Techno-economic analysis of potential natural gas liquid (NGL) recovery processes under variations of feed compositions

Getu, Mesfin; Mahadzir, Shuhaimi; Long, Nguyen Van Duc; Lee, Moonyong

doi:10.1016/j.cherd.2013.01.015

Cited by 71 publications

(33 citation statements)

References 4 publications

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“…Considering the limitations of existing CH 4 -NGL separation processes, we propose two process designs based on methane recovery of 86% and 96% in the demethanizer section, and they are labeled Process I and Process II, shown in Figures 3 and 4. For the 96% recovery demethanizer, a turbo-expander process scheme with a distillation column modeled using RadFrac in Aspen Plus was used [34]. For 85% recovery, cascade gas membrane separation was used, and cost calculation for this unit operation was based on a well-mixed membrane model.…”

Section: Demethanizermentioning

confidence: 99%

Valorization of Shale Gas Condensate to Liquid Hydrocarbons through Catalytic Dehydrogenation and Oligomerization

Ridha

Gençer

et al. 2018

Processes

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Abstract:The recent shale gas boom has transformed the energy landscape of the United States. Compared to natural gas, shale resources contain a substantial amount of condensate and natural gas liquids (NGLs). Many shale basin regions located in remote areas are lacking the infrastructure to distribute the extracted NGLs to other regions-particularly the Gulf Coast, a major gas processing region. Here we present a shale gas transformation process that converts NGLs in shale resources into liquid hydrocarbons, which are easier to transport from these remote basins than NGL or its constituents. This process involves catalytic dehydrogenation followed by catalytic oligomerization. Thermodynamic process analysis shows that this process has the potential to be more energy efficient than existing NGL-to-liquid fuel (NTL) technologies. In addition, our estimated payback period for this process is within the average lifetime of shale gas wells. The proposed process holds the promise to be an energy efficient and economically attractive step to valorize condensate in remote shale basins.

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Section: Demethanizermentioning

confidence: 99%

Valorization of Shale Gas Condensate to Liquid Hydrocarbons through Catalytic Dehydrogenation and Oligomerization

Ridha

Gençer

et al. 2018

Processes

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“…A mass/emissions inventory for the extraction and purification was compiled (Supplemental Material, Table S9), based on careful examination of the following sources that serve as proxies for the process:, …”

Section: Hvo Biopropane Supply Chain By Processmentioning

confidence: 99%

A carbon footprint of HVO biopropane

Johnson¹

2017

Biofuels Bioprod Bioref

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Biopropane made by hydrogenating vegetable or animal oil/fat is being commercialized as a biofuel alternative to liquefied petroleum gas (LPG). Its carbon footprint has been calculated from field to tank, using public data for each process in the supply chain, for six main feedstocks: palm oil, palm oil fatty acid distillate, tallow, used cooking oil, rape oil, and soy oil. Scenarios have been applied to the calculations using four main variables: allocation method, i.e., economic or energy; methane capture at the oil mill (or not); application of indirect land‐use change (or not); and classification of the feedstock as a residue (or not). HVO biopropane's carbon footprint varies, depending on the feedstock and the four variables, from as low as 5 g CO2e/MJ to as high as 102 g. In most cases, this qualifies for government support, i.e., financial credits and biofuel mandates enacted by EU member states under the Renewable Energy Directive. © 2017 The Authors. Biofuels, Bioproducts and Biorefining published by Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…The indirect costs include the freight, management, engineering, and other expenses. In accordance with the general chemical plant cost index (CEPCI=593.1) [14] and the annual cost of infrastructure cost formula [15] to establish a cost model, the capital cost analysis is carried out for the four types of schemes in the four kinds of feed components. A comparison of the total capital cost of each scheme is shown in Fig.…”

Section: Comparative Analysis Of Capital Costmentioning

confidence: 99%

Techno-Economic Comparison and Analysis of a Novel NGL Recovery Scheme with Three Patented Schemes

Huang¹,

Wang²,

Sun³

et al. 2017

TOPEJ

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At present, most of the light hydrocarbons (LH) separation processes that have been proposed lack the flexibility of receiving various feed components, thereby leading to an unstable operation in the liquid natural gas (LNG) receiving terminal. In response, a novel light hydrocarbons separation process (PSP) is proposed in this paper. Previously, some parameters and processes were improved upon and patented as US 7165423 B2, US 7069743 B2, and WO/2012/054729, which are respectively named as LTP, NCP, and NLP. Based on the analysis of LNG's component statistical data in China, this paper conducts a techno-economic comparison and analysis of four kinds of LH separation process under four groups of typical feed-in components. The comparison results reveal that the system energy consumption of LTP is increased by the heater, and the higher the heavy hydrocarbon content in the feed components, the more obvious the increase in the process's energy consumption is. NCP has the highest ethane recovery rate; however, its capital cost is too high, especially for the distillation column investment. NLP has the highest operating cost due to compressor use. Compared to the others, the PSP has the best economic benefit for specific performance: its capital cost is 18% less than that of NCP, its operating cost is 71.8% less than that of NLP, its net profit is 8% higher than that of NLP, its total investment cost is 71.7% lower than that of NLP, and its investment recovery period is the shortest. In conclusion, the PSP can be economically and efficiently used in China LNG receiving terminal, thereby generating the flexibility to receive multiple feed components.

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Techno-economic analysis of potential natural gas liquid (NGL) recovery processes under variations of feed compositions

Cited by 71 publications

References 4 publications

Valorization of Shale Gas Condensate to Liquid Hydrocarbons through Catalytic Dehydrogenation and Oligomerization

Valorization of Shale Gas Condensate to Liquid Hydrocarbons through Catalytic Dehydrogenation and Oligomerization

A carbon footprint of HVO biopropane

Techno-Economic Comparison and Analysis of a Novel NGL Recovery Scheme with Three Patented Schemes

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