Three considerations for modeling natural gas system methane emissions in life cycle assessment

Grubert, Emily; Brandt, Adam R.

doi:10.1016/j.jclepro.2019.03.096

Cited by 40 publications

(36 citation statements)

References 49 publications

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“…On the one hand, the characterization of methane emissions from natural gas supply chains in commonly used life cycle inventory databases is inconsistent and outdated, and likely to underestimate these emissions. [44][45][46] On the other hand, reported methane emissions from natural gas supply chains based on field measurements exhibit large variability, 41,47,48 making it difficult to select a representative "average" emission value for use in LCA calculations. Several factors contribute to real and reported variability in methane emissions from the oil and gas sector.…”

Section: ) Methane Emissions From Natural Gas Supply Chainsmentioning

confidence: 99%

“…System boundaries are relevant, because the natural gas supply chain consists of various steps from exploration to final distribution and it is sometimes unclear which of these steps are included in reported estimates. 46 In general, large-scale blue hydrogen production will be connected to the high-pressure natural gas transmission grid and therefore, methane emissions from final distribution to decentralized consumers (i.e. the lowpressure distribution network) should not be included in the quantification of climate impacts of blue hydrogen.…”

Section: ) Methane Emissions From Natural Gas Supply Chainsmentioning

confidence: 99%

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On the climate impacts of blue hydrogen production

Bauer

Treyer

Antonini

et al. 2021

Preprint

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Natural gas based hydrogen production with carbon capture and storage is referred to as blue hydrogen. If substantial amounts of CO2 from natural gas reforming are captured and permanently stored, such hydrogen could be a low-carbon energy carrier. However, recent research raises questions about the effective climate impacts of blue hydrogen from a life cycle perspective. Our analysis sheds light on the relevant issues and provides a balanced perspective on the impacts on climate change associated with blue hydrogen. We show that such impacts may indeed vary over large ranges and depend on only a few key parameters: the methane emission rate of the natural gas supply chain, the CO2 removal rate at the hydrogen production plant, and the global warming metric applied. State-of-the-art reforming with high CO2 capture rates combined with natural gas supply featuring low methane emissions does indeed allow for substantial reduction of greenhouse gas emissions compared to both conventional natural gas reforming and direct combustion of natural gas. Under such conditions, blue hydrogen is compatible with low-carbon economies and features climate change impacts in line with green hydrogen from electrolysis supplied with renewable electricity. However, neither current blue nor green hydrogen production pathways render fully “net-zero” hydrogen without additional carbon dioxide removal.

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Section: ) Methane Emissions From Natural Gas Supply Chainsmentioning

confidence: 99%

Section: ) Methane Emissions From Natural Gas Supply Chainsmentioning

confidence: 99%

On the climate impacts of blue hydrogen production

Bauer

Treyer

Antonini

et al. 2021

Preprint

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show abstract

“…We have performed density functional theory (DFT) calculations to optimize the structural models of MEA and the hydrogen disulfide with systems has been studied in the gas. All the structures were optimized B3LYP exchange-correlation functional and the 6-311 (+) G** standard basis set have been used to run all computations as implemented in the NWCHEM package [25].…”

Section: Simulation Detailsmentioning

confidence: 99%

Molecular dynamics simulation of natural gas sweetening by monoethanolamine

Novin¹,

Shameli

Balali

2020

Eurasian Chem. Commun.

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The aim of the study is to investigate sweeting process of sour gas by dynamic simulation of monoethanolamine (MEA) molecule. In the present paper using molecular dynamic simulation, the interaction of sour gas mixture included methane, ethane and H2S with MEA as absorption was also investigated the quantum method DFT B3LYP 6-311 (+) G** was used for electric charge calculation. The simulation results confirmed that the tendency of the H2S molecule is to be absorbed to amine nitrogen and oxygen hydroxyl group in MEA. No tendency for strong interaction between sulfur atoms of H2S molecule and hydrogen of amine or hydroxyl groups was observed. The investigation of changing distance between the hydrogen of H2S and nitrogen/oxygen of MEA confirmed a stable between hydrogen atoms of H2S and nitrogen/oxygen atoms in MEA. Also the investigation of distance changing show movement of hydrogen atoms of H2S molecule which interacted with MEA molecule in the time frame of the simulation. This study was observed that after absorption of H2S molecule by MEA molecules sour of them made the bridge for connection of MEA molecules with each other. Actually H2S molecules after interact with MEA molecules used addition their free hydrogen forinteraction and Making Bridge. Finally a structure of some MEA molecules are joined together, which are stable up to end of the simulation.

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“…If renewable sources of electricity were used in systems 3 and 4, they would incur minimal lifecycle CO 2 emissions . As described earlier, the methane used in system 2 could be either biogenic or fossil without incurring net carbon emissions; however, if the production of methane caused leakage, the net removal of CO 2 could be partially or completely offset . Thus, the electricity or methane required to reduce a mole of sulfate in the proposed systems is a critical variable in determining the lifecycle impacts of the systems.…”

Section: Lifecycle Emissionsmentioning

confidence: 99%

System Models of Sulfur‐, Electricity‐, and Methane‐Powered Biological Carbon Capture for Negative Emissions

Snyder

2019

Energy Tech

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Nearly every plausible emission scenario that limits climate change to less than 2 °C includes net negative global emissions in the late 21st century. These negative emissions are achieved using negative emission technologies (NETs), a diverse class of currently theoretical technologies that use energy to remove CO2 from the atmosphere. While a number of technological options are available, many of the most promising CO2 capture systems take advantage of biological systems and are thus driven by light energy. Sulfur offers an alternative energy source for biological carbon capture. Herein, system models are presented that use reduced sulfur to power marine chemosynthetic carbon capture, with four proposed alternatives for the management of the produced biomass and sulfate. These four alternatives differ in the energy and process used to reduce the sulfate produced by the growth of the microorganisms back to sulfur or sulfide and in sum, the four systems create direct air carbon capture systems that utilize either geologic reduced sulfur, electricity, or biomass as energy sources. Thus, three new energy sources for direct air carbon capture are identified.

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Three considerations for modeling natural gas system methane emissions in life cycle assessment

Cited by 40 publications

References 49 publications

On the climate impacts of blue hydrogen production

On the climate impacts of blue hydrogen production

Molecular dynamics simulation of natural gas sweetening by monoethanolamine

System Models of Sulfur‐, Electricity‐, and Methane‐Powered Biological Carbon Capture for Negative Emissions

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