Natural Gas Liquids Production Research Articles

A comprehensive comparison of the turbo-expander, Joule-Thomson, and combination of mechanical refrigeration and Joule-Thomson processes for natural gas liquids production

Natural gas liquids production from natural gas streams is essential for energy diversification, economic development, environmental sustainability, and ensuring a stable and reliable energy supply. However, the NGL recovery process is associated with high energy consumption and significant environmental impact. This study compares three common NGL recovery processes based on turbo expander, Joule-Thomson, and combined processes through a 4E analysis approach. The 4E analysis framework includes four key aspects: environmental impact, energy consumption, exergy efficiency, and economic feasibility. By simultaneously considering these factors, a comprehensive assessment can be achieved. The specific energy consumption is optimized, and the results show that the specific energy consumption of the turbo-expander process is 164.4 % and 181.7% lower than the Joule-Thomson and combined processes, respectively. Also, the exergy efficiency for the turbo-expander, Joule-Thomson, and combined processes is 75, 71, and 60%, respectively. In addition, the ethane recovery rates for the turbo-expander, Joule-Thomson, and combined processes are 74.85%, 31%, and 69.87%, respectively. Economic analysis also indicated that the turbo-expander is more cost-effective than the other two processes, and the production cost in the turbo-expander process is lower by 45.45 and 54.54%, respectively. In addition, the turbo-expander process emits less carbon dioxide during NGL production.

Liquid hydrogen storage and regasification process integrated with LNG, NGL, and liquid helium production

Hydrogen (H2) is a clean energy carrier and has recently gained significant attention. Efforts are being made to promote liquid hydrogen (LH2) owing to its long-time storage, transportation, and high-purity end-use requirements. LH2 storage and regasification is an essential step in the H2 supply chain. This study proposes a novel integrated energy system that produces liquefied natural gas (LNG), natural gas liquids (NGL), and liquid helium (LHe) utilizing the cold energy of LH2. A well-known process simulation software (Aspen Hysys® v11) is employed to simulate the integrated process. The optimal design variables are found through the Aspen Hysys® built-in Mixed optimization technique. The optimal design shows a specific energy consumption of 0.347 kWh/kg with exergy destruction of 43.3 MW. The required volume of the spherical tank for LH2 storage is 6.3 m3. The results of the lifecycle cost analysis show that the Levelized cost of producing LNG, NGL, and LHe is 0.50 USD/kg, 0.56 USD/kg, and 98.0 USD/kg, respectively. The conclusion of this study suggests that the proposed process can improve the overall H2 supply chain by effectively utilizing LH2 for LNG, NGL, and LHe production.

World crude oil and natural gas liquids production

Oil & Energy Trends: Annual Statistical ReviewVolume 44, Issue 1 p. 23-38 Statistical Tables World crude oil and natural gas liquids production First published: 21 June 2023 https://doi.org/10.1111/oets.12137AboutPDF ToolsRequest permissionExport citationAdd to favoritesTrack citation ShareShare Give accessShare full text accessShare full-text accessPlease review our Terms and Conditions of Use and check box below to share full-text version of article.I have read and accept the Wiley Online Library Terms and Conditions of UseShareable LinkUse the link below to share a full-text version of this article with your friends and colleagues. Learn more.Copy URL Volume44, Issue1June 2023Pages 23-38 RelatedInformation

World crude oil and natural gas liquids production

Oil & Energy Trends: Annual Statistical ReviewVolume 43, Issue 1 p. 23-38 Statistical Tables World crude oil and natural gas liquids production First published: 10 July 2022 https://doi.org/10.1111/oets.12115AboutPDF ToolsRequest permissionExport citationAdd to favoritesTrack citation ShareShare Give accessShare full text accessShare full-text accessPlease review our Terms and Conditions of Use and check box below to share full-text version of article.I have read and accept the Wiley Online Library Terms and Conditions of UseShareable LinkUse the link below to share a full-text version of this article with your friends and colleagues. Learn more.Copy URL Share a linkShare onFacebookTwitterLinkedInRedditWechat Volume43, Issue1July 2022Pages 23-38 RelatedInformation

World crude oil and natural gas liquids production

World crude oil and natural gas liquids production

Alternative indicators to assess the distribution characteristics of methane, ethane, and propane derived from petroleum in the Montney Formation, Western Canada

Understanding fluid distribution within the most prolific low-permeability hydrocarbon reservoir of the Western Canadian Sedimentary Basin (WCSB), the Montney Formation, continues to be a challenge due to the complex history of hydrocarbon migration, which includes thermal alteration of hydrocarbons that migrated before maximum burial as well as more recent migration due to uplifting in the Eocene. In this study, we have assessed the occurrence of methane, ethane, and propane using parameters that are based on the possibility of molecular interconversion between C1-C3 alkanes. This approach allowed us to identify the boundary between two hydrocarbon plays within the Montney Formation based on the composition coefficient Q, and the compositional factors (C2H6)2 and (CH4).(C3H8), which are less susceptible to methane migration [particularly (C2H6)2]. One play is located primarily in Alberta and includes unconventional and conventional hydrocarbon fields; the second play is located exclusively in British Columbia and consists of unconventional hydrocarbon fields. Our new approach enables the identification of main hydrocarbon migration zones within conventional and unconventional sections (e.g. northeast, southeast, and central-west). Additionally, we used the C2/C3 ratio as a maturity indicator in the Montney Formation, which facilitates the identification of overpressure zones (to the southwest) and target areas for natural gas liquids (NGL) production (based on an estimated 1.5 %Ro). The assessment we have conducted can be further explored in other low-permeability hydrocarbon reservoirs.

Health-based evaluation of ambient air measurements of PM2.5 and volatile organic compounds near a Marcellus Shale unconventional natural gas well pad site and a school campus

BackgroundLimited air monitoring studies with long-term measurements during all phases of development and production of natural gas and natural gas liquids have been conducted in close proximity to unconventional natural gas well pads.ObjectiveConducted in an area of Washington County, Pennsylvania, with extensive Marcellus Shale development, this study investigated whether operations at an unconventional natural gas well pad may contribute to ambient air concentrations of potential health concern at a nearby school campus.MethodsAlmost 2 years of air monitoring for fine particulate matter (PM2.5) and volatile organic compounds (VOCs) was performed at three locations between 1000 and 2800 feet from the study well pad from December 2016 to October 2018. PM2.5 was measured continuously at one of the three sites using a beta attenuation monitor, while 24-h stainless steel canister samples were collected every 6 days at all sites for analysis of 58 VOCs.ResultsMean PM2.5 concentrations measured during the different well activity periods ranged from 5.4 to 9.5 μg/m3, with similar levels and temporal changes as PM2.5 concentrations measured at a regional background location. The majority of VOCs were either detected infrequently or not at all, with measurements for a limited number of VOCs indicating the well pad to be a source of small and transient contributions.SignificanceAll measurement data of PM2.5 and 58 VOCs, which reflect the cumulative contributions of emissions from the study well pad and other local/regional air pollutant sources (e.g., other well pads), were below health-based air comparison values, and thus do not provide evidence of either 24-hour or long-term air quality impacts of potential health concern at the school.

World Crude Oil and Natural Gas Liquids Production

Oil & Energy Trends: Annual Statistical ReviewVolume 41, Issue 1 p. 22-37 Statistical Tables World Crude Oil and Natural Gas Liquids Production First published: 19 August 2020 https://doi.org/10.1111/oets.12065AboutPDF ToolsRequest permissionExport citationAdd to favoritesTrack citation ShareShare Give accessShare full text accessShare full-text accessPlease review our Terms and Conditions of Use and check box below to share full-text version of article.I have read and accept the Wiley Online Library Terms and Conditions of UseShareable LinkUse the link below to share a full-text version of this article with your friends and colleagues. Learn more.Copy URL Share a linkShare onFacebookTwitterLinkedInRedditWechat Volume41, Issue1July 2020Pages 22-37 RelatedInformation

Use of exergy efficiency for the optimization of LNG processes with NGL extraction

In this paper, processes for liquefied natural gas (LNG) production with upstream or integrated natural gas liquids (NGL) removal have been optimized and compared. Since the NGL and LNG production systems use both work and heat to deliver products with different energy quality, it is challenging to measure accurately the thermodynamic efficiency by using conventional energy performance indicators. Thus, two different objective functions, specific energy consumption and exergy efficiency, have been applied in the optimization of these complex systems in order to evaluate the effectiveness of the two performance indicators. The results indicate that use of the exergy-based objective function results in a richer NGL and a larger amount of LNG production with a marginal increase in energy consumption, showing a higher thermodynamic efficiency than the result with the energy-based objective function. Besides, integrated NGL extraction shows a lower thermodynamic performance than upstream removal, indicating that further advanced schemes are required for effective integration of the NGL extraction part in the LNG process.

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Oil and Energy TrendsVolume 44, Issue 7 p. 9-10 STATISTICAL HIGHLIGHTS Crude oil and natural gas liquids production First published: 29 July 2019 https://doi.org/10.1111/oet.12719Read the full textAboutPDF ToolsRequest permissionExport citationAdd to favoritesTrack citation ShareShare Give accessShare full text accessShare full-text accessPlease review our Terms and Conditions of Use and check box below to share full-text version of article.I have read and accept the Wiley Online Library Terms and Conditions of UseShareable LinkUse the link below to share a full-text version of this article with your friends and colleagues. Learn more.Copy URL Share a linkShare onFacebookTwitterLinkedInRedditWechat No abstract is available for this article. Volume44, Issue7July 2019Pages 9-10 RelatedInformation

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Greenhouse Gas Emissions of Transportation Fuels from Shale Gas-Derived Natural Gas Liquids

Production of natural gas liquids (NGLs) in the United States is expanding rapidly and production now exceeds domestic demand. An emerging use of NGLs is the production of transportation fuels, however, the greenhouse gas (GHG) emissions of these fuels may limit their access to some markets affected by policies that consider these emissions. This work estimates well-to-tank GHG emissions of NGL-based transportation fuels and compares these estimates to GHG emissions from conventional gasoline production. The emission estimates, and their magnitude relative to well-to-tank GHG emissions for conventional petroleum fuels, are highly sensitive to NGL fuel production scenarios, co-product treatment methods, and feedstock source.

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production

Oil and Energy TrendsVolume 43, Issue 11 p. 10-11 STATISTICAL HIGHLIGHTS Crude oil and natural gas liquids production First published: 27 November 2018 https://doi.org/10.1111/oet.12628Read the full textAboutPDF ToolsRequest permissionExport citationAdd to favoritesTrack citation ShareShare Give accessShare full text accessShare full-text accessPlease review our Terms and Conditions of Use and check box below to share full-text version of article.I have read and accept the Wiley Online Library Terms and Conditions of UseShareable LinkUse the link below to share a full-text version of this article with your friends and colleagues. Learn more.Copy URL Share a linkShare onFacebookTwitterLinkedInRedditWechat No abstract is available for this article. Volume43, Issue11November 2018Pages 10-11 RelatedInformation

Crude oil and natural gas liquids production

Crude oil and natural gas liquids production