Cleaner coal and greener oil production: An integrated CCUS approach in Yanchang Petroleum Group

Wang, Xiangzeng; Zeng, Fanhua; Gao, Ruimin; Zhao, Xisen; Hao, Shiyan; Liang, Quansheng; Jiang, Shaojing

doi:10.1016/j.ijggc.2017.04.001

Cited by 43 publications

(16 citation statements)

References 2 publications

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“…Fluid injection in geological deep rocks is commonly performed for numerous purposes, such as the injection of water from the surface to produce electricity in enhanced geothermal systems (EGS; (Albaric et al, 2014;Hettkamp et al, 1998;Kraft & Deichmann, 2014;Kwiatek et al, 2014;Majer et al, 2007;Zang et al, 2017), injection of natural surface brines to prevent them from contaminating surface freshwater (King, Block, & Wood, 2016), injection of CO 2 for limiting climate change (Dempsey et al, 2014;Li et al, 2017), for enhancing oil production (Li et al, 2017;Wang et al, 2017), or the disposal of wastewater produced during the oil and gas field exploitation (Stabile et al, 2014).…”

Section: Fluid Injection and Induced Seismicitymentioning

confidence: 99%

Is There a Link Between Mineralogy, Petrophysics, and the Hydraulic and Seismic Behaviors of the Soultz‐sous‐Forêts Granite During Stimulation? A Review and Reinterpretation of Petro‐Hydromechanical Data Toward a Better Understanding of Induced Seismicity and Fluid Flow

Meller

Ledésert

2017

JGR Solid Earth

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In the framework of the European Soultz‐sous‐Forêts enhanced geothermal system (EGS) in Alsace, France, 20 years of scientific and preindustrial tests had to be performed before the site began production of electricity in 2008. Stimulation tests were designed to enhance the permeability because most of the numerous natural fractures that crosscut the granite body were sealed by secondary minerals that crystallized as an effect of the circulation of local hot brines. The deep‐seated granitic reservoir is located between 4,500 and 5,000 m depths. Hydraulic stimulations were conducted in the four deep wells (GPK1, GPK2, GPK3, and GPK4) inducing different microseismic event patterns, which cannot be explained by tectonic structures alone. In the present work, we provide a review of the hydraulic tests and reinterpret them in the light of mineralogical data obtained along the boreholes. A clear relationship appears between mineralogy (mainly clay and calcite content) and the petrophysical, mechanical, and hydraulic behaviors of the rock mass. High calcite contents are correlated with an abundance of clay minerals, low Young's modulus, low magnetic susceptibility, and variation in spectral gamma ray. Microearthquakes are generated in the fresh granite zones, while clay and calcite‐rich zones, linked with hydrothermal alteration, might behave aseismically during hydraulic stimulations. These findings highlight the importance of a detailed knowledge of the petrography of a reservoir to conduct an effective stimulation while keeping the seismic hazard at a minimum.

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Section: Fluid Injection and Induced Seismicitymentioning

confidence: 99%

Is There a Link Between Mineralogy, Petrophysics, and the Hydraulic and Seismic Behaviors of the Soultz‐sous‐Forêts Granite During Stimulation? A Review and Reinterpretation of Petro‐Hydromechanical Data Toward a Better Understanding of Induced Seismicity and Fluid Flow

Meller

Ledésert

2017

JGR Solid Earth

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“…The two-stage membrane separation process is shown in Figure 11. The flow rate of raw gas is set as 1000 Nm 3 •h −1 , and the pressure is 0.15 MPa (absolute pressure, the same below). After being compressed by the compressor, the raw gas encountered with the recycle gas was separated by the 1st-stage membrane.…”

Section: System and Simulation Condition Settingmentioning

confidence: 99%

“…Abundant low-permeability oil and gas resources are buried in petroliferous basins dominated by continental deposits [ 2 ]. According to incomplete statistics, Yanchang Oilfield is the second-largest low-permeability oilfield in China [ 3 ], with proven reserves of 1.12 × 10 8 t and an oil-bearing area of 215.5 km 2 [ 4 ]. However, most oil fields in this area are currently in the late stage of water-enhanced oil recovery.…”

Section: Introductionmentioning

confidence: 99%

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Zhang

Sheng

et al. 2021

Membranes

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CO2 enhanced oil recovery (CO2-EOR) technology is a competitive strategy to improve oil field economic returns and reduce greenhouse gas emissions. However, the arbitrary emissions or combustion of the associated gas, which mainly consists of CO2 and CH4, will cause the aggravation of the greenhouse effect and a huge waste of resources. In this paper, the high-performance facilitated transport multilayer composite membrane for CO2/CH4 separation was prepared by individually adjusting the membrane structure of each layer. The effect of test conditions on the CO2/CH4 separation performance was systematically investigated. The membrane exhibits high CO2 permeance of 3.451 × 10−7 mol·m−2·s−1·Pa−1 and CO2/CH4 selectivity of 62 at 298 K and 0.15 MPa feed gas pressure. The cost analysis was investigated by simulating the two-stage system. When the recovery rate and purity of CH4 are 98%, the minimum specific cost of separating CO2/CH4 (45/55 vol%) can be reduced to 0.046 $·Nm−3 CH4. The excellent short-to-mid-term stability indicates the great potential of large industrial application in the CH4 recovery and CO2 reinjection from oilfield associated gas.

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“…9,10 In addition, the presence of CO 2 in natural gas will reduce its calorific value, increasing the transportation cost per unit of energy. [14][15][16] In addition, flue gas CO 2 capture is undoubtedly a short-cut for the associated petroleum gas. 12,13 Among them, the mature and efficient chemical absorption method, with a high CO 2 removal efficiency and scale-up feasibility, is most commonly used.…”

mentioning

confidence: 99%

“…12,13 Among them, the mature and efficient chemical absorption method, with a high CO 2 removal efficiency and scale-up feasibility, is most commonly used. [14][15][16] In addition, flue gas CO 2 capture is undoubtedly a short-cut for the associated petroleum gas. The difference between the two methods is the influence of the characteristics of the raw material on the process parameters.…”

mentioning

confidence: 99%

Process simulation of CO₂ capture from CO₂‐EOR associated petroleum gas with aqueous MEA and MDEA solvents

Liu

Zhang

Wang

et al. 2019

Energy Science & Engineering

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Associated petroleum gas produced by CO2‐enhanced oil recovery (CO2‐EOR) has a complex composition, high CO2 content, and is unstable. To date, no integrated process simulation for CO2 capture of the EOR associated petroleum gas has been developed. Based on the analysis of the associated petroleum gas obtained from the Shengli oilfield, a new full‐simulation model of CO2 capture from 100 000 Nm3/d of the associated petroleum gas was developed for the process design of chemical absorption of blended amine solvents and an analysis of the relationship between different process parameters and the targeted result—low circulation flow and energy consumption—was performed using Aspen Plus (Version 8.6). A 90% CO2 removal rate was achieved using 0.2 mol CO2/mol of a blended amine as solvent, with an energy consumption of 3.16 GJ/tCO2. By analyzing the influence of absorption pressure, temperature, and packing height on the circulation flow, the influence of absorption and desorption pressure on the energy consumption of the system was determined. It can be concluded that the optimal parameters are as follows: packing height of absorption column, 10 m; absorption temperature, 308.15 K; desorption pressure, 0.12 MPa; and CO2 loading, 0.2 mol/mol of lean solvent, with an absorption pressure of 0.3‐0.6 MPa.

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Cleaner coal and greener oil production: An integrated CCUS approach in Yanchang Petroleum Group

Cited by 43 publications

References 2 publications

Is There a Link Between Mineralogy, Petrophysics, and the Hydraulic and Seismic Behaviors of the Soultz‐sous‐Forêts Granite During Stimulation? A Review and Reinterpretation of Petro‐Hydromechanical Data Toward a Better Understanding of Induced Seismicity and Fluid Flow

Is There a Link Between Mineralogy, Petrophysics, and the Hydraulic and Seismic Behaviors of the Soultz‐sous‐Forêts Granite During Stimulation? A Review and Reinterpretation of Petro‐Hydromechanical Data Toward a Better Understanding of Induced Seismicity and Fluid Flow

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Process simulation of CO₂ capture from CO₂‐EOR associated petroleum gas with aqueous MEA and MDEA solvents

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Cleaner coal and greener oil production: An integrated CCUS approach in Yanchang Petroleum Group

Cited by 43 publications

References 2 publications

Is There a Link Between Mineralogy, Petrophysics, and the Hydraulic and Seismic Behaviors of the Soultz‐sous‐Forêts Granite During Stimulation? A Review and Reinterpretation of Petro‐Hydromechanical Data Toward a Better Understanding of Induced Seismicity and Fluid Flow

Is There a Link Between Mineralogy, Petrophysics, and the Hydraulic and Seismic Behaviors of the Soultz‐sous‐Forêts Granite During Stimulation? A Review and Reinterpretation of Petro‐Hydromechanical Data Toward a Better Understanding of Induced Seismicity and Fluid Flow

Efficient Facilitated Transport Polymer Membrane for CO2/CH4 Separation from Oilfield Associated Gas

Process simulation of CO2 capture from CO2‐EOR associated petroleum gas with aqueous MEA and MDEA solvents

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Process simulation of CO₂ capture from CO₂‐EOR associated petroleum gas with aqueous MEA and MDEA solvents