SECURING ASIA’S ENERGY FUTURE: DIVERSIFIED SUPPLY, LOWER EMISSIONS AND THE ROLE OF LNG

An assessment based on information available as at 8 November 2026. Historical figures, preliminary estimates and forecasts are distinguished below.

Asia’s energy security depends on its ability to provide reliable and affordable energy while reducing greenhouse gas emissions. These objectives must advance together: unreliable supply disrupts economic activity, unaffordable energy places pressure on households and industry, and continued emissions growth increases climate risks.

Liquefied natural gas (LNG) can contribute to this effort by diversifying gas supplies and supporting certain industrial and electricity needs. However, its contribution to decarbonisation depends on how it is produced, transported and used and what energy source it replaces.

1) CURRENT POSITON: GROWING ENERGY DEMAND AND VULNERABLE SUPPLY

Asia is not one uniform energy market. Countries differ in domestic resources, infrastructure, purchasing power and energy policies. Regional planning must therefore accommodate different national circumstances.

Southeast Asia illustrates the scale of the challenge. The International Energy Agency’s (IEA) Southeast Asia Energy Outlook 2026 projects that the region will account for nearly 20% of global energy demand growth to 2035 under today’s policy settings. Before the current crisis, approximately one-third of its gas imports came from the Middle East, exposing buyers to concentrated supply routes.

The 2026 disruption demonstrates why this exposure matters. The IEA’s Global Gas Security Review 2026 reports the following:

These figures describe a market in which alternative suppliers have helped, but have not fully replaced disrupted deliveries. The full-year figure remains a forecast.

2) HOW DEMAND CAN RISE OVER TIME WHEN GAS CONSUMPTION FALLS TODAY

Long-term energy needs and short-term fuel consumption are different measures.

Industrial development, electrification, cooling and digital infrastructure can increase electricity requirements. However, high LNG prices can simultaneously reduce gas consumption by making gas-fired generation and industrial production less economical.

The IEA forecasts a 1.5% decline in Asia-Pacific natural gas demand in 2026, partly reflecting switching from gas to coal and reduced activity in energy-intensive industries. Lower gas consumption under these circumstances should not automatically be interpreted as improved efficiency or successful decarbonisation.

Southeast Asia also faces a structural supply challenge. In the IEA’s stated-policies scenario, regional gas production declines from approximately 210 billion cubic metres in 2024 to 175 billion cubic metres by 2035, while gas demand grows by more than 30%. These are scenario projections, rather than guaranteed outcomes, but they illustrate the potential widening gap between domestic production and consumption.

3) HOW LNG FROM OTHER COUNTRIES CAN CONTRIBUTE

The strongest contribution from overseas LNG is greater choice: more suppliers, more delivery routes and more flexibility when disruptions occur.

The United States has contributed additional supply through facilities including Plaquemines LNG and Corpus Christi Stage 3. Canada, Mexico, Mauritania and Senegal also entered the LNG export market through new projects reflected in the IEA’s 2025 assessment. Globally, LNG exports reached approximately 580 billion cubic metres in 2025, equivalent to around 13% of natural gas consumption.

Canada provides a practical example of a new supply route to Asia. LNG Canada loaded its first export cargo on 30 June 2025. Its initial two processing trains have a combined nameplate capacity of 14 million tonnes per year. Nameplate capacity indicates design capability; actual annual deliveries depend on operating performance and utilisation.

PETRONAS holds a 25% interest in LNG Canada and announced that its first cargo from the facility departed for Japan on 7 July 2025. The company identifies the project’s west-coast location as providing a direct shipping corridor to North Asian markets. This illustrates how a Malaysian energy company can diversify its portfolio through overseas production partnerships.

The policy implication is to evaluate suppliers as a portfolio. Diversification should consider geography, shipping routes, contractual flexibility, reliability, delivered cost and emissions performance. Purchasing from several companies does not provide sufficient protection if their cargoes depend on the same vulnerable route.

4) DOES LNG QUALIFY AS LOWER CARBON ENERGY?

LNG remains a fossil fuel. Its environmental performance must be assessed across the full chain:

The IEA’s updated September 2026 assessment estimates average emissions from LNG production through regasification at 18.6 grammes of CO₂ equivalent per megajoule delivered. This figure excludes final combustion and downstream distribution after regasification. It must therefore not be presented as LNG’s complete life-cycle emissions intensity.

An earlier IEA assessment, based on 2024 data, found that LNG had approximately 25% lower life-cycle emissions than coal on average under its methodology. That comparison does not establish an identical saving for every power station, industrial installation or supply route.

For a particular project, the assessment should examine:

• The fuel or technology being displaced,
• Gas leakage and methane emissions throughout the supply chain,
• Energy used for liquefaction and transport, and
• The efficiency and operating pattern of the receiving plant.

Whether renewable electricity, storage, electrification or efficiency could deliver the same service with lower emissions.

LNG can support emissions reduction where verified performance demonstrates an improvement over the realistic alternative. A general description such as “clean LNG” is insufficient evidence.

5) ACTIONS BEING TAKEN

Several developments show how energy security and emissions management can advance together.

More flexible LNG trade - The International Energy Agency (IEA) reports that destination-flexible contracts represented more than 50% of LNG contracts in 2025, compared with 29% in 2016. Such arrangements help redirect cargoes towards markets experiencing shortages, although buyers remain exposed to competition and price increases,

Greater emissions transparency - Initiatives including the Oil and Gas Methane Partnership 2.0 and the Coalition for LNG Emissions Abatement toward Net-zero are improving the structure and visibility of emissions reporting. The IEA nevertheless cautions that significant uncertainty remains in supply-chain estimates, and

Regional electricity cooperation - On 14 January 2026, Tenaga Nasional Berhad, @Electricite du Laos and the Electricity Generating Authority of Thailand (EGAT)  signed an agreement supporting the second phase of the Lao PDR–Thailand–Malaysia–Singapore Power Integration Project. TNB stated that the arrangement completed implementation enabling total electricity trade of up to 200 MW, including additional supply from Malaysia to Singapore.

This matters because energy security also improves when countries can share electricity and diversify the resources used to generate it.

6) WHAT'S NEXT

The following priorities emerge from these findings.

a) Plan Electricity and Gas together - Demand forecasts should consider industrial growth, cooling, data centres, renewable deployment, storage and efficiency. LNG terminals, pipelines and power stations should be assessed against several demand and price scenarios before investment decisions are made,

b) Diversify both Suppliers and Routes - Procurement strategies should examine common exposure to shipping chokepoints, upstream facilities and contractual restrictions. Emergency arrangements should identify alternative cargoes, delivery windows and available receiving capacity,

c) Match Contracts to Realistic Demand - Long-term purchases can support supply certainty, but excessive fixed commitments can become costly if demand falls. Buyers should assess volume flexibility, resale rights, pricing formulas and take-or-pay obligations together,

d) Make Lower Emissions Claims Measurable - Procurement specifications should define reporting boundaries, require credible methane data and provide for independent verification. Improvements at the liquefaction plant should be distinguished from improvements across the complete supply chain,

e) Accelerate Efficiency, Renewables, Grids and Storage - These investments should proceed alongside necessary fuel procurement. The IEA estimates that renewables, electrification and efficiency investments since 2015 reduced Southeast Asia’s fossil-fuel import costs by approximately US$30 billion in 2025,

f) Strengthen Operational Resilience - Receiving terminals, pipelines and power stations require effective maintenance, competent operators, emergency preparedness, cybersecurity and tested continuity arrangements. Additional supply contracts have limited value if receiving infrastructure cannot operate reliably, and

g) Assign Accountability and Track Results -  Governments, utilities and operators should establish owners, deadlines and measurable indicators. Useful measures include supplier concentration, outage frequency, energy intensity, methane emissions, verified emissions per unit of electricity and the share of demand that can respond during emergencies.

Asia’s energy future will be stronger when diversified LNG supply is combined with domestic resources, regional electricity cooperation and sustained investment in lower-emissions alternatives. LNG’s role should be judged by the reliability it adds, the exposure it reduces and the emissions improvement it can demonstrate.

SWRO: Turning Seawater into a Resource for Industry and Communities - By Nik Zafri

Cover image: AI-generated illustration of an SWRO facility - not a photograph of the former client’s installation.

Disclaimer and Acknowledgement

This article is intended for general technical awareness and knowledge sharing. It draws partly on my consultancy experience supporting a client with interests in construction and desalination towards ISO 9001 certification.

I have not personally observed a working installation using the approach informally described as “slow-boiling” desalination. References to that approach reflect general technical principles and applicable requirements, rather than firsthand verification of an operating unit.

This article does not assess project investment costs, commercial feasibility, water sales or selling prices. Any illustrative electricity-cost calculations are included solely to explain the calculation method and should not be interpreted as actual tariffs, total production costs, quotations or commercial projections.

The discussion does not replace project-specific engineering assessments, regulatory approvals or verification of water and recovered-salt quality for their intended use.

I also extend my thanks to the subject matter experts who prefer to remain anonymous for their valuable input and technical insights.

Water security is also business continuity.

For factories, power stations and mining operations, an interruption in water supply can affect production, equipment, product quality and contractual commitments.

Seawater Reverse Osmosis (SWRO) offers coastal industries an alternative source of freshwater, potentially reducing their dependence on rivers, groundwater and municipal treated-water supplies.

The main focus of this article is SWRO.

1) HOW DOES IT WORK

SWRO uses pressure to drive water through semi-permeable membranes, separating seawater into a low-salinity product stream, called permeate, and a concentrated salt stream, called brine. It operates through membrane separation rather than boiling and condensation.

Diagram 1: Simplified SWRO treatment process

llustrative process only. The treatment configuration depends on seawater characteristics and the required product quality.

Pretreatment protects membranes against fouling and damage. Energy-recovery devices recover hydraulic energy from the pressurised brine stream, reducing pumping demand. The concentrated stream still requires appropriate management.

2.0 CAN IT SUPPORT INDUSTRY

Municipal treated water remains a valuable supply. However, industrial processes may require water specifications that differ from drinking-water requirements.

SWRO can provide an alternative feedwater source, with additional treatment selected for each application.

Table 1: SWRO and its application to various industries

RO is used in boiler-feedwater and semiconductor water-treatment systems. However, SWRO permeate is not automatically boiler-ready or ultrapure water. Further purification and conditioning must meet the relevant equipment and process specifications.

The wider benefit is supply diversification. Where industry can use a suitable alternative source, it may reduce demand on freshwater resources shared with surrounding communities.

Chile provides a practical example. BHP reports that Escondida ceased groundwater withdrawals for operational water supply in 2019 and has sourced its operational water withdrawals from desalinated ocean water since FY2020. Its infrastructure uses reverse osmosis and pumps desalinated water inland to the mine.

3.0 EXAMPLE - WATER OUTPUT AND ELECTRICITY DEMAND

The following calculations illustrate the relationship between feedwater, recovery, product water and electricity consumption.

These are assumed values for explanation, not plant design criteria, a quotation or a performance guarantee.

Table 2: Assumed Values

3.1. Permeate Production

Permeate = Feed × Recovery = 1,000 × 0.45 = 450 m³/day

This is equivalent to 450,000 litres per day, before downstream treatment losses and plant service-water consumption.

3.2. Brine Production

Brine = Feed − Permeate = 1,000 − 450 = 550 m³/day

This simplified balance excludes pretreatment backwash, chemical-cleaning waste and other side streams. Actual intake and waste-management requirements must include them.

3.3 Electricity Demand

Daily electricity = Permeate × Specific electricity consumption = 450 × 3.5 = 1,575 kWh/day

The assumed energy figure must represent a clearly defined system boundary. Additional treatment or long-distance pumping may increase overall consumption.

3.4. Electricity cost

Daily electricity cost = Electricity demand × Electricity rate = 1,575 × RM0.40 = RM630/day

Electricity cost per cubic metre of permeate: RM630 ÷ 450 = RM1.40/m³

This is electricity cost only. Total water cost must also include capital recovery, financing, membranes, chemicals, labour, maintenance, testing, residuals management and distribution.

If all 450 m³/day were suitable for an industrial duty and displaced an equivalent municipal-water demand, the theoretical substitution over 30 operating days would be:

450 × 30 = 13,500 m³

Actual substitution would depend on plant availability, demand, storage and net usable output.

4.0 CAN DESALINATED SEAWATER BE CONSUMED?

Yes, properly treated and verified desalinated seawater can become safe drinking water.

Salt removal is one part of the process. Potable supply also requires control of chemical and microbial risks, appropriate post-treatment, protected storage and distribution, and compliance with applicable drinking-water requirements.

WHO guidance addresses these risks through a water safety plan approach. It also highlights stabilisation or remineralisation to reduce the corrosiveness of desalinated water, and the need to assess substances such as boron that may require particular treatment attention.

Diagram 2: The intended use determines the treatment pathway

Singapore’s NEWater is a separate source: it is produced from treated used water and is extensively used by industry. This distinction matters when comparing seawater desalination with water reclamation and reuse.

6.0 APPLICATION OF ISO 9000 SYSTEM

Different standards address different aspects of the operation.

ISO 13205 and ISO 23446 are technical references with different scopes. As of November 2026, ISO 23446:2021 remains published and is under systematic review; the review does not itself create a replacement edition.

An ISO 9001 certificate supports confidence in the organisation’s management system. It does not, by itself, establish that every batch of water is safe to drink. Product conformity still requires defined acceptance criteria, effective controls and verified results.

7.0 BOILERS AND JKKP

The connection with boilers can arise in two ways: SWRO water may undergo further treatment for use as boiler feedwater, or a separate thermal desalination system may use steam to evaporate seawater.

In Malaysia, the boiler and associated equipment must be assessed against Jabatan Keselamatan dan Kesihatan Pekerjaan (JKKP/DOSH) requirements.

For thermal systems sometimes described informally as “slow boiling,” the heating rate does not determine the legal classification. The equipment’s design, pressure conditions and heating arrangement must be examined.

Under the Occupational Safety and Health (Plant Requiring Certificate of Fitness) Regulations 2024, a steam boiler involves a closed vessel generating steam above atmospheric pressure. JKKP also defines pressure vessels as closed containers operating above or below atmospheric pressure.

A vacuum evaporator should therefore be assessed for applicable pressure-vessel requirements and exclusions. A steam boiler supplying heat to that evaporator may require a separate assessment.

For equipment classified as a regulated steam boiler, key requirements include:

• Required design verification and installation approval.

• Inspection and a valid Certificate of Fitness before operation.

• Registered boiler engineers or visiting engineers and boiler operators, according to applicable Twelfth Schedule arrangements.

• Appropriately registered competent persons or companies for prescribed specialist work.

• Applicable approval for alterations affecting the approved design or operating conditions.

Compliance with applicable statutory and regulatory requirements forms part of ISO 9001 requirements. These legal obligations should therefore be identified and referenced in the Quality Manual and relevant procedures, and fulfilled regardless of certification status.

The management system should connect each regulated item to its approved design, registration details, Certificate of Fitness, competent-person appointments, inspection records and maintenance requirements.

Operating procedures should address the actual hazards, including steam burns, pressure release, vacuum collapse, low-water conditions, scaling, corrosion, chemical cleaning and safe isolation. Protective devices, operating limits and testing arrangements must follow the approved design and applicable requirements.

Water quality and equipment safety require separate evidence: a satisfactory water-test result does not demonstrate that a boiler or evaporator is safe to operate.

8.0 BALANCED DECISION

SWRO carries energy, maintenance and brine-management costs. Intake and discharge arrangements also require environmental assessment. Its suitability should be evaluated alongside demand reduction, leakage control, process-water recycling and other available supplies.

For a coastal industrial development, feasibility should cover the complete system: seawater quality, production demand, power reliability, membrane maintenance, storage, pipelines, environmental requirements and the final water specification.

From a consultancy perspective, this is where process-based management matters: understanding the intended use, identifying risks, establishing controls and retaining evidence that the system consistently delivers what was specified.

The objective is reliable water that is fit for its intended use, supported by sound engineering, safe equipment, controlled operations and evidence of quality.