1,720,972 research outputs found
Replication Data for: "Repeated Leak Detection and Repair Surveys Reduce Methane Emissions Over Scale of Years"
No full textThis dataset provides all the raw data collected as part of the field study associated with the paper: "Repeated Leak Detection and Repair Surveys Reduce Methane Emissions Over Scale of Years". The data provided here can be used to replicate all results presented in the manuscript
Replication Data for: Global Liquefied Natural Gas Industry Expansion May Imperil Paris Agreement Temperature Targets
No full textDataset description: Primary database of LNG export and import terminals around the world curated from publicly available sources such as government agency reports, non-governmental organization reports, public announcements, and peer-reviewed studies. The data provided here include existing, under-construction, approved, and proposed LNG infrastructure projects and underlies the analysis presented in the paper "Global Liquefied Natural Gas Industry Expansion May Imperil Paris Agreement Temperature Targets" by Yang et al
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Global dynamics of blue and green hydrogen production : comparative analysis and a multi-criteria decision-making framework for feasibility assessment
Full text linkGlobal efforts to address climate change have converged on a target of achieving net-zero greenhouse gas emissions by mid-century. In this context, hydrogen has emerged as a key solution to decarbonize hard-to-abate sectors such as iron and steel or shipping. Unsurprising, several countries around the world have announced plans, policies, and investments to support a low-carbon hydrogen economy. Whether these initiatives and policy support can sustain a local hydrogen ecosystem in the long-term is unclear. Deploying and growing a hydrogen supply chain at scale depends on a number of factors beyond limited policy support or initial investment. Under limited budgets and competing priorities, how can countries and lending institutions choose which hydrogen production projects to invest in? This study introduces a multi-criteria decision-making framework that broadly evaluates the role of various technical, socio-economic, and environmental factors across different countries in sustainably producing blue or green hydrogen. We use this framework to comparatively assess the potential for blue and green hydrogen production in several candidate countries with diverse economic, environmental, and social circumstances: the United States of America (USA), Brazil, Argentina, Chile, Saudi Arabia, China, India, South Korea, Kazakhstan, the European Union (EU) and Nigeria. The findings reveal notable variability in the feasibility of blue or green hydrogen production across these countries. We show that relying solely on technical feasibility such as the availability of gas reserves or solar power potential is insufficient to reliably assess the feasibility of a domestic hydrogen economy, as evidenced by the scenarios in Brazil and China for green and blue hydrogen, respectively. The novelty of this work lies in its integration of qualitative and quantitative metrics to comprehensively compare the potential for blue and green hydrogen production globally. Policymakers and industry practitioners within countries or regions can use this study to formulate hydrogen strategies that are tailored to their unique circumstances and resources. Global lending institutions could also incorporate this framework as a screening criterion to optimally allocate funds to the most feasible projects within specific countries or regions.Petroleum and Geosystems Engineerin
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Global comparative analysis of decarbonization potential in hard-to-abate sectors using hydrogen
No full textSteel production, electricity generation, and transportation are hard-to-abate sectors largely contributing to global greenhouse gas emissions due to the current reliance on fossil fuels and high emission intensity of the current technologies employed in each respective sector. With nations pledging to combat climate change and reach net-zero emissions, alternative fuels such as hydrogen gained significant interest for decarbonization. Hence, countries around the globe announced policies and projects to expedite decarbonizing hard-to-abate sectors and scale-up hydrogen production. However, which sector should be prioritized to incorporate hydrogen as decarbonizing solution in competing economies? Through a global compressive comparative analysis, this study evaluates multiple hydrogen production pathways decarbonization potential in the steel, electricity generation, and transportation sectors using country-specific data. 15 countries were selected in this study to show regional variability, diverse energy mix, difference in available resources, GDP and GDP per capita along with interest in hydrogen through announced policies and projects. The countries selected are: South Africa, Morocco, Saudi Arabia, Mexico, South Korea, Chile, Italy, Brazil, France, India, Japan, China, United States, Germany, and Australia. Our results suggest that hydrogen utilization in each sector should be tailored for each country’s current situation. In our analysis, for example, we demonstrate how hydrogen utilization scenarios in steel making show an increase in overall emissions in nations with low Electric Arc Furnace (EAF) steel production emission intensity such as the United States and France. In addition, we showcase how nations should consider blending green hydrogen with natural gas to achieve impactful emission reduction in natural gas electricity generation. Moreover, we show that all hydrogen fuel cell electric vehicles light-duty vehicles reduce transportation associated emissions except when using grey hydrogen in nations with low annual mileage and high fuel economy, evidenced by the grey hydrogen scenario in Japan. This study serves as a guide for governments and policymakers to target impactful decarbonization in hard-to-abate sectors using hydrogen as well as select the best hydrogen production pathway to reach their emission reduction targets.Petroleum and Geosystems Engineerin
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Spatiotemporal variation in anthropogenic methane emissions in the Appalachian Basin
Full text linkReduction of anthropogenic methane emissions is crucial for climate change mitigation efforts. The variability and intermittency of methane emission sources present significant challenges in accurately assessing true inventory estimates. While numerous studies have provided insights into anthropogenic methane emissions from specific sources such as oil and gas facilities, coal mines, and landfills, a comprehensive analysis encompassing all these sources in a single study appears to be lacking in the current literature. As the first step, this thesis introduces a novel non-spatial workflow to empirically characterize methane emissions from diverse anthropogenic sources, including underground coal mines, oil and gas sites, landfills, and concentrated animal feedlot operations. Next, the developed workflow is applied to propose the adaptation of geostatistical and spatial statistics methods, incorporating variogram modeling, to objectively assess the stationarity of available methane emissions data. The results derived from this two-fold analysis can be utilized to enhance the description of the complex spatiotemporal distribution of anthropogenic methane emissions, thereby informing more accurate policy modeling and climate change mitigation strategies.Petroleum and Geosystems Engineerin
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Reconciling bottom-up and top-down methane emission estimates at midstream natural gas facilities : a Bayesian probabilistic approach
No full textAccurately quantifying methane emissions from natural gas infrastructure is a critical focus of anthropogenic emission reduction efforts, yet significant discrepancies persist between bottom-up (BU) inventory methods and top-down (TD) measurements. Previous reconciliation efforts have been limited by their reliance on comparing mean values of BU and TD estimates, which neglects the full inherent uncertainty in both approaches. In this work, we present a comprehensive probabilistic framework for reconciling BU and TD estimates at midstream oil and gas facilities. By incorporating uncertainty in both BU and TD estimates using statistical bootstrapping, quantile regression, and Monte-Carlo simulation, we generate and compare distributions for reconciling TD-BU discrepancies. We find that while the median TD estimate can be higher than the median BU estimate, there is significant overlap in their distributions, particularly when comparisons are temporally matched. Furthermore, we introduce a Bayesian approach to incorporate source-matched, TD measurement data into BU estimates to derive posterior BU emission inventory distributions. This allows for the use of empirical information to continuously improve measurement informed inventories while limiting the impact of potentially inaccurate TD measurements. We find that a single Bayesian update of prior BU distributions reduces the gap between median BU and TD estimates by over 50% on average. Methods outlined here provide a practical and quantitative framework for emissions reconciliation across the oil and gas supply chain.Petroleum and Geosystems Engineerin
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Geospatial life cycle assessment of blue hydrogen production pathways : case study of the Marcellus shale and Permian basin
Full text linkBlue hydrogen is considered one of the numerous potential pathways to achieve net-zero climate targets for a decarbonized world. While recent studies have shown a wide range in greenhouse gas (GHG) emission impact of blue hydrogen, geospatial differences remain unclear. This is especially important as recent studies have shown significant differences in methane emissions across oil and gas basins, facility types, and operators. This work develops a geospatial life cycle assessment (LCA) model to estimate GHG emissions of different blue hydrogen production pathways. Two case studies are evaluated: blue hydrogen production in Texas with gas from the Permian basin, and in Ohio with gas from the Marcellus shale. The main finding is that producing hydrogen from Permian basin-derived gas has life cycle GHG emissions intensity of ~7.4 kg CO₂e/kg H₂, which is more than twice the emissions intensity associated with blue hydrogen production using natural gas sourced from the Marcellus shale (~3.3 kg CO₂e/kg H₂). Recently, the Inflation Reduction Act in the United States includes tax credit provisions for hydrogen production based on achieving life cycle emissions intensity below 4 kg CO₂e/kg H₂. The results from this work indicate that only one of these U.S. case scenarios might qualify as low-carbon hydrogen without further reduction in methane leakage or increase in carbon capture rate when a full life cycle assessment from the well to the carbon capture and storage (CCS) facility is considered. The impacts of methane leakage rate and carbon capture efficiency are investigated through a sensitivity analysis to develop benchmarks for hydrogen production that would qualify for the tax credit. Finally, this research provides insights into the environmental implications of blue hydrogen compared to other low-carbon hydrogen production technologies such as green hydrogen.Petroleum and Geosystems Engineerin
Going Beyond Counting First Authors in Author Co-citation Analysis
Full text linkThe present study examines one of the fundamental aspects of author co-citation analysis (ACA) - the way co-citation
counts are defined. Co-citation counting provides the data on which all subsequent statistical analyses and mappings
are based, and we compare ACA results based on two different types of co-citation counting - the traditional type that
only counts the first one among a cited work's authors on the one hand and a non-traditional type that takes into
account the first 5 authors of a cited work on the other hand. Results indicate that the picture produced through this non-traditional author co-citation counting contains more coherent author groups and is therefore considerably clearer. However, this picture represents fewer specialties in the research field being studied than that produced through the traditional first-author co-citation counting when the same number of top-ranked authors is selected and analyzed. Reasons for these effects are discussed
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Evaluating the implications of accurate methane emissions reporting on the waste emissions charge in the Inflation Reduction Act
Full text linkAddressing methane emissions in the oil and gas industry is an important component of global climate action because methane is a potent, short-term climate pollutant. Effective mitigation of methane emissions requires accurate emissions accounting. In 2023, the U.S. Environmental Protection Agency (EPA) released the proposed Greenhouse Gas Reporting Program (GHGRP) regulations, which includes amendments to rules that describe methods for reporting methane emissions from oil and gas facilities. Recent measurements have found that methane emissions in oil and gas industry are greater than reported emissions, leading to an undercounting of the total methane emissions for the U.S. The proposed regulations update emissions factors and equations used in reporting, add new emission source categories, and new or revised reporting methods, such as the “other large release events.” In this work, I analyze and compare methane emissions estimates using engineering calculations from an upstream natural gas operator using the previous and proposed EPA GRHRP regulations. I consider these estimates and the implications for the methane waste emissions charge in the Inflation Reduction Act of 2022. I find mixed effects. The proposed changes will lead to increases in reported emissions, such as in the reporting categories for malfunctioning intermittent pneumatic bleed devices and two-stroke lean-burn reciprocating internal combustion engines. In other categories the changes will reduce reported emissions, such as in the reporting categories for properly operating intermittent bleed pneumatic devices and four-stroke rich-burn engines. The proposed changes will also change the overall emissions intensity for the company’s operations. Evaluating the implications for the proposed GHGRP regulations is important to understand for the updated reporting requirements as well as the methane fee and the potential climate benefits for reducing methane emissions in the oil and gas industry.Energy and Earth Resource
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