By Chandranath Chakraborty, Founder & Managing Partner · [email protected]
As tariffs, market prices and regulated charges diverge across the region, companies need to move beyond unit-price sourcing and manage power as a portfolio of distinct cost exposures.
Power costs across APAC are moving for very different reasons. Singapore's electricity tariff increased 17.5% for the quarter to September after wholesale power prices more than doubled in seven months. Japan's renewable-energy surcharge has risen to a record ¥4.18/kWh for FY2026. In Korea, the industrial electricity rate for large companies increased 10.2% while household tariffs were held unchanged.
These are not three versions of the same problem. Singapore reflects fuel and wholesale-market exposure. Japan includes a nationally determined surcharge. Korea demonstrates the influence of policy and utility economics. Yet in many companies they eventually appear in the same place: one electricity line in the accounts and one expectation that procurement should reduce it.
That is where the opportunity is often misunderstood.
An industrial electricity bill is not one negotiable price. It combines regulated network charges, statutory levies, market-linked energy costs and commercial terms. Each component behaves differently and requires a different intervention. A tender may be part of the answer, but so may contract redesign, fixing strategy, demand management, supplier negotiation or a different allocation of market risk.
For companies with material power spend across APAC, the first question should therefore be broader than whether the current supplier price is competitive. Management needs to understand which part of the cost can be changed, what is driving it and which intervention will deliver the best economic result.
MomentumX works from that fact base through sourcing strategy, commercial redesign, negotiation, implementation and value delivery.
For the worked model behind this analysis, or to discuss a specific site, category or APAC portfolio: [email protected]
Singapore provides a useful illustration. Network and grid charges are approximately 6.55 cents/kWh and sit within the regulated framework. They do not fall because a buyer changes retailer or negotiates harder.
Japan has a different structure but the same management implication. Its FY2026 renewable-energy surcharge is fixed nationally at ¥4.18/kWh, up from ¥3.98 the previous year. Every buyer pays it irrespective of supplier choice.
Korea introduces another dimension. KEPCO increased industrial electricity rates for large companies by 10.2% in October 2024 to KRW182.7/kWh while household tariffs were held unchanged. The outcome reflected policy and the financial position of the national utility as well as energy-market fundamentals.
The labels and mechanisms vary by country, but the implication is consistent: the total electricity bill and the commercially addressable spend are not the same number.
This distinction matters when savings targets are set. A target applied to the whole bill can hold procurement accountable for regulated or market-driven costs it cannot control. At the same time, focusing narrowly on supplier margin can miss larger opportunities in contract structure, market exposure and demand.
Consider a Singapore industrial site consuming 20 GWh of electricity a year. At 31.91 cents/kWh, its annual bill is approximately S$6.4 million.
Network and grid charges at 6.55 cents/kWh account for roughly S$1.3 million. That portion is regulated and cannot be changed through a supplier negotiation.
The remaining approximately S$5.1 million should not be treated as fully negotiable supplier spend either. Much of it is linked to gas and wholesale electricity prices. Singapore's Uniform Singapore Energy Price moved from S$95.1/MWh in December 2025 to S$206.1/MWh across 1-25 June 2026.
A procurement team cannot negotiate away a doubling of the underlying market.
What management can influence is how the business is exposed to that market: supplier margin, contract duration, fixed or floating structure, timing of price fixes, load profile and allocation of risk between buyer and seller.
The same calculation looks very different elsewhere in APAC. At a Japanese site consuming the same 20 GWh a year, the ¥4.18/kWh renewable surcharge alone adds approximately ¥84 million annually before the energy price and other network charges are considered. In Korea, the reference point is the regulated industrial tariff and its policy cycle rather than the same wholesale mechanism seen in Singapore.
The analytical method travels across markets; the economics do not. That is why the work needs to be done by country and site rather than once at group level.
One of the most important management disciplines in power sourcing is distinguishing the outcome of the sourcing decision from the movement of the underlying market.
A procurement team can negotiate a strong contract and still see the total bill rise because wholesale power or fuel prices have moved against the business. Conversely, a falling market can make an ordinary commercial arrangement look successful.
Without separating those effects, finance cannot explain the variance cleanly and procurement cannot demonstrate where value was actually created.
The same principle applies to longer-term contracts. Corporate power purchase agreements can reduce exposure to spot markets, but they replace some of that exposure with longer-term contractual risk.
The Q2 2026 data illustrates the point. LevelTen Energy's North American solar PPA index stood at US$61.40/MWh, down 4.8% during the quarter, while European PPA prices moved in the opposite direction. A spot commodity price and a long-term contracted price are different instruments. A business can be exposed to both at the same time.
The management question is therefore not simply which supplier offers the lowest rate. It is which risks the company should retain, which it should transfer, for how long and at what cost.
In many companies, responsibility for electricity is fragmented. Facilities or engineering may manage consumption. Procurement owns the supplier contract. Finance owns the budget. Treasury may become involved in hedging or market exposure.
The invoice, however, arrives as one number.
That encourages the organisation to manage electricity as a single sourcing category even though the underlying components have different economic drivers and often different owners.
Across the energy and utilities work reflected in the underlying category analysis, the commercially negotiable share of an industrial power bill in Asia can range broadly, from around one-third to two-thirds of the total depending on the market, contract and site structure.
Many organisations do not know where their own sites sit within that range.
This matters beyond procurement. For finance, it affects forecasting and variance analysis. For operations, it affects decisions on load profile and consumption. For procurement, it determines the part of the spend that should genuinely carry a savings expectation. For management, it clarifies whether the issue is primarily a sourcing problem, a market-risk problem, a demand problem or a structural cost problem.
A conventional tender can therefore produce a disappointing result even when it is well executed. The sourcing process may simply be working on the wrong part of the economics.
The starting point is relatively straightforward. Take twelve months of invoices for each material site and separate the cost into its principal components: regulated network charges, statutory levies, market-linked energy and supplier- or contract-specific costs. Each component should then be sized in monetary terms.
That creates an action map.
Regulated charges belong in the forward planning and budgeting calendar. Market-linked exposure requires decisions on timing, fixing and risk appetite. Supplier economics can be addressed through competitive sourcing and negotiation. Contract structure may require redesign rather than simply retendering. Demand-related cost may require intervention from operations rather than procurement.
Once those components are visible, the organisation can move from a broad objective of reducing electricity spend to a specific set of actions with clear ownership and economic logic.
This also changes the role of procurement. Instead of running a periodic tender against a large undifferentiated spend number, procurement can help management decide which risks to retain, which to transfer, which commercial terms to change and where competitive tension will genuinely improve the economics.
Decomposition is useful only if it leads to action.
Where the analysis identifies material value, the next question is how to capture it. Depending on the market and site, the answer may involve a sourcing event, commercial restructuring, supplier renegotiation, a different fixing approach, changes to contract tenure, power purchase arrangements, demand intervention or a combination of these measures.
The appropriate intervention can also vary within the same company. A multi-country manufacturer may have one site where supplier margin is the main opportunity, another where market exposure dominates, and a third where regulated charges and connection economics make operational changes more important than sourcing.
This is why a group-wide price comparison alone is rarely enough.
MomentumX can take the work through the full cycle: establishing the cost structure, identifying and sizing the opportunity, selecting the right commercial and operational levers, redesigning the sourcing or contracting model where required, negotiating the change and supporting implementation through to value delivery.
The objective is not to produce a better explanation of the electricity bill. It is to create a measurable improvement in the economics of the category.
For CFOs, a component-level view improves forecasting and separates external market movements from controllable performance. It also provides a more defensible basis for budgets and variance analysis.
For CPOs, it changes power from a periodic price negotiation into active management of cost structure, contract economics and market exposure.
For business and operating leaders, it helps determine whether the next dollar of improvement sits in procurement, contracting, consumption, asset decisions or risk management.
For private-equity sponsors, the issue can be particularly important across multi-country portfolios. Energy may appear as a single cost line at portfolio-company level while concealing very different plant-level exposures created by geography, tariff structure, contracts, connection economics and operating profile.
The same principle applies across industries. Manufacturing, consumer products, logistics, data centres, hospitality, healthcare, retail and other power-intensive operations will have very different usage profiles, but the management challenge is similar: understand the economics beneath the bill before deciding where to intervene.
Across all of these situations, the central question is not simply whether power is expensive.
It is why the business is paying what it is paying, which part of that cost can be changed, and what will actually change it.
For the worked model behind this article, a Confidential Spend Review of a specific category or contract, or a discussion on an APAC cost programme: [email protected]
MomentumX works from opportunity identification through commercial strategy, negotiation, implementation and value delivery.
A Confidential Spend Review — a senior look at a single category or contract, on client data under a non-disclosure agreement or on an illustrative basis.
Or the Spend Exposure Index, a confidential self-assessment completed privately, with no data shared.
Written by Chandranath Chakraborty, Founder & Managing Partner, MomentumX Consulting. Two decades running procurement for The Walt Disney Company, Nike, Unilever and Procter & Gamble, with structural cost reductions above 12 per cent across a US$1B+ regional spend base in his most recent role. LinkedIn · [email protected]