What Mine Electrification Actually Requires Before the Trucks Arrive

Australian mining companies are ordering battery-electric haul trucks at pace. BHP is trialling 240-tonne battery-electric haul trucks at its Jimblebar iron ore mine in Western Australia, and battery-electric locomotives have arrived in Port Hedland for testing. The equipment is real, it is arriving, and it is impressive.

Here is the trap. The electrical backbone that makes those trucks viable, the transformers, substations, switchgear, grid connections, and the power systems studies that sit beneath them, may not be ready. Without deliberate planning, it may never be.

This gap between the pace of equipment commitments and the pace of infrastructure planning is now the central risk in Australian mine decarbonisation. Electrification is already underway at scale: BHP Mitsubishi Alliance (BMA) in Central Queensland shifts to 100% renewable electricity from July 2026. But the machines and the power systems that feed them are moving at different speeds.

This article is the decision-making resource you did not know you needed. You will finish it knowing what infrastructure must be assessed first, why the sequence matters for both cost and safety, and what a well-planned electrification pathway actually looks like on an Australian mine site.

The equipment is not the project: what mine electrification actually requires

To most people, mine electrification looks like a straightforward swap: pull out the diesel machines, roll in the battery-electric ones. That is the surface. It is also the wrong place to start.

Battery-electric mining equipment is one component of a much larger electrification system, not the system itself. The moment you change the type of machinery running on a site, you change the mine’s entire electrical demand profile. That shift ripples straight into the transformers, the cables, the protection systems, and the upstream grid connection.

According to Australian Power Equipment co-directors Abby Crawford and Andrew Cockbain, battery-electric fleets fundamentally change load profiles and fault levels. Treat the electrical infrastructure as an afterthought, and you inherit major safety, reliability, and cost risks that no quality of equipment can offset.

The real project is the electrical backbone. Without it, even the most advanced battery-electric machine cannot perform as intended. That backbone includes:

• Transformers
• Substations
• Switchgear
• Cabling networks
• Grid connections
• Power systems studies

Here is the financial argument you need to internalise. Research from the Australian Renewable Energy Agency (ARENA) shows that electricity costs represent 15-40% of a mine’s operating expenditure (OPEX), yet electrical infrastructure accounts for no more than 15% of initial direct capital expenditure (CAPEX).

Mine decarbonisation strategies span a broader technology portfolio than electrification alone, and operators building a long-term emissions reduction program need to understand how fleet electrification, hydrogen trials, process heat changes, and carbon offset mechanisms interact before committing to an infrastructure-first sequence for any one of them.

That imbalance is the whole problem in a single ratio. Operators have historically spent little upfront on electrical infrastructure while carrying enormous long-term cost exposure through power. Whole-of-life planning exists to fix exactly that gap.

Get this reframing right and everything changes. Electrification stops being a vehicle procurement program and becomes what it actually is: a power systems project. The equipment is the output, not the investment.

The financial case supports treating it that way.

The compelling case for infrastructure-first electrification The CEFC/MRIWA “Mine Zero” analysis found that treating electrification as an integrated pathway, with infrastructure planned and optimised alongside equipment, delivers a return on investment of approximately 20%, the highest of any modelled decarbonisation approach.

What sits between the grid and the machine: the infrastructure components explained

Picture the electricity flowing from the grid to a machine at the mine face. It does not arrive at one voltage and stay there. It steps down through a cascade of infrastructure, and every layer in that cascade is a place where under-specification creates a failure point.

At the top sits the grid connection point, where high-voltage transmission lines feed into the site. From there, bulk supply substations step the voltage down from 220 kV or 66 kV. Distribution substations take it further down to 11-33 kV. Finally, utilisation voltages of 415 V to 1,000 V deliver power to the machine itself.

Before any of that can be committed to, one diagnostic tool determines whether the existing infrastructure can carry the load: the power systems study. This is the assessment that tells you whether your current network can support the electrification scope you have in mind.

According to Genus project director Beau Stoner, assessing grid connection capacity through power systems studies should be among the earliest steps taken, well before any capital is committed to electrification. The scale of the new load determines how deep those studies need to go and how feasible the whole exercise turns out to be.

There is a financial sting most operators underestimate. When network operators find that upgrades are needed, mining companies are generally required to fund those upgrades themselves. That makes early engagement with the network operator not a courtesy but a cost-control measure.

The scale of this infrastructure is not trivial. Australian Power Equipment has sourced and supplied 12 MVA 33/6.6 kV substations and their associated cable systems for both open-cut and underground mines.

Consider Rio Tinto’s Pilbara operations. Hitachi Energy built the company a network of 17 substations across its sites. That figure tells you something important: high-voltage infrastructure, not vehicle technology, is often the physical and financial limiting factor in mine electrification. This is also the layer where planning decisions become effectively irreversible.

Underground distribution: why depth changes the equation

Underground mines follow the same logic but under more pressure. Power enters underground at 11-33 kV via boreholes or decline cabling, then steps down through a cascade of substations advancing with the mining front. 11 kV is now standard, and 22-33 kV is increasingly deployed.

Depth compounds every variable. Deeper mines mean longer high-voltage reticulation runs, more substations, higher fault levels, and a step-up in distribution voltages. These factors must be anticipated in the design, not bolted on reactively.

This is where a common mistake bites. Add battery charging stations without recalculating fault levels, protection settings, and transformer ratings, and you can compromise the selectivity and safety of the entire network. The additions look small; their electrical consequences are not.

Why the sequence matters: the risks of infrastructure planned after the equipment arrives

You now know what the infrastructure is. The harder question is what happens when you build it in the wrong order.

The most underestimated technical challenge is protection coordination and high-voltage (HV) reticulation design. Battery-electric equipment and high-power chargers force networks to be re-engineered for higher fault levels and higher distribution voltages, and that is a far deeper problem than simply adding more power at the grid connection.

The mechanism is specific. Battery-electric machines and their chargers introduce large, often clustered, short-duration loads that produce high peaks in demand, very different from the steady draw of diesel operation. Those peaks raise transformer loading, short-circuit levels, and voltage-drop issues, pushing existing switchgear and protection systems beyond their original design envelope.

When infrastructure is treated as secondary to equipment, the failure modes are predictable:

1. Overloads on transformers and switchgear never rated for battery-electric peak loads
2. Unsafe fault levels where protection systems have not been re-coordinated for the new network topology
3. Nuisance trips as protection systems encounter unfamiliar load signatures
4. Constraints on future electrification stages that the initial infrastructure cannot accommodate
5. Repeated retrofits, where each equipment change triggers another round of remediation

That last point is not hypothetical. BMA’s staged ABB electrification upgrade at the Goonyella metallurgical coal mine, detailed in March 2024, involved modernising existing electrical installations with a pipeline of further upgrades to follow. Read one way, that is diligent whole-of-life management. Read another, ongoing remediation is precisely the cost of electrification that requires repeated upgrades rather than a single optimised program.

This is the CEFC/MRIWA finding running in reverse. If integrated planning delivers approximately 20% ROI, then piecemeal equipment substitution does not produce equivalent returns. Every project that defers infrastructure assessment is quietly pre-committing to a more expensive, riskier implementation.

There is one risk that surprises operators more than any other, because it breaks the assumption that electrification is a contained, on-site project.

The upgrade that leaves the mine boundary Genus project director Beau Stoner has noted that the extent of infrastructure upgrades required can potentially extend beyond the mine boundary into the broader network. Discover after capital commitment that the grid itself needs reinforcing, and the cost and schedule implications land well outside anything budgeted for a fleet purchase.

Early engagement with network operators and power systems studies is what prevents that scenario. The sequence is not a preference. It is a financial and safety imperative.

The pressure mining electrification places on regional grid infrastructure is already visible in South Australia, where mining electricity demand is driving investment in transmission capacity that extends well beyond individual mine boundaries, illustrating precisely the off-site cost exposure that early network operator engagement is designed to anticipate.

Designing for the mine’s full life: the integrated electrification ecosystem

Enough about what goes wrong. Consider what a deliberately planned electrified mine looks like when the sequence is right, because that destination is already being built in Australia.

A well-designed electrified mine functions as an integrated energy ecosystem. Grid connections, on-site renewable generation, battery storage, intelligent substations, automated distribution, and strategically positioned charging infrastructure all work as a single coordinated system rather than a collection of bolted-together parts:

• Intelligent substations and switchgear
• On-site renewable generation
• Battery storage systems
• Automated monitoring and distribution
• Strategically positioned charging facilities
• Parallel supply connections for reliability

Reaching that state depends on whole-of-life planning, and that principle has a name behind it.

Designing around whole-of-life value Australian Power Equipment co-director Andrew Cockbain frames the strongest electrification outcomes as resilient and adaptable electrical networks designed around whole-of-life value, incorporating refurbishment, redeployment, and recycling from the outset rather than as afterthoughts.

In practice, that means understanding present and future electrical loads, where those loads will sit, and how they will shift over the mine’s operational life, then designing networks flexible enough to absorb that change.

For reliability, parallel supply connections are the preferred configuration, providing backup if one circuit fails. Where parallel connections are not feasible, an internal hybrid system serves as the alternative.

The evidence that this ecosystem is real, not aspirational, is already on the ground. BMA‘s transition to 100% renewable electricity from July 2026 at its Central Queensland coal operations is exactly the renewable integration milestone whole-of-life planning enables. Genus’s Pilbara Transmission Project (220 kV transmission lines and substations) and the Millstream 220 kV substation show infrastructure being built ahead of or alongside electrification to guarantee adequate supply.

The read for you is straightforward. BMA’s July 2026 transition is not an endpoint; it is proof that operators who treat the electrical backbone as the primary project today are the ones positioned to reach that outcome without costly mid-course corrections.

Remote and off-grid operations: whole-of-life planning in isolated environments

A significant proportion of Australia’s mines are not grid-connected, and for them the stakes are higher still. With no grid to lean on, the entire energy supply must be engineered for reliability and life-of-mine cost from day one.

ARENA’s modelling of hybrid diesel-renewable-storage systems for off-grid mines makes the framework explicit: power system design should be judged on life-of-mine costs and reliability, not short-term fuel savings. For remote operations, that whole-of-life lens is not optional. It is the only sound basis for the decision.

For remote and off-grid operations, hybrid power integration combining diesel generators, on-site renewables, and battery storage systems represents the practical architecture that whole-of-life planning must optimise, since no single source can deliver the reliability or cost profile that grid-connected sites take for granted.

One reported example illustrates the payoff, though it should be treated with appropriate caution: an AUD 46 million electrification investment at the Mt Marion Lithium Project is reported to have delivered a 23% reduction in operational expenses in its first year. That figure is not independently confirmed, but it points in the direction the modelling predicts.

The decision framework for operators and investors approaching electrification now

So how do you apply all of this to a real project or investment assessment? The answer is a sequence, and the sequence is the entire point.

1. Commission power systems studies and assess grid connection capacity
2. Model the full-life load profile across the mine’s operational lifespan
3. Design the electrical infrastructure around that whole-of-life profile
4. Engage the network operator on any required upgrades
5. Procure equipment last, once the backbone is confirmed

Before committing capital, four questions separate a ready project from a risky one:

Be honest about the scale of investment. It ranges from tens of millions for individual site upgrades to multi-billion-dollar programs for large operations. Ampcontrol delivered a 65 MVA transformer and a major substation project for a Bowen Basin underground mine, reported in January 2026. Australian Power Equipment’s 12 MVA substation work sits at the smaller end. Both are real capital, and both are the enabling condition for electrification’s returns.

The economics justify the outlay. With electricity representing 15-40% of mine OPEX, the long-term cost lever is enormous, and the CEFC/MRIWA 20% ROI benchmark is what integrated planning unlocks.

The MRIWA net-zero emission mining resources hub underpins the CEFC/MRIWA ‘Mine Zero’ analysis cited throughout this article, providing the primary modelling framework from which the 20% ROI figure for integrated electrification pathways is drawn.

According to Beau Stoner and the Australian Power Equipment co-directors, early communication with network operators and partnerships with the right expertise are operationally and financially critical.

The sequence is not bureaucratic procedure. It is the mechanism by which the 20% return is earned or forfeited. Evaluate an electrification project without first commissioning power systems studies, and you are making a capital commitment without knowing its real cost.

This article is for informational purposes only and should not be considered financial advice. Investors should conduct their own research and consult with financial professionals before making investment decisions.

Past performance does not guarantee future results. Financial projections are subject to market conditions and various risk factors.

Infrastructure first, equipment second: the only sequence that makes the numbers work

Every data point in this article converges on a single conclusion. The electrical infrastructure is the project. The equipment is what you get for having built that infrastructure correctly.

Australia’s leading operators have already internalised this. BMA’s move to 100% renewable electricity from July 2026, Rio Tinto’s 17-substation Pilbara network, and Genus’s 220 kV transmission projects are not equipment stories. They are infrastructure stories, and the fleets follow from them.

The current moment is one of genuine opportunity. The companies treating power systems studies, grid connection planning, and whole-of-life electrical design as the primary investment are the ones building toward the integrated energy ecosystems that deliver the strongest long-term returns.

What separates a successful electrification program from an expensive remediation cycle is not the quality of the equipment. It is the quality and timing of the infrastructure planning that came before the equipment decision. The CEFC/MRIWA 20% ROI benchmark is available to operators who get that sequence right, and largely forfeited by those who do not.

For investors evaluating electrification announcements as signals of ESG progress, our full explainer on ESG commitments and mine electrification capital examines how to distinguish operators with genuine infrastructure planning behind their decarbonisation targets from those making equipment-led announcements without the electrical backbone to support them.

The gap between the two groups is not a technology gap. It is a planning sequence gap, and the electrical infrastructure decisions made over the next two to five years will decide which category each Australian mine falls into. So when you assess any electrification project, ask one question first: does this start with infrastructure, or does it start with equipment?