safe and reliable electricity networks. TLC have considered the impact on customers, many of whom are navigating significant challenges due to the cost-of-living crisis, when determining their prices. Amongst other key factors, TLC’s prices also aim to assist New Zealand with decarbonisation (through lower off-peak prices) and retailers in developing innovative pricing options for customers. Injection Payment Requirements A key change that the Electricity Authority has introduced is the Electricity Industry Participation Code Amendment (Injection Payment Requirements). Accordingly, TLC has made the required alterations to facilitate this obligation: KEY POINTS
ADDITIONAL INFORMATION
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LLNW |
Lakeland Network |
17.3% |
This year there will be a price increase of an average 17.3% for the residential and general customer groups from 1 April 2026. Whilst the average price increase is as stated above, there will be variations in the line charges change noted by load groups. The general customer groups have had their individual control period demand levels reassessed, these revised levels are in the schedules which will take effect from 1 April 2026. The schedule lists ICP’s that are subject to a CPD price, and therefore excludes all residential and some general ICP’s Low Fixed Charge Regulations Phase Out The 2025/26 year represents the fifth and final year of the mandated phase out of the Low Fixed Charge Regulations. All networks will therefore increase daily fixed charges accordingly. Distributed Generation Rebate Tariff The Electricity Authority has introduced new Code requirements obligating distributors to introduce negative tariffs for residential and small business customers who export electricity during network peak periods. The negative injection tariff applies to residential and small business customers (≤45 kVA) with an approved network application. Small business is defined as those customers with a connection capacity of up to 45 kVA, with injection volumes required to be submitted in half-hourly format. |
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MARL |
Marlborough Lines Limited |
Not advised |
Not advised |
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MPOW |
Mainpower New Zealand Ltd |
Not advised |
Mainpower has absorbed the increase in operational costs associated with building and maintaining the distribution network for 2026. They have done so by increasing the customer rebate, effectively capping the distribution cost impact on customers for the year. However, they have passed through the increase in transmission costs from Transpower. This increase is $5.1m from the year prior. Mainpower have also increased their recovery on the variable component compared with 2025 pricing. Overall, these factors have a positive effect for an average connection on the network. As a result, the average Residential customer is expected to see a decrease of approximately 3.6% in network charges, which is around $4 per month. For Non-residential, Irrigation, and Temporary Supply customers, network charges will remain at the same level as last year for an average user in the group. All remaining customer groups will see a decrease of around 6% for an average user in those groups. |
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NELS |
Nelson Electricity |
11.5% |
The boards of Network Tasman and Nelson Electricity resolved to amalgamate Nelson Electricity and Network Tasman with effect from 31 March 2026. On completion of the amalgamation Nelson Electricity’s assets and liabilities will vest in Network Tasman and Nelson Electricity will cease to exist as a distributor. From a pricing perspective, Network Tasman will continue to differentiate price levels between the two (sub)networks, but Network Tasman will implement reforms to better align the price structures applied across the two networks. Not all price structures will be aligned for the 2026/27 pricing year, and more work is planned in future pricing years to achieve full alignment of the price structures across the two networks. As a consequence of the amalgamation, price schedules for the two networks will be published under Network Tasman branding. Similarly, the pricing methodology applied to set prices for both sub-networks will be published in a single disclosure. Network Tasman is increasing the overall revenues forecast to recover from retailers trading on the Nelson network. Their total revenues are forecast to increase by approximately 11.5%.
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NPOW |
NorthPower Limited |
7.7% |
Northpower has recently set the prices which they will charge electricity retailers for 2026/2027. Compared to last year, these prices have increased on average by around 7.7%. |
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ORON |
Orion New Zealand Ltd |
14.5% |
On average Orion's network prices are increasing by +14.5%. The uplift reflects the increase to allowable revenues as we enter year two of the Commission’s default price-quality path effective from 1 April 2025 to 31 March 2030 (DPP4). Based on the average consumer within each segment, the pricing is increasing as follows:
Orion has made minimal changes to its pricing structures for the 2026 pricing year to maintain stability and consistency for retailers and consumers. Following consultation with retailers, the following changes will take effect from 1 April 2026: Winter peak injection payment A winter peak injection payment has been introduced for residential, small, and medium general connections, in accordance with clause 12A.7 of the Electricity Industry Participation Code. Peak periods align with Orion’s consumption tariffs (7am–11am and 5pm–10pm on weekdays), with the negative charge applying only during the winter period (1 May to 31 August). Closure of two-way price categories The 2WAYRES and 2WAYSME price categories will be closed following the introduction of winter peak injection payments across all residential, small, and medium general connections. Retailers with ICPs on these categories have been notified of the applicable replacement price category effective from 1 April 2026. Residential Low User fixed charge increase Consistent with the Government’s December 2021 decision to phase out low fixed charge regulations, the general fixed daily supply charge for Residential Low Users will increase from 75 cents to 90 cents. |
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OTPO |
OtagoNet Joint Venture |
12.5% |
In line with the second year Default Price Path (DPP4), OtagoNet Joint Venture (OJV) has received an increase in allowable revenue. As a result, OJV is to increase its line charges for all its customers by an average of 12.45%. The new prices also include an increase in Transmission costs of 17%. Standard residential and general customer group fixed charges increase by 16.6% with 11.9% changes to the peak and 5% increase to the shoulder variable prices to increase the pricing signal. Low user customers have a 15 cent per day increase in their daily fixed charge to 90 cents per day and an increase to the peak variable price and the shoulder variable price. Low Fixed Charge Regulations Phase Out The 2025/26 year represents the fifth and final year of the mandated phase out of the Low Fixed Charge Regulations. All networks will therefore increase daily fixed charges accordingly. Distributed Generation Rebate Tariff The Electricity Authority has introduced new Code requirements obligating distributors to introduce negative tariffs for residential and small business customers who export electricity during network peak periods. The negative injection tariff applies to residential and small business customers (≤45 kVA) with an approved network application. Small business is defined as those customers with a connection capacity of up to 45 kVA, with injection volumes required to be submitted in half-hourly format. |
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POCO |
Powerco Ltd |
7.9% |
The price increase is 7.9% compared to last year; this reflects changes to Powerco’s overall network revenue requirements comprising distribution, transmission, pass-through costs and other recoverable costs. The Commerce Commission sets what network and transmission companies are allowed to charge every five years in its Default Price Path (DPP) review. The latest review, which set the allowable revenue for FY26-30, has resulted in larger increases than previously seen across the regulated networks, including Transpower. As shown below, the impact varies by region and consumer group.
Notable changes to Categories, Tariffs, and the Pricing Policy
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SCAN |
Scanpower Ltd |
5.6% |
Prices have been set to secure a 5.6% increase in total annual line charge revenue while adapting to the Electricity Authority's regulatory expectations (as they relate to distribution pricing reform and how networks must charge for new connections as from that date). The primary driver of this increase is a 15.9% increase in transmission costs for the coming year, as recently notified by Transpower. This follows a 16.2% increase last year. Whilst Scanpower are sensitive to the issue of affordability, it is not viable for Scanpower to absorb this level of cost increase without passing a proportion through to consumers. Under their new pricing, Scanpower calculate that an average domestic customer will pay an additional $1 per week. |
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TASM |
Network Tasman |
9.5% |
Network Tasman are increasing the overall revenues they forecast to recover from retailers trading on the Tasman network in 2026-27. Their total revenues are forecast to increase by approximately 9.5%. This increase is driven by changes to each of the two key components that make up their line charges, being transmission and distribution costs.
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TOPE |
Top Energy Ltd |
6.3% |
The price changes have been made in accordance with the provisions of the 2026-2030 Default Price Path (DPP4) established by the Commerce Commission. The overall change in Top Energy prices is 6.3% before the posted discount. This consists of a 4.6% increase in distribution charges, including recoverable costs, and a 17.1% in passthrough charges, including Transmission. Loss factors have also been reviewed and revised. While the DDP4 regulations permit Top Energy an increase in Forecast Allowable Revenue of 15.8% this year, excluding washup drawdowns, they recognise the financial impact this would have on the community. They have therefore decided to implement a significantly smaller increase than what is allowed to ease this burden. This year, Top Energy continues to phase out the Low Fixed Charge Tariff and increase revenue recovery from fixed charges. For Low User Residential Customers, the daily charge will increase 15c/day to 90c/day as permitted under the Electricity (Low Fixed Charge Tariff Option for Domestic Consumers) Amendment Regulations 2021. For Standard Residential, the daily charge will increase by 47.50c/day to 285.00c/day, and General User will increase by 60c/day to 360c/day. The differential between peak and off-peak TOU prices for standard residential and General customers has been reduced. The overall price change has then been achieved primarily by adjusting other variable charges. |
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TPCO |
The Power Company Ltd |
11.5% |
TPCL’s Board of Directors has approved an increase to line prices effective from 1 April 2026. Residential and general customers will experience an overall increase of 11.5%, which includes a 17.8% increase in transmission costs. Whilst the average price increase is as stated above, there will be variations in the line charges change noted by load groups. This year in line with our pricing strategy we are passing through price increases mainly through the fixed charges and an increase to variable prices with the peak variable price being increased by a larger proportion to increase the differential and signal to the shoulder price. Low Fixed Charge Regulations Phase Out The 2025/26 year represents the fifth and final year of the mandated phase out of the Low Fixed Charge Regulations. All networks will therefore increase daily fixed charges accordingly. Within Electricity Invercargill Limited and The Power Company Limited, a differential in fixed charges will remain in place to reflect the benefits of controlled load arrangements. Distributed Generation Rebate Tariff The Electricity Authority has introduced new Code requirements obligating distributors to introduce negative tariffs for residential and small business customers who export electricity during network peak periods. The negative injection tariff applies to residential and small business customers (≤45 kVA) with an approved network application. Small business is defined as those customers with a connection capacity of up to 45 kVA, with injection volumes required to be submitted in half-hourly format. |
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VECT & UNET |
Vector Networks |
7.8% |
Vector’s electricity distribution prices are regulated by the Commerce Commission (Commission). The Commission sets the allowable revenues a distributor can earn every five years. This is referred to as the default price path (DPP). The fourth DPP (DPP4) commenced 1 April 2025. Vector's prices (excluding transmission) that will apply from 1 April 2026, for the second period of DPP4, are increasing by a weighted average of 7.81%. However, the impact on individual customers may vary from the weighted average price increase due to differences in consumption, and peak and off-peak usage profiles. The price increase is driven by an increase in revenue allowed in the Commission’s DPP4 for Vector plus pass through and recoverable costs. Pricing structure changes Vector will:
Transmission charges Vector has split Transmission charges from its Lines charges. This means, rather than being bundled with its other charges, Transmission Charges appear as a separate line item on your bill. We have used forecasted demand to apportion Vector's Transmission Charges and from 1 April 2026 this rate will change to $0.0286/kWh from the current $0.0289/kWh. We’ve calculated this using the annual Transmission charge Vector has allocated to us and divided it by the forecasted electricity consumption for our customers from 1 April 2026 to 31 March 2027. This enables us to create a single $/kWh value and to carry out a ‘wash-up’ at the end of the year if there are any imbalances. Vector will also calculate a wash up before September 2027. While our methodology is designed to minimise wash-ups, we’ll contact customers who need to pay more or receive a credit shortly after we have been advised by Vector of their wash up calculations. |
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WAIK |
WEL Networks |
10.8% |
With the adjustment in the Regulatory Weighted Average Cost of Capital from the Commerce Commission, along with increased Transmission Charges, WEL prices for FY27 have increased on average by 10.8%.
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WAIP |
Waipa Networks Ltd |
6.2% |
These changes represent a 5% increase in target Distribution revenue and a 9.8% increase in Transmission costs. Distribution and Transmission combined, the average increase for all customers is 6.16%. There have been two changes to the pricing structure which were consulted on in November 2025 Distributed Generation Negative Price Part 12A.7 of the Code amendment requires distributors to implement a negative charge for injection at times where ICPs in the region drive future network investment. This requirement applies only to price categories designed to target Residential customers or small businesses (that have a network connection size up to 45kVA and that export up to 45kW of electricity back to the network at peak times). Waipā Networks has implemented a negative price of ($0.04) per kWh for the Residential Advanced price category, applicable to the Peak periods of 07:00 - 09:30 and 17:30 - 20:00. These time periods are aligned to Waipā Networks existing consumption Peak times. As Waipā Networks has a single pricing region the negative price applies to all areas of their network. Distributed Generation Price Code Structure To date Waipā Networks have had a single 24hr price for distributed generation for their Residential and General groups. With the introduction of the above negative Peak price Waipā Networks have taken the opportunity to align other distributed generation time periods to their existing consumption periods. They have also introduced specific prices/codes for the 400V and 11kV categories. |
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WATA |
Network Waitaki |
7.0% |
The price adjustments detailed below reflect not only the recovery of Network Waitaki’s (distribution) costs but also the pass through of Transpower (transmission) cost increases. 1. Distribution Price Component (Network Waitaki) This year’s price adjustment reflects a strong effort by Network Waitaki to balance necessary network investment to support the future energy needs of the region along with ensuring effective cost control to help maintain the affordability of electricity for their consumers. As part of this process, Network Waitaki have reviewed the need for and timing of their major capital projects along with the use of debt to fairly share the costs of these investments over current and future consumers. The resulting distribution increase of 6.1% reflects Network Waitaki's ongoing commitment to a strong program of asset maintenance and renewals along with ensuring cost effective network management and business support systems. 2. Pass through Price Component In line with the Commerce Commission DPP4 Price Quality Path decision for Transpower, Network Waitaki’s transmission charges will increase by 16.2%. They are also facing increases of at least 6% in other pass-through costs such as local authority rates and industry levies. As a result of these factors, average lines charges across their network will increase by approximately 7%, noting that individual customer impacts will vary depending on price structure and usage patterns. |
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WPOW |
Westpower Ltd |
Not advised |
There has been a continuation of changes to the process for calculating tariffs this year in line with the guidelines from the Electricity Authority (EA) for Distribution Pricing and the new requirements for time-varying tariffs and a negative tariff for injection at peak times.
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