Business Consulting in New Zealand
We work with renewable-energy businesses operating in New Zealand to sharpen commercial strategy, win revenue and enter or expand into new segments. New Zealand does not have Australia’s decarbonisation problem — 88.5% of its electricity was already renewable in 2025. It has a harder one: replacing a gas system that is running out, while demand is forecast to grow 81% by 2050.
Solar installersC&I solarBattery & energy storageEnergy retailersRenewable-energy technologyEnergy software & SaaSEV & chargingEquipment suppliersEnergy services
New Zealand Market at a Glance
Four figures we track for the New Zealand market. Each names its source and reporting period.
MBIE, Energy in New Zealand 2026 · CY2025
MBIE, Electricity Demand and Generation Scenarios
Electricity Authority, generation investment pipeline · 2026
MBIE, at 1 January 2026 · down 23% in a year
What the Numbers Mean for Business
The generation argument is already won
New Zealand generated 88.5% of its electricity from renewables in 2025, up from 85.5%, on 9,098 MW of renewable capacity. Renewables reached a record 47.7% of primary energy supply. That means the commercial opportunity here is not persuading anyone to decarbonise electricity — it is the firming, storage and network work that a highly renewable system needs, and the 52% of primary energy that is still fossil-fuelled.
Gas is the constraint, and it is closing
Proven and probable gas reserves fell 23% in a year to 731 PJ, the lowest on record. The Maui field ceases production at the end of 2026, and on 2 September 2026 Methanex — which uses around 40% of national gas supply — announced it will idle its Taranaki plant from early 2027. That frees gas for generation in the short term while removing the market’s largest flexible load, and it puts a repricing risk under every industrial gas contract in the country.
The pipeline is real, and delivery is the bottleneck
There are 1,380 MW of committed projects and a further 1,415 MW under construction, with 1.7 GW of committed capacity due over three years — 94% of it renewable and 930 MW of it solar. Transpower still warns of a winter energy margin breach by 2031 if the pipeline slips. With Master Electricians estimating a shortage of around 6,000 electricians, the constraint on this market is not demand or capital. It is people and delivery capacity.
Understanding the New Zealand Market
What is happening in the New Zealand market, and why it matters commercially.
Solar arrives at scale
New Zealand has spent a decade as a hydro, geothermal and wind market. Solar changed that in two years: installed capacity grew 52% during 2025 to 830 MW, generation rose 66%, and solar is now 57% of the Electricity Authority’s 2026 project pipeline.
| The shift | The commercial impact |
|---|---|
| Pace and scale | Installed solar capacity went from 545 MW to 830 MW during 2025 — 52% growth in one year — and passed 1 GW by June 2026. Solar reached 9.1% of renewable capacity, against 1.9% in 2020. |
| Where it is concentrated | Utility-scale build is concentrated in Northland, Waikato, Bay of Plenty and Canterbury, where irradiance, flat land and network capacity meet. Seven plants of 9 MW or larger were commissioned in 2025. |
| Who captures the value | EPCs, civil and electrical contractors, and the connection, commissioning and O&M chain behind them. Very little of the equipment value stays onshore; almost all of the delivery value does. |
| Timing | Now, and visible for three years. Around 930 MW of the 1.7 GW of committed new capacity to 2028 is solar, so the delivery workload is already contracted rather than forecast. |
| What to watch | Whether grid-connected utility-scale projects keep clearing financial close. The 150 MW Tauhei and 38 MW Omeheu farms energised in 2026 set the delivery benchmark the rest of the pipeline is measured against. |
Where this shows up in the P&L
Delivery revenue before service revenue. Utility-scale work is lumpy, milestone-billed and working-capital hungry, which is a different financial shape from the residential and commercial work most New Zealand businesses grew on.
What to change now
Decide whether you are bidding utility-scale delivery or serving the businesses that do. Trying to do both from one overhead is how New Zealand solar businesses have historically run out of cash in a growth year.
How to know it is working
Contracted forward workload in months, reviewed against crew capacity. Solar’s growth rate makes revenue look healthy long after the pipeline has stopped converting.
Gas decline and the firming problem
This is the defining commercial fact of the New Zealand energy market. Proven and probable gas reserves fell 23% in a year to 731 PJ at January 2026 — the lowest since records began — the Maui field ceases production at the end of 2026, and on 2 September 2026 Methanex announced it will idle its Taranaki plant.
| The shift | The commercial impact |
|---|---|
| Pace and scale | Reserves at 731 PJ, down 23% year on year. Methanex, which consumes around 40% of national gas supply, stops methanol production at the end of February 2027 after 32 years. |
| Where it is concentrated | Taranaki, where production, processing and roughly 500 direct and support jobs sit. The consequences are national: thermal firming, dry-year cover and wholesale price volatility all key off gas availability. |
| Who captures the value | Anyone selling firming — batteries, demand response, flexibility aggregation, geothermal and, at the policy end, the proposed LNG import terminal. Also anyone helping an industrial gas user get off gas before their contract is repriced. |
| Timing | Immediate and continuing. Methanex’s exit frees gas for generation through to the end of the decade while removing the market’s largest flexible demand — a short-term easing that makes the medium-term position harder to read, not easier. |
| What to watch | Gas contract renewal pricing for industrial users, and whether the LNG import terminal proceeds. Both decide the cost floor under every electrification business case in the country. |
Where this shows up in the P&L
Input cost and wholesale exposure. Businesses with gas in their process, or an unhedged electricity position, are carrying a risk that has repriced twice since 2024 and is not finished.
What to change now
If you sell to industrial users, build the offer around their gas contract expiry rather than around your product. If you buy gas or spot electricity, hedge the position before the next renewal, not after it.
How to know it is working
Energy cost per unit of output, tracked monthly rather than annually, and the proportion of your load under contract. Annual review is too slow for a market moving at this pace.
Grid-scale storage
New Zealand commissioned its first grid-scale battery in 2025. By the end of 2026 there will be three, and storage is 18% of the Electricity Authority’s 2026 pipeline. This is the segment where an early position is still available.
| The shift | The commercial impact |
|---|---|
| Pace and scale | Meridian’s 100 MW / 200 MWh Ruakākā battery completed in May 2025. Genesis at Huntly and Contact at Glenbrook, each around 100 MW, are due by the end of 2026, with a further 277 MW actively pursued. |
| Where it is concentrated | Upper North Island, at existing grid and industrial sites where connection capacity already exists. Meridian holds four further consented projects, including a battery in Manawatū. |
| Who captures the value | Civil and high-voltage electrical contractors, control and SCADA integrators, commissioning engineers and long-run O&M providers — plus the traders and optimisers who monetise the asset once it is live. |
| Timing | The capability window is now. New Zealand has built two grid-scale batteries; the businesses that work on the next three will hold the only local reference projects for years. |
| What to watch | Whether the Electricity Authority’s market-design work makes storage revenue stackable across energy, reserves and firming. Revenue certainty, not battery cost, is what limits the pipeline. |
Where this shows up in the P&L
A small number of large contracts with long lead times and real bonding and insurance requirements — a balance-sheet decision as much as a capability one.
What to change now
Decide whether you are chasing construction, integration or operations. They need different people, and the businesses that win the second and third projects are the ones that picked one on the first.
How to know it is working
Named reference projects and the capability they prove. In a market this small, one credible delivery is worth more than any marketing spend.
Transmission and network investment
Meeting forecast demand needs around NZ$26 billion of capital above base requirements over thirty years, and Transpower alone will spend more than NZ$8.5 billion over fifteen. Consumers are already paying for it: lines charges drove 54% of the 6.8% rise in power bills in the first half of 2026.
| The shift | The commercial impact |
|---|---|
| Pace and scale | Around NZ$26 billion of additional capital over thirty years, roughly NZ$835 million a year. Transmission charges from Transpower rose 17% in 2026 and flow through to every connected customer. |
| Where it is concentrated | Grid upgrades on the Transpower network and network reinforcement across the 29 distribution businesses, following the Commerce Commission’s 2024 revenue determinations. |
| Who captures the value | Civil, electrical and high-voltage contractors, surveying and environmental consultants, and the equipment and services chain behind them — largely before any generation revenue exists. |
| Timing | Rolling through the current regulatory periods, so this is a programme workload rather than a project one. The buyers are regulated entities with published capital plans. |
| What to watch | The next Commerce Commission determinations and each distributor’s asset management plan. Both publish what will be built and when, well ahead of tender. |
Where this shows up in the P&L
Two ways at once. It is a revenue opportunity if you deliver network work, and a rising cost line if you are an energy-intensive business or a retailer passing charges through.
What to change now
If you sell to networks, work from published asset management plans rather than tender notices — by tender the specification is already set. If you buy electricity, model lines charges separately from energy; they are rising faster.
How to know it is working
Share of revenue from regulated buyers, or for a buyer, the split of your bill between energy and delivery. Most businesses cannot state that split, which is why the increases surprise them.
Electrification of demand
MBIE expects national electricity demand to rise 81% by 2050, from 39.6 TWh to 71.7 TWh. Process heat is the near-term driver: over half of it is still fossil-fuelled, producing around 8 million tonnes of CO₂e — about 28% of New Zealand’s energy emissions.
| The shift | The commercial impact |
|---|---|
| Pace and scale | Demand from 39.6 TWh to 71.7 TWh by 2050 on MBIE’s scenarios. Policy intent is to ban new low- and medium-temperature coal boilers and phase out existing ones by 2037. |
| Where it is concentrated | Food and dairy processing, wood processing, meat and manufacturing — mostly regional, mostly South Island and central North Island, and mostly on coal or gas today. |
| Who captures the value | Mechanical and electrical engineering, industrial heat pump and electrode boiler suppliers, energy consultants building the business case, and the connection specialists who make the load possible. |
| Timing | Driven by plant replacement cycles and gas contract expiry rather than by a target year. The commercial trigger is a boiler at end of life or a repriced gas contract, not a policy date. |
| What to watch | New large-load connection enquiries, including data centres, and whether EECA co-funding continues. Co-funding availability moves projects by years, in both directions. |
Where this shows up in the P&L
New revenue lines rather than growth in existing ones. Electrifying customers buy engineering, business cases and controls, all of which price differently from equipment supply.
What to change now
Sell the business case before the technology. These decisions are made by a CFO comparing capital cost against a gas price they no longer trust, not by an engineer comparing equipment.
How to know it is working
Share of revenue from customers whose electrical load is growing. If that share is flat, you are selling into replacement demand rather than the transition.
Distributed energy and rooftop solar
Only about one in twenty-five New Zealand homes has solar, against more than three in ten in Australia — and that gap is closing quickly. Installations grew 57% in the year to June 2026, roughly 275 households a week, helped by a government review of residential consenting.
| The shift | The commercial impact |
|---|---|
| Pace and scale | 80,463 homes had solar at June 2026, up 14,318 in a year — 57% growth. Distributed solar capacity rose 44% in 2025 with a record 258 MW installed. |
| Where it is concentrated | Northland, Bay of Plenty, Hawke’s Bay, Nelson and Canterbury lead on penetration; Auckland leads on volume. Uptake tracks irradiance and household income rather than network constraint. |
| Who captures the value | Installers and electricians with the Mains Parallel Generation endorsement, and increasingly the retailers and aggregators who hold the ongoing relationship after the install. |
| Timing | The land-grab phase is happening now. Penetration this low means the market is still about acquiring first-time customers, which is a different business from Australia’s replacement and retrofit market. |
| What to watch | The outcome of the residential consenting review and the move to legalise plug-in solar. Both would lower the cost to serve and pull volume forward sharply. |
Where this shows up in the P&L
Volume growth against thin, fragile margins. Demand rose an estimated 400% in three months in early 2026 — the businesses that could not resource it lost the customers rather than the revenue.
What to change now
Resource for a step change rather than a trend line, and decide whether you sell hardware or hold a relationship. A one-off install and a ten-year service relationship are different businesses sharing a first transaction.
How to know it is working
Installs per crew per week, and the proportion of customers under an ongoing service or monitoring agreement. If that second number is near zero, every job has to be won again.
Market structure and competition reform
Four vertically integrated gentailers dominate generation and retail. The Electricity Authority and Commerce Commission’s Energy Competition Task Force is changing that deliberately, and the measures landing through 2026 are the most consequential market reform in a decade.
| The shift | The commercial impact |
|---|---|
| Pace and scale | Level playing field measures announced May 2026, a new wholesale hedge product from January 2026, and time-of-use plans required from large retailers for most consumers by 1 July 2026. |
| Where it is concentrated | Wholesale contracting and retail pricing. The intent is to give independent retailers and generators access to firming and risk management on non-discriminatory terms. |
| Who captures the value | Independent retailers, independent generators and flexibility traders — the participants for whom access to hedges, not access to customers, has been the binding constraint. |
| Timing | Through 2026 and into 2027. Obligations on gentailers to contract with independents, and non-discrimination requirements, are being phased in rather than switched on. |
| What to watch | Whether hedge volumes actually reach independents. Rules that create an obligation without liquidity change the paperwork and not the market. |
Where this shows up in the P&L
Cost of risk. For an independent, hedge access is the difference between a viable retail book and one that cannot survive a dry year.
What to change now
If you are independent, build the capability to use the new products now — most of the benefit will go to the participants who are ready when liquidity appears. If you are a gentailer’s counterparty, re-read your terms.
How to know it is working
Your hedged position as a share of load, and the price you pay for it against the published wholesale curve.
Where the openings are, who they suit, and what it takes to be credible in them.
Utility-scale solar delivery
Around 930 MW of solar sits inside the 1.7 GW of committed capacity to 2028. New Zealand has built utility-scale solar for two years; almost nobody here has a deep track record, which is unusual and will not last.
| The opportunity | The commercial impact |
|---|---|
| The opening | Balance-of-plant, electrical delivery, connection works and long-run O&M on grid-connected and distribution-connected solar farms. |
| Who it suits | Civil and electrical contractors with programme delivery discipline, and businesses that can hold crews and plant across a multi-project window. |
| Deal size and cycle | Single contracts from NZ$1m to tens of millions, awarded six to eighteen months ahead of construction. |
| Capability required | Health and safety systems a tier-one developer will audit, high-voltage competence, bonding capacity, and the balance sheet to carry milestone billing. |
| Competitive intensity | Currently low by international standards and rising. Australian contractors are already looking across the Tasman at the same pipeline. |
Where the revenue comes from
Construction contracts first, then the twenty-five-year O&M relationship behind them — which is where the margin quality actually sits.
What to build or buy
Prequalification and safety systems before capability. Most contractors lose these bids on documentation, not on price or competence.
How to test it cheaply
Bid a subcontract package on a project already under construction. It tells you whether your systems clear a developer’s audit before you carry head-contract risk.
Firming, storage and flexibility
New Zealand’s dry-year problem used to be solved with thermal generation. With gas declining and Lake Onslow cancelled, it now has to be solved with batteries, demand response and aggregated flexibility — and the market for that is being built from close to nothing.
| The opportunity | The commercial impact |
|---|---|
| The opening | Grid-scale battery delivery and operations, commercial and industrial demand response, and aggregation of distributed batteries and controllable load. |
| Who it suits | Businesses that combine electrical capability with software and market literacy. Neither alone is sufficient, which is exactly why the segment is not crowded. |
| Deal size and cycle | Grid-scale contracts in the tens of millions on multi-year cycles; C&I demand response as recurring revenue per site, contracted in weeks. |
| Capability required | Understanding of the Electricity Industry Participation Code, reserve and ancillary services markets, and metering and control that a market participant will accept. |
| Competitive intensity | Low. A handful of participants are credible here today, and the reform programme is deliberately widening access to the market they trade in. |
Where the revenue comes from
Stacked revenue — energy arbitrage, reserves and firming contracts — rather than any single stream. Modelling one stream in isolation is how these business cases fail.
What to build or buy
Market and trading capability, since the engineering is available to hire. A partnership with an existing market participant is usually faster than registration.
How to test it cheaply
Run demand response across your own sites or a friendly customer’s before selling it. The measured response tells you what the offer is worth.
Commercial and industrial solar
Small business power bills rose 7.2% in the first half of 2026, mostly on lines charges that will keep rising. C&I rooftop penetration is negligible, and PPA structures now let a customer take the saving without the capital.
| The opportunity | The commercial impact |
|---|---|
| The opening | Rooftop and ground-mount systems from 50 kW to 1 MW for manufacturers, cool stores, distribution centres, retail and hospitality — sold on delivered cost, not on ideology. |
| Who it suits | Installers who can add commercial proposal discipline and financial modelling, and businesses able to arrange or underwrite a PPA or lease. |
| Deal size and cycle | NZ$80k to NZ$1.5m, three to nine months, with a finance or procurement function in the approval path. |
| Capability required | A defensible savings model, structural and electrical engineering documentation, references at the same scale, and a funding partner if you offer a PPA. |
| Competitive intensity | Moderate. Many can install it; few can put a proposal in front of a CFO in language that gets approved. |
Where the revenue comes from
A smaller number of larger contracts, plus expansion and storage work on sites that perform as modelled. Reference sites do most of the selling.
What to build or buy
Modelling and proposal capability, and one referenceable project at the target scale. Both cost less than a sales team and do more.
How to test it cheaply
Take three existing commercial customers a fully modelled proposal. Whether they engage tells you if the capability is credible before you market it.
Process heat conversion
Over half of New Zealand’s process heat is still fossil-fuelled, and policy intent is to phase out low- and medium-temperature coal boilers by 2037. Gas decline has turned a compliance timeline into a commercial one.
| The opportunity | The commercial impact |
|---|---|
| The opening | Feasibility, business case, engineering and delivery for industrial heat pumps, electrode boilers, biomass conversion and the electrical infrastructure each one needs. |
| Who it suits | Mechanical and electrical engineering businesses, energy consultancies, and equipment suppliers who can carry a project from business case through commissioning. |
| Deal size and cycle | NZ$500k to NZ$20m+, twelve to thirty-six months, usually with EECA co-funding somewhere in the path. |
| Capability required | Process engineering credibility, an emissions and energy model the customer’s board will accept, and connection capability for a materially larger electrical load. |
| Competitive intensity | Low to moderate, and concentrated among a small number of specialists. The constraint is capable suppliers, not interested customers. |
Where the revenue comes from
Long engagements with high engineering content, and the maintenance relationship afterwards. Feasibility work is a low-margin door into a high-margin project.
What to build or buy
Business-case capability and one completed conversion to point at. In a market this small, one reference plant opens the whole sector.
How to test it cheaply
Offer a paid feasibility study to two existing industrial customers with ageing boilers. It is a small commitment for them and a real qualification for you.
Residential solar and storage
New Zealand residential solar is roughly where Australia was fifteen years ago, and it is compounding fast. Batteries are the next attach, and almost nobody has built the service relationship that follows the install.
| The opportunity | The commercial impact |
|---|---|
| The opening | First-time residential solar, battery retrofit into the existing installed base, and the monitoring and service relationship that turns a one-off sale into recurring revenue. |
| Who it suits | Installers with EWRB-registered electricians holding the Mains Parallel Generation endorsement, and businesses that can run a repeatable sales and install process at volume. |
| Deal size and cycle | NZ$10k to NZ$35k, one to eight weeks. Volume, conversion rate and install throughput decide the economics, not deal size. |
| Capability required | Compliant installation practice under AS/NZS 3000, 4777.2 and 5033, distributor connection approval, and a service model that survives after handover. |
| Competitive intensity | Rising quickly and price-led. The differentiation available is trust and service, and it is available now because so few competitors offer either. |
Where the revenue comes from
Installation margin first, then battery attach into your own customer book — which is materially cheaper to sell to than a cold market.
What to build or buy
Install capacity and a service proposition, in that order. Acquiring another installer’s customer book is usually faster than building one.
How to test it cheaply
Offer battery retrofit to your existing solar customers before marketing it externally. Weak attach on warm customers will not be rescued by cold demand.
Connection, consenting and compliance services
Grid connection, resource consent, environmental assessment and compliance are the services every project buys and few businesses supply well. Electrify NZ reform will change the process without reducing the volume of work.
| The opportunity | The commercial impact |
|---|---|
| The opening | Connection applications and network engagement, consenting and expert evidence, iwi and community engagement, commissioning and compliance documentation. |
| Who it suits | Consultancies and specialists with genuine regulatory literacy — this is a credibility market where the buyer is choosing on track record, not price. |
| Deal size and cycle | NZ$50k to NZ$2m per project, running alongside development for one to three years. |
| Capability required | Current knowledge of the Electricity Industry Participation Code, the fast-track pathway and the reform bills, plus relationships at Transpower and the distributors. |
| Competitive intensity | Low, and constrained by the availability of experienced people rather than by demand. |
Where the revenue comes from
Fee revenue tied to project count rather than project size, which makes it a more stable line than construction.
What to build or buy
People. This capability is hired or acquired; it is not built quickly, and the reform programme is about to make current knowledge scarcer.
How to test it cheaply
Take one project through the fast-track pathway end to end. What you learn is the product, and it is saleable immediately.
Independent retail and aggregation
The Energy Competition Task Force is changing wholesale access, hedge availability and retail pricing obligations specifically to let independents compete. That is a policy-created opening, and those close when the policy attention moves on.
| The opportunity | The commercial impact |
|---|---|
| The opening | Independent retail, flexibility aggregation and virtual power plant models — including retail propositions built around the time-of-use plans now required of large retailers. |
| Who it suits | Businesses with a customer base already, or an installed base of solar and batteries that can be aggregated into a tradeable position. |
| Deal size and cycle | Recurring revenue per customer, with the economics turning on acquisition cost, churn and the hedge position behind the book. |
| Capability required | Retailer registration and Code compliance, Consumer Care Obligations, billing and metering, and genuine wholesale risk management. The last of these is what most entrants underestimate. |
| Competitive intensity | Moderate, and about to change. The barrier has been hedge access rather than customer access, and that is precisely what the reform targets. |
Where the revenue comes from
Margin per customer per month, over a book large enough to absorb wholesale volatility. Below that scale it is a trading position, not a business.
What to build or buy
Risk management capability first. Entrants fail on an unhedged winter, not on customer acquisition.
How to test it cheaply
Partner with an existing licensed retailer before registering. It tests the proposition without the compliance and capital cost of standing one up.
The constraints that most often cost money here, and what to do about each one.
Grid connection and network constraints
For developers and C&I providers, network constraints can turn a commercially attractive project into a delayed or lower-value opportunity — often after commitments have already been made to customers and financiers. In New Zealand the position varies by distributor, so a national assumption is worth nothing.
| The constraint | The commercial impact |
|---|---|
| Connection queue position | Revenue recognised months or years after the sale is booked. |
| Export limits applied at approval | Modelled yield and customer savings fall after pricing is fixed. |
| Network augmentation timelines | Delivery dates sit outside the control of the business selling the project. |
| Site-by-site hosting capacity | Otherwise identical sites carry materially different risk. |
| Re-approval after design change | Late redesign cost absorbed inside a fixed-price contract. |
Qualify sites against network reality early
Screen hosting capacity and queue position before a proposal is priced. Declining a site costs less than carrying it.
Hold optionality in contracts
Price connection risk explicitly and tie milestones to network decisions rather than calendar dates.
Spread the pipeline across connection risk
A portfolio mixed across constrained and unconstrained sites keeps cash moving when one approval slips.
Margin compression and price competition
Volume growth can mask a deteriorating unit economic position for several reporting periods, and tendering on price alone rewards the least disciplined quoting.
| The constraint | The commercial impact |
|---|---|
| Price-only tendering | Work won at margins that cannot fund the service obligations attached to it. |
| Undifferentiated commodity offer | Engineering and service value given away inside the unit price. |
| Discretionary discounting in the field | Margin lost on deals that were already winnable. |
| Risk absorbed rather than priced | Variations and rework carried by the business, not by the contract. |
| Aggregate margin reporting | Loss-making segments hidden inside a healthy blended number. |
Separate the commodity from the engineering
Quote hardware, engineering and service as distinct value. Buyers can only pay for what the proposal makes visible.
Set and govern a gross-margin floor
Define the floor, approve exceptions deliberately and decline work below it.
Report margin by segment, product and channel
Blended margin hides the problem. Win-loss by margin band shows which discounts were never needed.
Skilled labour and delivery capacity
Businesses win work they cannot deliver to the promised timeline, then absorb the cost in rework, subcontractor premiums and lost customer goodwill. Master Electricians estimates New Zealand is already short around 6,000 electricians, and apprentice intake is running well below what the infrastructure pipeline needs.
| The constraint | The commercial impact |
|---|---|
| Accredited labour availability | Growth capped by crews rather than by demand. |
| Regional concentration of demand | Travel, accommodation and downtime erode project margin. |
| Selling ahead of capability | Timeline slippage, churn and warranty exposure. |
| Emergency subcontracting | Premium rates paid at the point of least negotiating power. |
| Crew utilisation visibility | Idle capacity in one region while another is oversold. |
Express growth in delivery terms
State the plan as crews, capability and locations, not revenue. Sales targets that outrun capacity become churn.
Price scarce labour properly
Decide which segments are worth crew time, and recover the true cost of the labour they consume.
Plan capacity in the same forecast as pipeline
Review both monthly in one meeting. Separate meetings produce separate assumptions.
Supply chain and equipment risk
Long lead times force stock commitments ahead of contracted demand, putting working capital at risk against a falling price curve. A small, distant market at the end of the shipping line carries all of that more sharply than a large one.
| The constraint | The commercial impact |
|---|---|
| Long lead times | Capital committed before demand is contracted. |
| Landed-cost movement | Quotes priced from list prices lose margin in transit. |
| Manufacturer warranty risk | The obligation sits with the installer in practice, whatever the paperwork says. |
| Supplier withdrawal | A service book stranded on unsupported product. |
| Approved-product sprawl | Training, spares and diagnostics cost multiplies. |
Treat inventory as a financing decision
Review stock monthly against contracted demand rather than procurement habit.
Diversify product without fragmenting the stack
Hold two credible options per category. More than that raises delivery cost without reducing risk.
Score suppliers on more than price
Track warranty response, technical support and delivery reliability so renewals are a commercial conversation.
Customer acquisition cost and trust
Lead costs have risen while conversion rates have not, and businesses buying leads without measuring cost per contracted dollar are usually funding a competitor’s education process. With only three to four percent of homes running solar, most New Zealand buyers have no personal reference point and default to caution.
| The constraint | The commercial impact |
|---|---|
| Longer evaluation cycles | Sales cost per deal rises before revenue does. |
| More competitive quotes per buyer | Price pressure concentrated at the point of decision. |
| Unverified performance claims | A trust discount applied to every proposal. |
| Lead spend without attribution | Budget concentrated in the worst-converting channels. |
| A finance buyer in C&I | Product-led proposals lose to modelled savings and risk allocation. |
Make trust a mechanism, not a message
Publish verifiable performance data, transparent assumptions and references in the buyer’s own segment.
Write for the buyer who signs
For C&I, lead with modelled savings and risk allocation rather than product specification.
Measure cost per contracted dollar
Track it by channel and reallocate quarterly. It is usually the fastest margin improvement available.
Capital access and project finance
Deposits, stock, labour and retention terms mean cash leaves the business well before it returns, and lenders remain cautious about concentrated counterparty and technology risk. A shallow local capital market makes that caution harder to work around than it is in Australia.
| The constraint | The commercial impact |
|---|---|
| Negative cash conversion cycle | Growth consumes cash faster than it generates it. |
| Retention and milestone terms | Profit recognised long before it is collected. |
| Lender caution on the sector | Facility size limited regardless of the order book. |
| PPA, lease and EaaS structures | Covenant, guarantee and ownership requirements the business is not structured to meet. |
| Reporting that is not fundable | Diligence stalls on data the business cannot produce. |
Match the funding structure to the offer
Decide which customers are sold capex and which are offered a financed product, and who carries performance risk in each case.
Model cash conversion alongside revenue
A growth plan without a cash plan is a funding request in disguise.
Start the fundability work early
Getting reporting, contracts and performance data into a fundable state takes roughly twelve months.
The rules that decide what you may sell, how you get paid, and what it costs to comply.
Electricity market regulation
The Electricity Authority administers the Code and is actively rewriting parts of it through the Energy Competition Task Force. Anything that touches wholesale trading, distributed generation or retail sits under it.
| The requirement | The commercial impact |
|---|---|
| What the rule requires | Registration as a participant for the relevant activity, compliance with the Code — including Part 6 for distributed generation connection — and adherence to reconciliation, metering and information disclosure obligations. |
| Who it applies to | Generators, retailers, traders, distributors, metering equipment providers and, through Part 6, anyone connecting generation to a distribution network. |
| Cost and lead time | Participant registration is measured in weeks. Building the systems and risk management the obligations assume takes considerably longer. |
| Change risk | High and deliberate. Level playing field measures, hedge market obligations and time-of-use requirements have all landed in 2026, with more phasing in. |
| What to verify locally | Current Code obligations and the Authority’s live consultations should be checked directly. The Code changes several times a year and secondary summaries date quickly. |
Exposure to check
Whether your intended activity requires participant registration, and which Code parts bind the commercial model you have designed.
What to put in place
Compliance and market operations capability sized for the obligations, not for the launch — most of the cost is ongoing rather than one-off.
What to monitor
Electricity Authority consultation papers and Task Force decisions. Both signal changes twelve to eighteen months before they bind.
Consenting and Electrify NZ
Electrify NZ and the accompanying planning reform are intended to cut consenting time and cost for renewable generation, grid-scale storage, transmission and lines. The direction is settled; the detail is still moving through Parliament.
| The requirement | The commercial impact |
|---|---|
| What the rule requires | Resource consent under the Resource Management Act, or entry to the fast-track pathway. Reform targets one-year consent decisions, 35-year consent durations and default lapse periods extended from 5 to 10 years. |
| Who it applies to | Developers of wind, solar, geothermal, pumped hydro and grid-scale batteries, plus transmission and local lines projects. |
| Cost and lead time | Historically the single largest source of schedule risk in a New Zealand renewable project. Reform is designed to compress it, and has not fully done so yet. |
| Change risk | High in the near term. The Government intends to pass the reform bills in 2026, with national policy direction finalised within nine months and standards rolled out in stages. |
| What to verify locally | Which pathway a specific project qualifies for, and the relevant regional and district plan provisions. These vary materially by council and are not yet standardised. |
Exposure to check
Whether your project timeline assumes the reformed regime or the current one. Business cases built on the reformed timeline before it is law carry the schedule risk.
What to put in place
Planning and consenting advice engaged before site selection, not after. Site choice is where most consenting cost is actually decided.
What to monitor
Progress of the reform bills, the national policy direction, and the national standards as they are staged in.
Electrical safety and installation standards
Prescribed electrical work must be done or supervised by a registered and licensed person, and solar and battery work carries a specific endorsement. This is the compliance layer that most often catches businesses expanding from another market.
| The requirement | The commercial impact |
|---|---|
| What the rule requires | Electrical Workers Registration Board registration and a current practising licence; the Mains Parallel Generation endorsement for grid-connected solar and battery work; installation to AS/NZS 3000, 4777.2 and 5033; and Certificates of Compliance and Electrical Safety Certificates on completion. |
| Who it applies to | Every business performing or supervising prescribed electrical work in New Zealand, including those using subcontracted labour. |
| Cost and lead time | Registration for an experienced overseas electrician is measured in months, not weeks, and is a common cause of delayed market entry. |
| Change risk | Moderate. Standards are periodically updated, and the review of residential solar consenting may change what approvals a household installation needs. |
| What to verify locally | Registration status of every worker and the current version of each standard. Both should be confirmed with the EWRB and Standards New Zealand rather than assumed from Australian practice. |
Exposure to check
Whether your workforce holds the specific endorsement your work requires. An Australian accreditation does not transfer automatically.
What to put in place
A registration and licence register maintained as a live control, and certification built into job closeout rather than chased afterwards.
What to monitor
EWRB requirements, standards revisions, and distributor connection requirements, which vary between the 29 distribution businesses.
Emissions and climate policy
New Zealand legislated net zero for all gases except biogenic methane by 2050, with a separate methane target. The NZ ETS is the price mechanism, and the second emissions reduction plan covers 2026 to 2030.
| The requirement | The commercial impact |
|---|---|
| What the rule requires | Net zero for long-lived gases by 2050 and biogenic methane 14 to 24% below 2017 levels, under the Climate Change Response Act. ETS participants surrender units against emissions; the 2026 cap is 16.3 Mt CO₂e. |
| Who it applies to | Directly, ETS participants including fuel suppliers and large industrial emitters. Indirectly, every business whose energy cost embeds a carbon price. |
| Cost and lead time | Carbon has traded around NZ$50 a tonne. That is enough to matter in an industrial energy business case and not enough to drive one on its own. |
| Change risk | Moderate. November 2025 amendments to the Climate Change Response Act removed the requirement for ETS supply settings to accord with the international commitment while retaining the domestic 2050 target. |
| What to verify locally | Current ETS obligations and unit price should be confirmed before they are used in a business case; both move with policy and with the auction calendar. |
Exposure to check
Whether your business or your customer’s is an ETS participant, and how much of your delivered energy cost is carbon price.
What to put in place
A carbon price assumption stated explicitly in every decarbonisation business case, with sensitivity around it rather than a single number.
What to monitor
ETS settings and auction results, and the emissions reduction plan as it is implemented through the 2026 to 2030 budget period.
Retail, consumer and pricing obligations
Anyone retailing electricity carries Consumer Care Obligations, Code compliance and, for larger retailers, new pricing requirements. Fair Trading Act exposure on savings claims applies to installers and PPA providers as much as to retailers.
| The requirement | The commercial impact |
|---|---|
| What the rule requires | Retailer registration and Code compliance; the Consumer Care Obligations covering vulnerable and medically dependent consumers; and, for retailers with 5% or more market share, a time-of-use plan available to most consumers from 1 July 2026. |
| Who it applies to | Electricity retailers directly. Installers, PPA providers and aggregators are caught by Fair Trading Act obligations on performance and savings claims. |
| Cost and lead time | Consumer care and billing compliance is an ongoing operating cost, and is routinely underestimated by entrants modelling only acquisition and wholesale cost. |
| Change risk | High. Retail pricing obligations are an active area of the reform programme and have changed twice in eighteen months. |
| What to verify locally | Current Consumer Care Obligations and pricing requirements should be confirmed with the Electricity Authority before a retail proposition is launched. |
Exposure to check
Whether savings and performance claims in your proposals would survive a Commerce Commission review, and whether your modelling assumptions are documented.
What to put in place
Substantiation for every quantified claim you publish, and consumer care processes designed in rather than retrofitted.
What to monitor
Electricity Authority retail decisions and Commerce Commission enforcement in the energy sector.
Foreign investment and market entry
New Zealand liberalised its foreign investment regime in 2026, which makes entry faster than it was. It does not remove screening, and it does not remove the local establishment obligations that follow.
| The requirement | The commercial impact |
|---|---|
| What the rule requires | Consent under the Overseas Investment Act where thresholds are met. Reforms in force from 6 March 2026 introduced a national interest test and reversed the presumption against foreign investment. New Zealand company registration, IRD and GST registration, and at least one director resident in New Zealand or Australia. |
| Who it applies to | Offshore businesses acquiring, establishing or investing in New Zealand energy assets or companies, and the local subsidiaries they establish. |
| Cost and lead time | Screening is faster and more targeted than under the previous regime, but still adds time to an acquisition. Establishing an entity is quick; establishing credibility in a small market is not. |
| Change risk | Moderate. The 2026 reforms are recent and the Overseas Investment Office’s application of the national interest test is still being established in practice. |
| What to verify locally | Structure, tax and employment obligations should be confirmed with New Zealand legal and tax advice before commitment. Nothing on this page is a substitute for that. |
Exposure to check
Whether your intended entry structure triggers screening under the reformed regime, and what that does to the transaction timetable.
What to put in place
New Zealand legal, tax and accounting advice engaged before the entry decision, rather than after a target has been identified.
What to monitor
Overseas Investment Office guidance on the national interest test, and how it is being applied to energy and infrastructure assets.
Business Consulting Services in New Zealand
The same four practices we bring to every market we advise in, applied to New Zealand conditions.
01StrategyKnow where to play before you commit capital.
Which New Zealand segments and regions justify your capital, and the commercial case behind the choice — grounded in the committed generation pipeline, the gas transition and a market small enough that the wrong segment choice is expensive to reverse.
- Market and competitor assessment
- Proposition and pricing strategy
- Commercial case and planning
02OperationsReduce the cost and friction of running the business.
Delivery cost, crew utilisation and operating model — the work that protects margin when registered labour is the binding constraint and every region is served across long distances.
- Operating model and structure
- Process and delivery cost
- Commercial governance and reporting
03Sales & MarketingTurn your lead pipeline into contracted revenue.
Demand generation, qualification and sales execution built for how New Zealand buyers actually purchase — from a first-time residential buyer with no reference point through to a regulated network with a published procurement cycle.
- Go-to-market and channel design
- Pipeline and conversion discipline
- Bid, tender and proposal support
04Agentic AIPut AI to work where it can produce a measurable return.
Automation and AI applied where they change unit economics — quoting, system design, compliance documentation and back-office work — sequenced against a business case rather than a pilot.
- Opportunity assessment and business case
- Workflow automation
- Data, reporting and AI enablement
Growing Your Business in New Zealand
Most conversations start in one of five places. Find the one that describes your position.
01Entering the marketFor international companies assessing New Zealand.
Whether New Zealand justifies the investment, which entry model fits, and what the first year realistically looks like. The 2026 investment reforms made entry faster; the market is still small enough that scale assumptions imported from Australia are usually wrong by a factor.
- Market and competitor assessment
- Entry model and partner selection
- Commercial case and first-year plan
02ExpandingFor businesses increasing market share, geographic coverage or customer penetration.
Which region, segment or customer type to take next, and whether you can serve it profitably. In New Zealand the most common expansion error is treating the two islands and 29 distribution networks as one market with one cost to serve.
- Segment and geographic prioritisation
- Proposition and pricing for the new segment
- Channel and partnership build-out
03Improving performanceFor businesses dealing with margin, revenue, productivity or operational issues.
Where value is leaking — pricing, mix, conversion or delivery cost — and fixing it in order of impact. Here it is usually travel and delivery cost against a price set by a competitor with a shorter drive.
- Margin and mix discovery call
- Pricing and quoting discipline
- Sales conversion and delivery cost
04ScalingFor businesses whose operating model is not keeping pace with growth.
Rebuilding the operating model — structure, process, systems and commercial governance — so growth stops costing more than it earns. When registered electricians rather than leads are the constraint, revenue targets set without capacity planning turn into churn.
- Operating model and structure
- Commercial process and governance
- Systems and reporting
05TransformingFor businesses looking at technology, automation and AI.
Where technology and AI genuinely change the economics of the business — quoting, design, compliance and back office — and how to sequence the work so it pays before it scales.
- Opportunity assessment and business case
- Automation of commercial workflow
- Data, reporting and AI enablement
Talk to Us about Your Position in New Zealand.
A scoping call is a working conversation, not a pitch. Tell us where you sit in the New Zealand market and we will tell you plainly whether we can help.