Overview

This webinar examined how natural gas markets may diverge based on carbon intensity, as global demand for gas continues to grow—particularly in developing economies seeking to replace higher-carbon fuels such as coal. While natural gas remains a relatively low-carbon fossil fuel at combustion, emissions across its full value chain, especially methane leakage and upstream CO₂, present a growing challenge. The presentation drew on recent research and an associated white paper to assess pathways for lowering the carbon intensity of natural gas and how these pathways could reshape future gas markets.

 
Expert Insights & Key Takeaways

Natural gas demand will continue to grow—but emissions matter
Global gas demand is expected to increase through at least 2040, driven by Asia and other developing regions. However, the climate viability of gas depends on addressing life-cycle greenhouse gas emissions, not just combustion emissions.

Carbon intensity varies widely across gas supply chains
Fossil natural gas sources differ significantly in emissions intensity due to variations in production practices, methane leakage rates, flaring, processing, and transport. Among global gas fields and LNG supply chains, carbon intensity can vary by a factor of five, creating opportunities for differentiation.

Methane and CO₂ abatement are essential near-term levers
Emissions reductions can be achieved through:

• Methane leak detection and repair
• Improved pneumatic devices
• Vapor recovery units
• Reduced flaring

Lower-carbon fuel use in compression and liquefaction
These measures can significantly reduce emissions without changing the fundamental gas infrastructure.

Renewable natural gas (RNG): high impact, limited scale
RNG produced from landfills, agricultural waste, and wastewater can achieve very low or even negative life-cycle emissions, but total supply potential is limited to a small fraction of overall gas demand. Current deployment is driven largely by policy incentives such as California’s Low Carbon Fuel Standard.

Synthetic methane offers deep reductions at high cost
Methane synthesized from captured CO₂ and low-carbon hydrogen can reduce emissions by 60–70%, depending on feedstocks. However, costs remain an order of magnitude higher than fossil gas, even with existing tax incentives.

Hydrogen blending has modest near-term potential
Blending hydrogen into existing gas grids can reduce emissions, but practical limits—typically around 10% by volume—are imposed by pipeline materials, safety, and operational constraints. Widespread adoption will require infrastructure upgrades.

LNG trade enables carbon-based differentiation
As international gas trade increasingly shifts from pipelines to LNG, buyers gain more flexibility in sourcing. This opens the door for carbon intensity to become a purchasing criterion, especially in Europe and North Asia.

Policy and market mechanisms are emerging
Governments are deploying a mix of carbon pricing, methane regulations, disclosure requirements, certification schemes, and incentives. While standards and verification remain fragmented, these challenges are manageable and evolving rapidly.
 

Future Outlook

Natural gas markets are likely to diverge based on carbon intensity, rather than remain a single undifferentiated commodity. Fossil gas with low methane leakage, improved operational practices, and transparent emissions reporting will be better positioned to compete in future markets. While renewable natural gas, synthetic methane, and hydrogen blending will play important roles, their impact will be incremental rather than transformative in the near term. As LNG trade expands and policy frameworks mature, carbon-differentiated gas markets are expected to emerge—reshaping investment, trade flows, and long-term demand for natural gas in a decarbonizing global energy system.

Guest Speakers

Greg Bean

Director

Gutierrez Energy Management Institute

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