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research on the influence of geological factors on casing stress in casing-in-casing cementing in the horizontal section of shale gas wells

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Journal of engineering and Applied Science 2024年第1期71卷 79页

作者： Zheng, Youzhi Zhao, Jun Hu, Xihui Li, Zhilin Zhang, Zhanwu Guo, Ziming He, Yu He, Lang Chen, Yong Xie, Yi Engineering Technology Research Institute PetroChina Southwest Oil and Gas Field Company Deyang China Science and Technology Information Department CNPC Chuanqing Drilling Engineering Company Limited Islamabad Pakistan School of Mechatronic Engineering Southwest Petroleum University Chengdu610500 China

Deep shale gas development has great potential, but the frequent occurrence of shale gas well casing change problems triggered by geological factors seriously restricts deep shale gas development. In order to investigate the influence of geological factors on the casing stress of the cemented casing in the sleeve, a model of formation-cement sheath-double casing assemblage was established, and the influence of three-way geostress and fault slip on the casing stress of the casing-in-casing cementing was investigated by using finite element analysis. The results show the following: the smaller the difference between the vertical geostress and the maximum horizontal geostress is, the lower the equivalent force on the casing is, and when the difference gradually decreases from 20 to 7 MPa, the maximum equivalent force of the inner casing under fracturing condition decreases by 9.4%;the increase of the minimum horizontal geostress leads to the increase of the equivalent force of the inner and outer casing. When the minimum horizontal stress gradually increases from 80 to 90 MPa, the maximum equivalent force of the inner casing under fracturing condition increases by 5.9%. The larger the fault slip and the fault angle, the larger the equivalent force generated on the casing. The shear resistance of the double-layer casing is significantly greater than that of the single-layer casing, with an average increase in fault slip distance that can be withstood of about 45.25% and 40.2% in the no internal pressure and fracturing conditions. The larger the casing steel grade and the thicker the wall thickness, the higher the shear resistance. It is recommended to reduce placing of wells in areas where the difference between the vertical and maximum horizontal ground stresses is large, and at locations where the fault slip angle is large, and to use both higher steel grades and larger wall thicknesses of casing. This research result demonstrates the feasibility of "milling + casing-

关键词： Gases

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The Successful Application of Expansion Tube technology in the Bongor Basin of Chad 13th

The Successful Application of Expansion Tube Technology in t...

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13th International Field Exploration and development Conference, IFEDC 2023

作者： Zhong, Zhao Li, Xiao-Gang Liu, Ji-Tong Ji, Fei Li, Gang-Lu Jia, Tao Liu, Chen-Chao Zhang, Guo-Bin Liu, Shan-Shan CNPC Engineering Technology R&D Company Limited Beijing102206 China China National Oil and Gas Exploration and Development Corporation Beijing100034 China CNPC Bohai Drilling Engineering Company Limited Tianjin300452 China

ISBN: (纸本)9789819702558

The Bongor is the main basin for increasing storage and production in the cnpc Chad. With the continuous deepening of development, underground safety operations face the following problems: the inability to effectively seal the gas layer in the overlying strata of the basement, the high risk of secondary completion of the basement gas injection well, and the poor stability of the wellbore in the M group shale formation. In response to the bottleneck problems faced by underground operations, geological, drilling, logging, and other data were analyzed and sorted. Based on the expansion tube technology, the safety sealing technology for high-pressure gas cap in basement, secondary completion technology for basement gas injection wells, and openhole sealing technology for expansion tubes were optimized and formed. They were successfully applied for the first time in the Bongor Basin, achieving a daily gas injection volume of 2000 Nm3, shortening the construction cycle, improving wellbore quality, and reducing complex underground risks, Subsequently, it will be widely promoted and applied as a mature technology, supporting the efficient development of the Bongor Basin. At the same time, the expansion tube technology has a demonstration effect on the development of similar oil fields due to its good practical functions and application value [1–6]. © The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd. 2024.

关键词： Gases

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Synthesis and Properties of a Gemini Quaternary Ammonium Surfactant for Depressurization and Increasing Injection 12th

Synthesis and Properties of a Gemini Quaternary Ammonium Sur...

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12th International Field Exploration and development Conference, IFEDC 2022

作者： Zhang, Gui-Qing Hao, Zhi-Wei Li, Lun CNPC Engineering Technology Research Company Limited Tianjin China CNPC Key Laboratory of Offshore Engineering Tianjin China

ISBN: (纸本)9789819919635

Aiming at the problems of high water injection pressure and insufficient water injection in high temperature and low permeability reservoirs, a Gemini quaternary ammonium surfactant was synthesized from oleic acid and aminopropyl tertiary amine, and its properties were evaluated. The effect of the surfactant on the oil-water interfacial tension and contact angle was studied, and the additives compatible with the surfactant, scale inhibitor and antiswelling agent, were selected to reduce the influence of formation water scaling and clay mineral expansion on permeability. The temperature resistance and pressure reduction rate of the depressurization and injection system composed of the surfactant and two additives were evaluated. The results show that the oil-water interfacial tension can be reduced to less than 0.01 mN/m when the dosage of the surfactant reaches 0.2%. After the surfactant is adsorbed, the rock surface changes from water-based wetting to neutral wetting, which reduces the influence of capillary force on the seepage of injectedwater. The depressurization and injection system ismixed with spent acid without stratification and precipitation, and can be used to prolong the low-pressure water injection time after acidification. After aging at 130 °C for 24 h, the performance of the system is basically the same as that before aging. The core displacement experiment shows that after injecting the surfactant, the water injection pressure decreases by 35%, which means that the surfactant has a good application prospect in reducing the water injection pressure and improving the water absorption capacity of high temperature and low permeability reservoirs. © The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd. 2023.

关键词： Wetting

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Modeling analysis of cobalt-based Fischer-Tropsch catalyst particles

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Chinese Journal of Chemical engineering 2024年第6期70卷 82-92页

作者： Huashuai Wu Gang Wang Yong Yang Yongwang Li College of Chemical Engineering and Technology Taiyuan University of TechnologyTaiyuan 030024China National Energy Research&Development Center for Coal to Liquid Fuels Synfuels China CompanyLimitedBeijing 101400China

The influences of particle size,shape,and catalyst distribution on the reactivity and hydrocarbon product selectivity of a cobalt-based catalyst for Fischer-Tropsch synthesis were investigated in the present work.A self-consistent kinetic model for Fischer-Tropsch reaction proposed here was found to correlate experimental data well and hence was used to describe the consumption rates of reactants and formation rates of hydrocarbon *** perturbed-chain statistical associating fluid theory equation of state was used to describe vapor-liquid equilibrium behavior associated with Fischer-Tropsch *** interaction between intraparticle diffusion and Fischer-Tropsch reaction was investigated in *** showed that in order to avoid the adverse influence of intraparticle diffusional limitations on catalyst reactivity and product selectivity,the use of small particles is *** eggshell spherical particles are shown to keep the original catalyst reactivity and enhance the selectivity of heavy hydrocarbon *** suitable layer thickness for a spherical particle with a diameter of 2 mm is nearly 0.15 *** the same outer diameter of 2 mm,the catalyst reactivity and heavy product selectivity of hollow cylindrical particles with a layer thickness of 0.25 mm are found to be larger than eggshell spherical *** the viewpoint of catalytic performance,hollow cylindrical particles are a better choice for industrial applications.

关键词： Fischer-Tropsch synthesis Kinetic modeling Vapor-liquid equilibria Numerical simulation Intraparticle diffusion Particle shapes

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Dynamic and static Biot's coefficient of transversely isotropic Longmaxi shale 58

Dynamic and static Biot's coefficient of transversely isotro...

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58th US Rock Mechanics / Geomechanics Symposium 2024, ARMA 2024

作者： Jia, Lichun Deng, Hu Xu, Qicong Xu, Wen Li, Lei Li, Luchun Drilling & Production Technology Research Institute of CNPC Chuanqing Drilling Engineering Company Limited Sichuan Chengdu China

ISBN: (纸本)9798331305086

In this work, the dynamic and static Biot's coefficients and elastic parameters of Longmaxi black shale are investigated by using acoustic measurement and triaxial compression tests. The results firstly show that the dynamic and static elastic stiffness, Young's modulus both increase with confining pressure, and the dynamic results is higher than the corresponding static values. The Young's modulus parallel to bedding is higher than that of perpendicular to bedding. However, the Poisson's ratio has no significant rule with confining pressure and bedding direction. Secondly, the dynamic and static Biot's coefficients decrease with confining pressure. And the Biot's coefficients perpendicular to bedding are higher than those parallel to bedding. Moreover, the static Biot's coefficients are higher than the dynamic results. Finally, there is a linear relationship between dynamic and static Biot's coefficients and Young's modulus, respectively. The anisotropic Biot's coefficient and the dynamic to static conversion could improve the accuracy of geomechanical analysis in Longmaxi shale. Copyright 2024 ARMA, American Rock Mechanics Association.

关键词： Rock mechanics

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Numerical Investigation of Combined Production of Natural Gas Hydrate and Conventional Gas

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Fluid Dynamics & Materials Processing 2024年第3期20卷 505-523页

作者： Hongzhi Xu Jian Wang Shuxia Li Fengrui Zhao Chengwen Wang Yang Guo School of Petroleum Engineering China University of Petroleum(East China)Qingdao266580China CPOE Research Institute of Engineering Technology Tianjin300451China CNPC Offshore Engineering Company Limited Beijing100028China

Natural gas hydrate(NGH)is generally produced and accumulated together with the underlying conventional ***,optimizing the production technology of these two gases should be seen as a relevant way to effectively reduce the exploitation cost of the gas *** this study,three types of models accounting for the coexistence of these gases are *** A considers the upper hydrate-bearing layer(HBL)adjacent to the lower conventional gas layer(CGL);with the Type B a permeable interlayer exists between the upper HBL and the lower CGL;with the type C there is an impermeable interlayer between the upper HBL and the lower *** production performances associated with the above three models are calculated under different conditions,including only a depressurized HBL(only HBL DP);only a depressurized CGL(only CGL DP);and both the HBL and the CGL being depressurized(HBL+CGL DP).The results show that for Type A and Type B coexistence accumulation models,when only HBL or CGL is depressurized,the gas from the other layer will flow into the production layer due to the pressure difference between the two *** the coexistence accumulation model of type C,the cumulative gas production is much lower than that of Type A and Type B,regardless of whether only HBL DP,only CGL DP,or HBL+CGL DP are *** indicates that the impermeable interlayer restricts the cross-flow of gas between HBL and *** three different coexistence accumulation models,CGL DP has the largest gas-to-water ratio.

关键词： Natural gas hydrate conventional gas coexistence accumulation depressurization combined production

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Dolomitization Model of Pelletoid of Arab C Formation in Southern Arabian Gulf 84

Dolomitization Model of Pelletoid of Arab C Formation in Sou...

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84th EAGE Annual Conference and Exhibition

作者： Li, F. Ye, Y. Li, L. Wan, Y. Research Institute of Petroleum Exploration and Development Petrochina China CNPC Engineering Technology R&D Company Limited China

ISBN: (纸本)9781713884156

Dolomitization is the main geological process that turn pelletoid into dolomites. How does dolomitization convert pelletoid into dolomites? Why do dolomites have different structures and crystals? This paper mainly answers these two questions. Based on core, cast thin sections, physical property and mercury intrusion, the Pelletoid types are first determined. Secondly, the diagenesis of the Pelletoid is comprehensively recognized, including the diagenetic types, diagenetic environment and diagenetic product. Finally, the dolomitization model of Pelletoid is established. There are four types dolomite in Arab C formation in BH oilfield. The Arab C Formation was in a tidal flat environment, in which facies include supratidal, intertidal and subtidal. Different facies have different water energy, lithology, exposure probability and time, as a result, the diagenesis such as gypsification, dolomitization, dissolution and cementation in different area vary greatly. That’s why there are four type of dolomite even the primitive particles are the same pelletoids. The pelletoids were mainly in the intertidal facies, subtidal facies with relatively high energy could also developed. Intertidal facies was easy to exposure, and gypsification and dolomitization was intense in penecontemporaneous stage. Due to the environment difference, response to sea level fluctuation and exposure time, the diagenesis, especially the extent of dolomitazition is different. As a result, the dolomite has different character in structure and crystal. © (2023) by the European Association of Geoscientists & Engineers (EAGE). All rights reserved.

关键词： Dolomite

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New Understanding of Matrix-Fracture Dual Media Reservoir Damage Based on Pressure-Controlled Fracturing 58

New Understanding of Matrix-Fracture Dual Media Reservoir Da...

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58th US Rock Mechanics / Geomechanics Symposium 2024, ARMA 2024

作者： Zhang, Yang Qiao, Yan Zhang, Shiling Wu, Hongjun Bai, Jie Guo, Xudong Li, Senmu CNPC Engineering Technology R&D Company Limited BeiJing China Research Institute of Petroleum Exploration & Development BeiJing China PetroChina Tuha Oilfield Company HaMi China

ISBN: (纸本)9798331305086

The Tarim Oilfield Krasu tectonic zone is deeply burial, high temperature, low porosity and permeability, and constitutes the complex matrix-fracture dual media seepage channels. Reservoir damage evaluation for such reservoirs is important for subsequent development. In this study, we firstly processed the fracture network in the reservoir core by controlled-pressure fracturing to improve the fracture tortuosity, and verified the reasonableness of this method by CT scanning and shape factor calculation. Then, based on the dual-media condition, we establish the water/oil-lock damage evaluation method, the stress-sensitive evaluation method, the fluid-sensitive evaluation method, and the in-well fluid damage evaluation method. Based on the above methods, the sensitivity of matrix-fracture dual-media reservoirs is moderately strong for water-oil locking, stress, and fluid salinity, moderately weak for liquid alkalinity, weakest for liquid flow rate. In-well fluid damage replacement experiments show that reservoir damage caused by first contact is the most important factor of reservoir damage during the whole process of drilling-completion-reconstruction. For deep tight reservoirs, fracturing fluid is easy to cause serious reservoir damage, and it is necessary to pay attention to reservoir protection during fracturing in low-yield blocks. Copyright 2024 ARMA, American Rock Mechanics Association.

关键词： Fracturing fluids

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Evaluation of the combined influence of geological layer property and in-situ stresses on fracture height growth for layered formations

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Petroleum Science 2024年第5期21卷 3222-3236页

作者： Peng Tan Zhao-Wei Chen Liu-Ke Huang Qing Zhao Sha-Rui Shao CNPC Engineering Technology R&D Company Limited Beijing102206China National Engineering Research Center for Oil&Gas Drilling and Completion Technology Beijing102206China School of Civil Engineering and Geomatics Southwest Petroleum UniversityChengdu610500SichuanChina Shale Gas Research Institute Southwest Oil&Gas Field CompanyChengdu610500SichuanChina

Fracture geometry is important when stimulating low-permeability reservoirs for natural gas or oil production. The geological layer(GL) properties and contrasts in in-situ stress are the two most important parameters for determination of the vertical fracture growth extent and containment in layered rocks. However, the method for assessing the cumulative impact on growth in height remains ambiguous. In this research, a 3D model based on the cohesive zone method is used to simulate the evolution of hydraulic fracture(HF) height in layered reservoirs. The model incorporates fluid flow and elastic deformation, considering the friction between the contacting fracture surfaces and the interaction between fracture components. First, an analytical solution that was readily available was used to validate the model. Afterwards, a quantitative analysis was performed on the combined impacts of the layer interface strength, coefficient of interlayer stress difference, and coefficient of vertical stress *** results indicate that the observed fracture height geometries can be categorized into three distinct regions within the parametric space: blunted fracture, crossed fracture, and T-shaped ***, the results explained the formation mechanism of the low fracture height in the deep shale reservoir of the Sichuan Basin, China, as well as the distinction between fracture network patterns in mid-depth and deep shale reservoirs.

关键词： Deep shale Hydraulic fracturing HF propagation Fracture interaction Cohesive zone method

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development and Application of a New Type of Casing Buoyancy Sub 34th

Development and Application of a New Type of Casing Buoyancy...

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34th International Ocean and Polar engineering Conference, ISOPE 2024

作者： Wang, Jiandong Zhao, Lingxiao Wang, Biao Ye, Sutao Zhang, Xiangrui Xia, Yuanbo Zou, Shujiang CNPC Tianjin Bo-Xing Engineering Science & Technology Limited Company Tianjin China Key Laboratory of Drilling Engineering CNPC Tianjin China National Engineering Research Center of Oil & Gas Drilling and Completion Technology Tianjin China CNPC Tarim Oilfield Company Korla Xinjiang China CNPC Offshore Engineering Limited Company Ltd Drilling Division Tianjin China

ISBN: (纸本)9781880653784

As the shortcomings of the reduced inner diameter (ID) of the casing string and the long time to drill out when using sliding sleeve type of casing buoyancy sub, while unstable opening pressure and ringshaped residue of large size frangible glass disk casing buoyancy sub when it is activated, which affects the passing ability of cementing plugs during circulation and cementing. This paper designed a new type of 244.5mm casing buoyancy sub, which uses a frangible glass disk to create an air chamber between the sub and the float equipment at the end of the casing string. Moreover, the disk is combined with a full ID sleeve, which is fixed to the upper joint by shear pins that can be adjusted to suit the well design and downhole environment. When hydrostatic and applied pressure shears the pins, the disk and sleeve slide down together and collide with a circle of zigzagged bumps at the upper end of the lower full ID joint to break the glass disk completely. The casing buoyancy sub has the advantages of full-bore ID, stable and adjustable opening pressure, multiple protections against accidental opening design, good sealing of the casing string and no ring-shaped residue after activation. The field test has been carried out in the CH1-1-34H well and the 244.5mm casing string have been successfully run to 2761m. The opening pressure difference with the design value was less than 0.5 MPa, and the cementing plugs passed through the sub smoothly without any fluctuation in pump pressure, the drill string and scraper all passed through without any obstruction. Compared with the sliding sleeve type of casing buoyancy sub used in the same group of wells, it could save 28 hours at least of drilling out time per well. © 2024 by the International Society of Offshore and Polar Engineers (ISOPE).

关键词： Buoyancy

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