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Prof. Xiuhua Zheng
China University of Geosciences (Beijing)

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0 Cement
0 Drilling Engineering
0 geological exploration
0 Geothermal engineering
0 Drilling fluid

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Research article
Published: 10 June 2021 in Journal of Dispersion Science and Technology
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The development of high-temperature and salt-resistant foaming agents is critical to the successful drilling of complex and low-pressure reservoirs. In this study, a novel alkyl glycine surfactant (AGS-8) was synthesized by the one-step method. The foam quality of AGS-8 at high temperatures (140–180 °C) and the salt solutions (5–36%wt) was evaluated by the Waring-Blender method to explore its applicability in harsh reservoirs. Results show that: (1) The successful synthesis and chemical structure of AGS-8 was determined by FTIR and 1H-NMR. (2) AGS-8 shows good thermal stability within 330 °C and has high surface activity. (3) AGS-8 generated stable foams after aging at 180 °C for 16 h. The outstanding high-temperature foam stability of AGS-8 is an important feature different from the conventional commercial foaming agents. (4) AGS-8 generated stable foams in saturated salt solution (36%wt NaCl) after 150 °C aged. A synergistic foam stabilization effect was found between high concentrations of NaCl (≥25%wt) and AGS-8. (5) The foam stabilization mechanism of AGS-8 was discussed and can be summarized as the electrostatic attraction effect of head groups and the enhancement of inter-molecular repulsive force. In conclusion, AGS-8 was found to be a promising foaming agent in the drilling of high-temperature salt-gypsum formations. Graphical Abstract

ACS Style

Wenxi Zhu; Xiuhua Zheng. Study of an anti-high-temperature and salt-resistance alkyl glycine foaming agent and its foam stabilizing mechanism. Journal of Dispersion Science and Technology 2021, 1 -12.

AMA Style

Wenxi Zhu, Xiuhua Zheng. Study of an anti-high-temperature and salt-resistance alkyl glycine foaming agent and its foam stabilizing mechanism. Journal of Dispersion Science and Technology. 2021; ():1-12.

Chicago/Turabian Style

Wenxi Zhu; Xiuhua Zheng. 2021. "Study of an anti-high-temperature and salt-resistance alkyl glycine foaming agent and its foam stabilizing mechanism." Journal of Dispersion Science and Technology , no. : 1-12.

Research article
Published: 03 May 2021 in Starch - Stärke
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Colloidal gas aphron (CGA) drilling fluid is an environmentally friendly near‐balanced drilling technology that has been successfully applied to depleted oil/gas reservoirs. To overcome the limitations of its application in high‐temperature drilling, acrylamide (AM), 2‐acrylamido‐2‐methyl‐1‐propane sulfonic acid (AMPS), and N‐vinylpyrrolidone (NVP) were grafted onto starch via inverse emulsion polymerization, and a foam stabilizer ESt‐g‐NAA with a temperature resistance of ≥150℃ was synthesized. The FT‐IR and 1H‐NMR analysis suggested that all monomers were grafted onto starch efficiently. ESt‐g‐NAA has good solubility and thermal stability, as well as an excellent ability to stabilize foams at high temperatures. Based on microscopic observation, stable aphrons were generated successfully in the CGA drilling fluid prepared by ESt‐g‐NAA and surfactant after 150℃ aged. Results show that ESt‐g‐NAA based CGA drilling fluid aged at appointed temperatures (120∼180℃) is a high‐performance drilling fluid with shear‐thinning behavior, extremely high values of LSRV, and well‐building capabilities. This article is protected by copyright. All rights reserved

ACS Style

Wenxi Zhu; Xiuhua Zheng; Jingjing Shi; Yifan Wang. Grafted Starch Foam Stabilizer ESt‐g‐NAA for High‐Temperature Resistant CGA Drilling Fluid via Inverse Emulsion Polymerization. Starch - Stärke 2021, 2000240 .

AMA Style

Wenxi Zhu, Xiuhua Zheng, Jingjing Shi, Yifan Wang. Grafted Starch Foam Stabilizer ESt‐g‐NAA for High‐Temperature Resistant CGA Drilling Fluid via Inverse Emulsion Polymerization. Starch - Stärke. 2021; ():2000240.

Chicago/Turabian Style

Wenxi Zhu; Xiuhua Zheng; Jingjing Shi; Yifan Wang. 2021. "Grafted Starch Foam Stabilizer ESt‐g‐NAA for High‐Temperature Resistant CGA Drilling Fluid via Inverse Emulsion Polymerization." Starch - Stärke , no. : 2000240.

Journal article
Published: 24 April 2021 in Journal of Petroleum Science and Engineering
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Colloidal gas aphrons (CGA) drilling fluid has been worldwide used in drilling depleted reservoirs and other under-pressured zones for its special plugging mechanism and excellent ability of lost circulation control. However, the research temperature of CGA system reported in the previous literatures is within 140 °C, and it is still an urgent challenge to promote its application in high-temperature (≥150 °C) deep wells. In this study, a novel environmentally-friendly xanthan gum derivatives XG-AA/AM/AMPS was synthesized by grafting acrylic acid (AA), acrylamide (AM), 2-acrylamido-2-methylpropane sulfonic acid (AMPS) onto XG and CGA drilling fluids with a temperature resistance of 180 °C has been successfully generated by using XG-AA/AM/AMPS as a foam stabilizer. Results presented that the XG-AA/AM/AMPS-based CGA drilling fluids can maintain reasonable rheology properties within 180 °C, i.e., significant shear thinning behavior, higher low shear rate viscosity, and apparent viscosity, and reasonable rheological parameters, which was conducive to cuttings carrying. At 140–180 °C, the filtration volume of prepared CGA fluid can be controlled within 13.5 mL. Furthermore, the high-temperature resistance mechanism of XG-AA/AM/AMPS was studied by several techniques (PSD, XRD, SEM, and polarizing microscope), which can be attributed to the dual effects of XG-AA/AM/AMPS on enhancing the dispersion of clay particles and the stability of aphrons.

ACS Style

Wenxi Zhu; Xiuhua Zheng; Jingjing Shi; Yifan Wang. A high-temperature resistant colloid gas aphron drilling fluid system prepared by using a novel graft copolymer xanthan gum-AA/AM/AMPS. Journal of Petroleum Science and Engineering 2021, 205, 108821 .

AMA Style

Wenxi Zhu, Xiuhua Zheng, Jingjing Shi, Yifan Wang. A high-temperature resistant colloid gas aphron drilling fluid system prepared by using a novel graft copolymer xanthan gum-AA/AM/AMPS. Journal of Petroleum Science and Engineering. 2021; 205 ():108821.

Chicago/Turabian Style

Wenxi Zhu; Xiuhua Zheng; Jingjing Shi; Yifan Wang. 2021. "A high-temperature resistant colloid gas aphron drilling fluid system prepared by using a novel graft copolymer xanthan gum-AA/AM/AMPS." Journal of Petroleum Science and Engineering 205, no. : 108821.

Journal article
Published: 14 April 2021 in Journal of Polymer Engineering
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Colloidal gas aphrons (CGA) are finding increasing application in depleted oil and gas reservoirs because of their distinctive characteristics. To overcome the limitations of its application in high-temperature drilling, a modified starch foams stabilizer WST with a temperature resistance of 160 °C was synthesized via radical polymerization. The chemical structure of WST was characterized by Fourier infrared spectroscopy and results showed that all three monomers acrylamide, 2-acrylamido-2-methyl-1-propane sulfonic acid, and N-vinylpyrrolidone have been grafted onto starch efficiently. Based on the microscopic observations, highly stable aphrons have been successfully generated in the WST-based CGA drilling fluids within 160 °C, and most aphrons lie in the range of 10–150 μm. WST can provide higher viscosity at high temperatures compared to xanthan gum, which helps to extend foam life and stability by enhancing the film strength and slowing down the gravity drainage. Results show that WST-CGA aged at elevated temperatures (120–160 °C) is a high-performance drilling fluid with excellent shear-thinning behavior, cutting carrying capacity, and filtration control ability. The significant improvement of filtration control and well-building capability at high temperatures is an important advantage of WST-CGA, which can be attributed to the enhancement of mud cake quality by WST.

ACS Style

Wenxi Zhu; Xiuhua Zheng. Application of modified starch in high-temperature-resistant colloidal gas aphron (CGA) drilling fluids. Journal of Polymer Engineering 2021, 41, 458 -466.

AMA Style

Wenxi Zhu, Xiuhua Zheng. Application of modified starch in high-temperature-resistant colloidal gas aphron (CGA) drilling fluids. Journal of Polymer Engineering. 2021; 41 (6):458-466.

Chicago/Turabian Style

Wenxi Zhu; Xiuhua Zheng. 2021. "Application of modified starch in high-temperature-resistant colloidal gas aphron (CGA) drilling fluids." Journal of Polymer Engineering 41, no. 6: 458-466.

Journal article
Published: 13 November 2019 in Journal of Petroleum Science and Engineering
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Colloidal Gas Aphron drilling fluids have been successfully applied in petroleum industry to drill low pressure formations and depleted reservoirs. As the increase of drilling depth and reservoir temperature, characteristics of CGA drilling fluids at high temperature are more concerned, yet less investigated. In this paper, attapulgite with better performance at high temperatures was selected to prepare CGA drilling fluids and the bubbles size distribution, rheological and fluid loss performance at 25 °C/90 °C/120 °C/150 °C/180 °C were studied. CGA fluid with Xanthan gum and 3% bentonite were prepared and tested as control group. Result indicates that: 1) The addition of attapulgite significantly reduces the average diameter of aphrons and improves the bubble size distribution of CGA fluids, which is conducive to the stability of CGA fluids; 2) Attapulgite effectively increases low shear rate viscosity (LSRV) of CGA fluid at room temperature, which will help to carry cuttings and seal formation. Power law model is the optimal model to describe the rheological behaviors of attapulgite-based CGA drilling fluids. Rheological parameters of Power law model show that the tested fluids have a shear thinning behavior at all temperatures and the flow behavior index can be controlled to an appropriate range by adjusting the amount of attapulgite; 3) Attapulgite greatly reduces the fluid loss of CGA drilling fluid, especially at high temperature. The attapulgite-based CGA drilling fluids can maintain an acceptable fluid loss (within 15 mL) for drilling operations at 120 °C. At 150/180 °C, 3% attapulgite exhibited the lowest fluid loss volume, which is reduced by 46.7%/25% as compared to 3% bentonite. In addition, the mechanism of attapulgite-based CGA fluid loss control was studied and can be concluded as the “embedded” mud cake structure composed by aphrons and attapulgite.

ACS Style

Wenxi Zhu; Xiuhua Zheng; Guomin Li. Micro-bubbles size, rheological and filtration characteristics of Colloidal Gas Aphron (CGA) drilling fluids for high temperature well: Role of attapulgite. Journal of Petroleum Science and Engineering 2019, 186, 106683 .

AMA Style

Wenxi Zhu, Xiuhua Zheng, Guomin Li. Micro-bubbles size, rheological and filtration characteristics of Colloidal Gas Aphron (CGA) drilling fluids for high temperature well: Role of attapulgite. Journal of Petroleum Science and Engineering. 2019; 186 ():106683.

Chicago/Turabian Style

Wenxi Zhu; Xiuhua Zheng; Guomin Li. 2019. "Micro-bubbles size, rheological and filtration characteristics of Colloidal Gas Aphron (CGA) drilling fluids for high temperature well: Role of attapulgite." Journal of Petroleum Science and Engineering 186, no. : 106683.

Journal article
Published: 27 September 2019 in Energies
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The flow of groundwater and the interaction of buried pipe groups will affect the heat transfer efficiency and the distribution of the ground temperature field, thus affecting the design and operation of ground source heat pumps. Three-dimensional numerical simulation is an effective method to study the buried pipe heat exchanger and ground temperature distribution. According to the heat transfer control equation of non-isothermal pipe flow and porous media, combined with the influence of permeable groundwater and tube group, a heat-transfer coupled heat transfer model of the buried pipe group was established, and the accuracy of the model was verified by the sandbox test and on-site thermal response test. By processing the layout of the buried pipe in the borehole to reduce the number of meshes and improve the meshing quality, a three-dimensional numerical model of the buried pipe cluster at the site scale was established. Additionally, the ground temperature field under the thermal-osmotic coupling of the buried pipe group during groundwater flow was simulated and the influence of the head difference and hydraulic conductivity on the temperature field around the buried pipe group was calculated and analyzed. The results showed that the research on the influence of the tube group and permeable groundwater on the heat transfer and ground temperature field of a buried pipe simulated by COMSOL software is an advanced method.

ACS Style

Xinbo Lei; Xiuhua Zheng; Chenyang Duan; Jianhong Ye; Kang Liu. Three-Dimensional Numerical Simulation of Geothermal Field of Buried Pipe Group Coupled with Heat and Permeable Groundwater. Energies 2019, 12, 3698 .

AMA Style

Xinbo Lei, Xiuhua Zheng, Chenyang Duan, Jianhong Ye, Kang Liu. Three-Dimensional Numerical Simulation of Geothermal Field of Buried Pipe Group Coupled with Heat and Permeable Groundwater. Energies. 2019; 12 (19):3698.

Chicago/Turabian Style

Xinbo Lei; Xiuhua Zheng; Chenyang Duan; Jianhong Ye; Kang Liu. 2019. "Three-Dimensional Numerical Simulation of Geothermal Field of Buried Pipe Group Coupled with Heat and Permeable Groundwater." Energies 12, no. 19: 3698.

Journal article
Published: 22 July 2019 in Energies
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Polyvinyl chloride (PVC) releases hydrochloric acid (HCl) during its thermal degradation, and hydrochloric acid can react with hydration products of alkali-activated binders. According to this characteristic of PVC and the temperature change that occurs during the development of a geothermal well, the PVC was added into slag/fly ash binder to develop self-degradable materials. The thermal degradation properties of PVC, compressive strength, hydration products, and microstructure of binders at different stages were tested, in order to study the degradation mechanism of the material. It was found that 20% PVC reduced the compressive strength, decreasing the level of binder from 13.95% to 76.63%. The mechanism of PVC promoting the material degradation mainly includes the following: (1) the thermal degradation of PVC increases the number of multiple damage pores in the material, at a high temperature; (2) HCl generated by the PVC thermal degradation reacts with the binder gels, and breaks them into particles; and (3) HCl also reacts with other substances in the binder, including CaCO3 and NaOH in the pore solution.

ACS Style

Huijing Tan; Xiuhua Zheng; Long Chen; Kang Liu; Wenxi Zhu; Bairu Xia. The Self-Degradation Mechanism of Polyvinyl Chloride-Modified Slag/Fly Ash Binder for Geothermal Wells. Energies 2019, 12, 2821 .

AMA Style

Huijing Tan, Xiuhua Zheng, Long Chen, Kang Liu, Wenxi Zhu, Bairu Xia. The Self-Degradation Mechanism of Polyvinyl Chloride-Modified Slag/Fly Ash Binder for Geothermal Wells. Energies. 2019; 12 (14):2821.

Chicago/Turabian Style

Huijing Tan; Xiuhua Zheng; Long Chen; Kang Liu; Wenxi Zhu; Bairu Xia. 2019. "The Self-Degradation Mechanism of Polyvinyl Chloride-Modified Slag/Fly Ash Binder for Geothermal Wells." Energies 12, no. 14: 2821.

Article
Published: 16 June 2018 in Journal of Earth Science
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The exploitation of thermal water and the mix of cold water changed the properties of geofluid in shallow reservoir, which altered the concentration of the chemical constitutes and continuously built new water-rock reaction. This paper deduced reservoir pressure and temperature variation tendency from 2004 to 2013, analyzed the change of some components in the shallow reservoir water, and finally obtained the evolution of the shallow geothermal water with hydrogeochemical model. The results show the reservoir pressure decreased significantly compared with the slight decline of reservoir temperature, and much cold groundwater infiltrated into the shallow reservoir, which affected the solubility of SiO2 and led to precipitation, the increased CO2 in shallow reservoir promoted the dissolution of aluminosilicate. Calcite and kaolinite precipitation zone has extended to the north in the field, which influenced the porosity of the reservoir rock.

ACS Style

Xiuhua Zheng; Chenyang Duan; Bairu Xia; Yong Jiang; Jian Wen. Hydrogeochemical Modeling of the Shallow Thermal Water Evolution in Yangbajing Geothermal Field, Tibet. Journal of Earth Science 2018, 30, 870 -878.

AMA Style

Xiuhua Zheng, Chenyang Duan, Bairu Xia, Yong Jiang, Jian Wen. Hydrogeochemical Modeling of the Shallow Thermal Water Evolution in Yangbajing Geothermal Field, Tibet. Journal of Earth Science. 2018; 30 (4):870-878.

Chicago/Turabian Style

Xiuhua Zheng; Chenyang Duan; Bairu Xia; Yong Jiang; Jian Wen. 2018. "Hydrogeochemical Modeling of the Shallow Thermal Water Evolution in Yangbajing Geothermal Field, Tibet." Journal of Earth Science 30, no. 4: 870-878.

Journal article
Published: 20 July 2017 in Energies
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An urgent problem of geothermal energy source development is how to cut down the production costs. The use of temporary sealing materials can reduce the costs associated with the circulation lost by plugging, and increase the production by self-degradation. Based on the utilization of starches as self-degradable additives in the medical field, this paper investigated the effects of three kinds of starches, namely corn starch (CS), hydroxypropyl starch (HPS) and carboxymethyl starch (CMS) on the properties of alkali-activated cement (AAC). In addition, the thermal properties of starch, the compressive strength and microstructures of the cement with starch were tested, to evaluate the potentiality of starch as self-degradable additive for geothermal cement. The analysis showed that: (1) all the starches have the effect of increasing the apparent viscosity, prolonging the setting time and reducing the static fluid loss of alkali-activated cement; (2) the addition of starch increased the number of pores in 200 °C-heated cement, facilitated the leaching process, and thus promoted the self-degradation; and (3) among the three starches, CMS has the most potential as a self-degradable additive.

ACS Style

Huijing Tan; Xiuhua Zheng; Limenglu Ma; Haixiao Huang; Bairu Xia. A Study on the Effects of Starches on the Properties of Alkali-Activated Cement and the Potential of Starch as a Self-Degradable Additive. Energies 2017, 10, 1048 .

AMA Style

Huijing Tan, Xiuhua Zheng, Limenglu Ma, Haixiao Huang, Bairu Xia. A Study on the Effects of Starches on the Properties of Alkali-Activated Cement and the Potential of Starch as a Self-Degradable Additive. Energies. 2017; 10 (7):1048.

Chicago/Turabian Style

Huijing Tan; Xiuhua Zheng; Limenglu Ma; Haixiao Huang; Bairu Xia. 2017. "A Study on the Effects of Starches on the Properties of Alkali-Activated Cement and the Potential of Starch as a Self-Degradable Additive." Energies 10, no. 7: 1048.

Journal article
Published: 23 February 2017 in Energies
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The accurate control of the wellbore pressure not only prevents lost circulation/blowout and fracturing formation by managing the density of the drilling fluid, but also improves productivity by mitigating reservoir damage. Calculating the geothermal pressure of a geothermal well by constant parameters would easily bring big errors, as the changes of physical, rheological and thermal properties of drilling fluids with temperature are neglected. This paper researched the wellbore pressure coupling by calculating the temperature distribution with the existing model, fitting the rule of density of the drilling fluid with the temperature and establishing mathematical models to simulate the wellbore pressures, which are expressed as the variation of Equivalent Circulating Density (ECD) under different conditions. With this method, the temperature and ECDs in the wellbore of the first medium-deep geothermal well, ZK212 Yangyi Geothermal Field in Tibet, were determined, and the sensitivity analysis was simulated by assumed parameters, i.e., the circulating time, flow rate, geothermal gradient, diameters of the wellbore, rheological models and regimes. The results indicated that the geothermal gradient and flow rate were the most influential parameters on the temperature and ECD distribution, and additives added in the drilling fluid should be added carefully as they change the properties of the drilling fluid and induce the redistribution of temperature. To ensure the safe drilling and velocity of pipes tripping into the hole, the depth and diameter of the wellbore are considered to control the surge pressure.

ACS Style

Xiuhua Zheng; Chenyang Duan; Zheng Yan; Hongyu Ye; Zhiqing Wang; Bairu Xia. Equivalent Circulation Density Analysis of Geothermal Well by Coupling Temperature. Energies 2017, 10, 268 .

AMA Style

Xiuhua Zheng, Chenyang Duan, Zheng Yan, Hongyu Ye, Zhiqing Wang, Bairu Xia. Equivalent Circulation Density Analysis of Geothermal Well by Coupling Temperature. Energies. 2017; 10 (3):268.

Chicago/Turabian Style

Xiuhua Zheng; Chenyang Duan; Zheng Yan; Hongyu Ye; Zhiqing Wang; Bairu Xia. 2017. "Equivalent Circulation Density Analysis of Geothermal Well by Coupling Temperature." Energies 10, no. 3: 268.

Journal article
Published: 14 October 2016 in Energies
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In consideration of the insolubility in water, sensitivity to heat and wide application in the oil and gas industry as a degradable additive, this paper introduces polylactic acid (PLA) to a self-degradable temporary sealing material (SDTSM) to investigate its effect on the SDTSM performance and evaluate its potential to improve the rheological properties and further promote the self-degradation of the material. The thermal degradation of PLA, the rheological properties, compressive strength, hydrated products and water absorption of SDTSMs with different PLA dosages were tested. The analysis showed that the addition of 2% PLA increased the fluidity by 13.18% and reduced the plastic viscosity by 38.04%, when compared to those of the SDTSM without PLA. PLA increased the water absorption of 200 °C-heated SDTSM and had small effect on the types but decreased the hydrate products of 85 °C-cured SDTSM, and created plenty of pores in 200 °C-heated SDTSM. PLA enhanced the self-degradation level of SDTSM by generating a large amount of pores in cement. These pores worked in two ways: one was such a large amount of pores led to a looser microstructure; the other was these pores made the water impregnate the cement more easily, and then made the dissolution of substances in the 200 °C-heated SDTSM progress faster to generate heat and to destruct the microstructure.

ACS Style

Huijing Tan; Xiuhua Zheng; Chenyang Duan; Bairu Xia. Polylactic Acid Improves the Rheological Properties, and Promotes the Degradation of Sodium Carboxymethyl Cellulose-Modified Alkali-Activated Cement. Energies 2016, 9, 823 .

AMA Style

Huijing Tan, Xiuhua Zheng, Chenyang Duan, Bairu Xia. Polylactic Acid Improves the Rheological Properties, and Promotes the Degradation of Sodium Carboxymethyl Cellulose-Modified Alkali-Activated Cement. Energies. 2016; 9 (10):823.

Chicago/Turabian Style

Huijing Tan; Xiuhua Zheng; Chenyang Duan; Bairu Xia. 2016. "Polylactic Acid Improves the Rheological Properties, and Promotes the Degradation of Sodium Carboxymethyl Cellulose-Modified Alkali-Activated Cement." Energies 9, no. 10: 823.