Muhammad Yousuf Jabbar

Liquefied natural gas (LNG) supply chains rely on extensive field-to-processing-to-liquefaction (FF–PP–LNG) pipeline networks, yet greenhouse gas (GHG) emissions from this midstream segment remain poorly characterised. The 2025 IEA inventory reports 350 MtCO₂-eq across LNG supply stages but excludes midstream emissions, obscuring hotspots, carbon budgets, and mitigation priorities. Here, we present a global bottom-up assessment of FF–PP–LNG pipelines. Covering >90% of 2022 LNG supply across 20 countries (~470,000 km of pipelines, ~2,000 fields, ~400 processing plants, and 45 liquefaction facilities), we identify 2,639 compressor stations emitting 50.6 MtCO₂-eq, corresponding to a volume-weighted carbon intensity of 0.255 gCO₂-eq MJ⁻¹ (FF–PP: 0.085 g; PP–LNG: 0.17 g). Methane leakage accounts for 96.9 MtCO₂-eq (65.7% of total GHGs). Satellite-based data attribute 2.87 MtCH₄ to FF–PP and 0.70 MtCH₄ to PP–LNG, with route intensities of 0.19–50 gCH₄ MJ⁻¹. Optimised transmission and compressor upgrades could abate 30 MtCO₂-eq y⁻¹. Results enable transparent carbon accounting and targeted investment of global LNG supply chains decarbonisation.

The recent global energy crisis, originating from the global pandemic, disruption in supply chains, and Europe's geopolitical developments, drove unprecedented reliance on liquefied natural gas (LNG) [1,2]. Yet, LNG's supply chain climate implications have remained poorly quantified [3]. Here, we present the first comprehensive greenhouse gas emissions assessment of global LNG value chain by capturing 85% of global LNG trade in 2022 by covering 2,500 oil and gas fields, >1,000 gas processing plants, 33 liquefaction terminals, 123 regasification terminals, 1.25 million km of natural gas transmission pipeline, and 948 unique LNG trade routes. We find that carbon intensity varies threefold between supply chains, from 8.0 to 26 g CO2eq./MJ, with methane emissions accounting for over half of the total climate impact, where approximately 75% of total methane emissions originate from superemitters. Our analysis of 948 trade routes reveals that importing countries' emissions profiles depend heavily on supply choices. Japan maintains below-average intensity through selective sourcing, while Spain's reliance on high-emission suppliers doubles its carbon footprint. While our analysis reveals no strong explicit correlation between carbon intensity and terminal LNG sales economics, more granular project-level analysis reveals systematic relationship between both combustion-related emissions and methane emissions, and LNG sales price. Meeting proposed methane regulations would require some exporters to cut emissions by up to 98%, potentially reshaping global trade patterns. These findings provide granular data needed to align energy security with climate goals, as LNG demand is projected to grow 40% by 2030 [2,4].

Understanding the greenhouse gas (GHG) emissions from natural gas systems is essential for transitioning to a low-carbon economy. This work estimates the well-through-transmission GHG emissions of the US natural gas from one million active wells covering 94% of 2022 US production. This is conducted by creating a high-resolution US oil and gas production area map to harmonize oil and natural gas supply chain data. We systematically integrate methane measurement data from the latest aerial campaigns into natural gas life cycle GHG emission estimates, capturing both methane fugitive (unintentional leakage and loss) and venting (intentional release) as well as a better characterization of super-emitter activities. Over ten public and commercial industry-leading datasets are integrated with an engineering-based unit process life cycle assessment (LCA) model. The estimated total GHG emissions are 631 MMT CO₂eq, more than twice that of the US Environmental Protection Agency estimates. The average well-through-transmission carbon intensity (CI) for US natural gas is 15.46 gCO₂eq/MJ, with an upstream (exploration through processing) CI of 12.35 gCO₂eq/MJ and a midstream (transmission) CI of 3.10 gCO₂eq/MJ. Methane fugitive and venting account for 73% and 16% of the upstream CIs, respectively, an order of magnitude higher than flaring emissions (1.6%). Reducing the methane fugitive and venting loss rates by 75% would lower the upstream CI by half.