What component material ratings miss about Asia’s power assets

Long-term reliability is often determined before equipment enters service.

Across India, China, and Indonesia, electricity systems must meet rising energy demand, integrate new generation, and maintain ageing assets. As grid operators extend asset life and demand more flexibility from existing plants, reliability will increasingly depend on the materials specified for seals, flanged connections, valves, pumps, compressors, and other critical components.

Those choices influence how components respond to harsh conditions created by thermal cycling, chemical exposure, pressure variation, and sustained mechanical loading throughout their intended service life.

The International Energy Agency’s (IEA) July 2026 Electricity Mid-Year Update forecasts electricity-demand growth of 7% in India and 5.5% in China in 2026, whilst its Southeast Asia Energy Outlook 2026 reports average annual regional demand growth of 6%, well ahead of the 4% overall energy demand seen since 2015.

India’s Central Electricity Authority is running a renovation and modernisation and life extension programme to extend some thermal units by 15 to 20 years beyond their original design life. These pressures make material selection a critical factor in asset availability, maintenance requirements, and lifecycle cost.

Indonesia provides a design-stage example. Pertamina Geothermal Energy (PGE) is using equipment-performance, outage, maintenance, and risk data from existing facilities to inform decisions for its 55-megawatt Lumut Balai Unit 3 geothermal plant. Unit 3 is due to enter service in 2030.

A 2026 PGE-authored study of the wider field estimated reservoir temperatures of 275 to 300°C beneath the Tanjung Tiga prospect and identified fluid acidity as a consideration for wellhead equipment and pipeline materials. The operator has said the project will incorporate condition monitoring, predictive maintenance, and enhanced diagnostics from the outset, whilst ensuring equipment can withstand corrosive fluids, and mineral scaling.

This approach shows why local operating evidence, failure records, and service conditions should inform equipment selection and qualification before commissioning.

The failure begins before the leak
Material degradation often receives attention only when a component cracks, leaks, or loses performance. However, the process can begin years earlier. Elastomers may lose recovery after sustained compression; thermoplastics can creep or wear; metals can corrode or fatigue. Thermal cycling, chemical exposure, and pressure variation can accelerate these mechanisms, particularly when they occur together.

Sealing systems are especially exposed at pressure boundaries, where they contact process media under changing temperatures. A seal’s condition can determine whether a valve isolates, a pump retains fluid, a flange remains tight or a compressor remains available.

Validation must therefore look beyond headline temperature ratings. Chemical compatibility, compression-set resistance, modulus, dimensional stability, wear, and extrusion resistance need to be assessed too. Component geometry matters: seal squeeze and gland fill must remain within workable limits at the minimum and maximum design temperatures.

This is why visible inspection alone is insufficient. A 2016 peer-reviewed study by Schrittesser and colleagues, published in Procedia Structural Integrity, found that saturation pressure, decompression rate and carbon dioxide content affected elastomer behaviour. It described damage ranging from crack initiation and growth to component fragmentation.

The broader lesson for power infrastructure is clear: an initial physical-property specification is only a starting point. Validation must also assess how a compound changes over time.

Validation must reflect the real environment
Harsh-service oil and gas engineering offers a useful model because it treats material compatibility as part of the design basis. Standards such as NORSOK M-710, ISO 23936-2 and API Specification 6A set validation approaches for non-metallic sealing materials and elastomers exposed to oil and gas production media, accounting for combined service conditions, failure modes, and loss-of-function consequences alongside individual property data.

Although these standards do not replace power-sector codes, their underlying principles transfer readily.

Within power generation, ASME B31.1 sets minimum requirements for the design, materials, fabrication, testing, inspection, operation, and maintenance of power piping. The applicable standards will vary by asset, and jurisdiction, but testing should represent the relevant combination of temperature, pressure, chemical media, and mechanical loading. A material that performs well in a short immersion test may behave differently under pressure cycling, sustained compression, or repeated start-stop operation. Validation criteria should be defined before testing so results are assessed consistently.

Laboratory validation should be followed, where possible, by controlled field evaluation and structured failure analysis. Field data can reveal operating transients, maintenance effects, and interacting stresses that are difficult to reproduce fully in a test rig. Monitoring cannot correct an unsuitable material choice. Pressure, temperature, vibration, and leakage trends can identify deterioration before a functional failure.

When a component fails, the mechanism should be established and fed back into material selection, component geometry, operating limits, inspection intervals, and future validation programmes. That feedback loop is more valuable than replacing a part without understanding why it failed.

Reliability determines lifecycle cost
The purchase price of a seal, connector, or bearing is easy to measure; the cost of poor reliability is spread across maintenance labour, lost output, safety risk, and shortened asset life.

For critical components, the appropriate comparison includes material price and the expected cost of inspection, maintenance, failure, and downtime over the intended service interval. As the Indonesian geothermal example discussed earlier demonstrates, reliability, availability, and maintainability need to be assessed against capital cost, whilst spare-parts planning should reflect component criticality.

The highest-performance material is not required in every position. Selection should be proportional to the consequence of failure and the actual service environment. The key question is whether the material can maintain the required function for the intended inspection, and maintenance interval, with an acceptable margin against foreseeable operating extremes.

Low-consequence applications may justify a simpler validation route; safety-critical pressure boundaries demand stronger evidence.

These principles carry significant weight in Asia, where demand growth, formal life-extension programmes, and the need for operational flexibility are increasing the value of reliable existing assets. The published evidence supports a clear market observation: long-term reliability is often determined before equipment enters service, when service conditions, degradation mechanisms, and lifecycle risk are built into validation.