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Matching Analysis and Experimental Study of Mechanical Properties of Cement Sheath Interface

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SSRN 2022年

作者： Cheng, Y.Q. Liu, S.Q. Shen, J.Y. Guo, X.L. Huang, Z. Liu, H.T. Research Institute of Petroleum Exploration & Development Beijing100089 China Cementing and Completion Research Institute CNPC Engineering Technology R&D Company Limited Beijing102206 China

Clarifying the mechanism of cement sheath interface matching and determining the cement sheath interface matching under specific downhole conditions is a fundamental and challenging requirement for accurate prediction of cement sheath integrity. The mechanical properties of the cement sheath interface, an important component of the cement sheath integrity, are the key factors affecting the damage of the cement interface. In this study, we propose a method to measure the variation of cement sheath interfacial match with the mechanical properties of the cement sheath under typical downhole conditions, including the Young's modulus of the cement sheath and the Poisson's ratio. The analysis of cement sheath interface matching was further combined with experimental methods to test the accuracy of the cement sheath interface matching method in this study and to assess the cement sheath integrity capabilities of different cement types under different operating conditions. The numerical results show that increasing the cement sheath Young's modulus as well as decreasing the Poisson's ratio without considering the downhole conditions can improve the cement sheath interface matching, but the cement sheath interface is more sensitive to the cement sheath Poisson's ratio. Laboratory measurements have shown that reducing Poisson's ratio by adding materials such as latex to cement significantly improves the cement's ability to ensure cement sheath integrity, although the Young's modulus of the cement sheath decreases in parallel with the addition of latex. Based on the results of the experimental and numerical methods, qualitative and quantitative recommendations are provided for field operations to suppress cement sheath integrity risks throughout the life cycle of the wellbore. © 2022, The Authors. All rights reserved.

关键词： Poisson ratio

True 3D Fracture Simulation with Geology-engineering Integration of Volume Modification in Jimsar Shale Oil 6

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True 3D Fracture Simulation with Geology-engineering Integra...

2020 6th International Conference on Environmental Science and Material Application, ESMA 2020

作者： Zhang, Kui Xiao, Yang Cheng, Leiming Liu, Shouyu Wang, Junchao Xu, Mingqiang Engineering Technology Research Institute Xinjiang Oilfield Company PetroChina Karamay China School of Energy Chengdu University of Technology Chengdu China Chengdu Institute of Technology Sunshine Energy Technology Co. Ltd. Chengdu China Shale Oil Project Management Department Development Company PetroChina Xinjiang Oilfield Company Karamay China CNPC Engineering Technology RandD Company Limited Beijing China

The main characteristics of Jimsar shale oil reservoir are of complex structure, strong heterogeneity and great difficulty in fracturing. It is mainly produced by volume fracturing technology, which is easy to form complex fracture networks. At present, the design and parameter optimization of fracturing scheme are not targeted, and the true 3D fracture simulation with geology-engineering integration is particularly important. On the basis of 3D geological modeling, the 3D geo-mechanical parameter distribution is determined by seismic data, logging data, experimental data, etc to simulate the stress environment in which the overburden pressure, surrounding rock pressure and lower strata pressure. And the 3D geo-mechanical parameter model is established by combining simulated analysis of the stress. On the basis of geological model, geomechanical model and natural fracture model, the natural fractures and faults determined by seismic, logging or discrete fracture modeling are integrated into the geomechanical model to complete the true 3D simulation of artificial fracture network based on true 3D geo-mechanical model. This simulation is the practice and improvement of the geology-engineering integration of shale oil reservoirs volume modification technology in Jimsar, which will deepen the geological understanding and strengthens the engineering technology supporting, provides reference basis for the optimization design of fracturing process and the maximization of the volume, and finally realizes the efficient development of shale oil in Jimsar. © Published under licence by IOP Publishing Ltd.

关键词： Integration

Theoretical Analysis and Field Application of Cooling Bottom Hole by Mud Density Reduction During Drilling in Deep Shale Gas Well

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SSRN 2024年

作者： Tang, Ming Zhang, Guangfu He, Shiming Kong, Linghao Wang, Shuangning Yao, Genghua Jing, Yadong Deng, Xianghua State Key Laboratory of Oil and Gas Reservoir Geology and Development Engineering Southwest Petroleum University Sichuan Chengdu610500 China Sinopec Xinan Oil and Gas Field Branch Sichuan Chengdu610041 China Drilling and Production Technology Research Institute CNPC Chuanqing Drilling Engineering Company Limited Sichuan Chengdu610500 China

During deep shale gas well drilling process, high bottom hole temperature (≥150℃) often causes the conventional rotary steerable tool and logging while drilling (LWD) to malfunction. Therefore, it is essential to reduce the bottom hole temperature for safe and efficient drilling. In this paper, a simplified wellbore temperature model for deep shale gas horizontal well was established based on thermodynamic theory, comprehensively accounting for both mechanical and hydraulic heat source. A quantitative analysis was performed to assess the impact of rheological parameters, engineering parameters, thermal parameters and two cooling methods on bottom hole temperature. In addition, a density reduction and cooling scheme for drilling in the horizontal section was developed and implemented on H-29-1 and H-29-6 Well. The results indicated that the temperature model is in good agreement with the Kirbir & Hasan model and real-time measurement data with an error less than ± 6 %. Mud density, behavior index, pump rate, weight on bit (WOB) and geothermal gradient had great influence on the bottom hole temperature (up to over 30℃). If the horizontal section is shorter than 1000 m, reducing the inlet temperature can effectively reduce the bottom hole temperature. But once the horizontal section exceeds 1500 m, reducing mud density is much more effective. With field application on H-29-1 and H-29-6 Well, mud density was reduced from 2.25 g/cm3 to 1.80 g/cm3, resulting in a maximum bottom hole temperature of 143℃ in the horizontal section, and rotary steerable tools and screw worked stably in downhole. Compared to adjacent wells on the same platform that bottom hole temperatures are all above 152 ℃, the maximum bottom hole temperature decreased by 9-13℃. Furthermore, in the horizontal section, the Rate of Penetration (ROP) is increased by more than 48 %, the pump pressure is reduced by 2-5MPa, and the average hole enlargement rate is only 1.92 %. All findings show that lower mud den

关键词： Horizontal wells

Controlling Filtration Loss of Water-Based Drilling Fluids by Anionic Copolymers with Cyclic Side Groups: High Temperature and Salt Contamination Conditions

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SSRN 2023年

作者： Li, He Sun, Jinsheng Xie, Shuixiang Lv, Kaihe Huang, Xianbin Zong, Jiajiang Zhang, Yu CNPC Engineering Technology Research and Development Company Limited China Key Laboratory of Unconventional Oil & Gas Development China University of Petroleum [East China Ministry of Education Shandong Qingdao266580 China Shandong Qingdao266580 China Safety and Environmental Protection Technology Research Institute China National Petroleum Corporation Beijing102200 China

Water-based drilling fluids (WDFs) as a thermally unstable colloidal system play an essential role in the drilling operation. The filtration loss control of WDFs under high temperature and salt contamination has been a research hotspot. In this study, the copolymer (named DSA) containing different cyclic side groups was synthesized to control the filtration loss of WDFs. The chemical structure and thermal stability of the DSA were analyzed. The result showed that DSA exhibited only a slight weight loss (6.0 wt%) until 300 °C. The effect of DSA concentration on the rheological performance of WDFs was investigated with a HAAKE rheometer. The filtration loss control ability of DSA was evaluated according to the American Petroleum Institute standards. The filtration loss volume of WDFs with 15 wt% NaCl could be controlled to 9.6 ml with 2.0 wt% DSA after aging at 190 °C. To study the mechanism, the absorption behavior of DSA on bentonite with concentration was studied. The saturated absorption capacity of 2.0 wt% DSA on bentonite was 94.7 mg/g. The effect of DSA on the dispersion of WDFs was analyzed by measuring the zeta potential and particles size distribution. Then, the micromorphology and permeability of the filter cakes for WDFs were analyzed. According to the results, DSA effectively absorbed on the bentonite surface, reducing the zeta potential and particles size of the bentonite to form filter cakes with low permeability. The filtration loss of WDFs was then controlled by DSA. The research results were instructive for the development of polymer with high temperature and salt resistance for WDFs. © 2023, The Authors. All rights reserved.

关键词： Bentonite

Genetic Mechanism and Evolutionary Pattern of Pore Structure in Deep Marine Shales in Sichuan Basin, South China: Insights from Sem Observation and Quantitative Characterization

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SSRN 2024年

作者： Wang, Xueying Zhang, Kun Jiang, Shu Song, Yan Jiang, Lin He, Xinyang Niu, Hulin Jiang, Wei Li, Jing Wu, Yijia Gao, Zhi Zhang, Chen Yuan, Xuejiao Han, Fengli Wang, Zeyun Ye, Laiting School of Geoscience and Technology Southwest Petroleum University Chengdu610500 China Ministry of Education Wuhan430074 China Shale Gas Evaluation and Exploitation Key Laboratory of Sichuan Province Chengdu610299 China Energy and Geoscience Institute University of Utah Salt Lake CityUT84108 United States Research Institute of Petroleum Exploration and Development PetroChina Beijing100083 China International Company of China Petroleum Logging Company CNPC Beijing102206 China Shale Gas Exploration and Development Project Department of CNPC Chuanqing Drilling Engineering Company Limited Chengdu610051 China Institute of Geological Exploration Development of CNPC Chuanqing Drilling Engineering Company Limited Chengdu610051 China State Key Laboratory of Oil and Gas Reservoir Geology and Exploitation Chengdu University of Technology Chengdu610059 China Institute of Sedimentary Geology Chengdu University of Technology Chengdu610059 China

Shale storage capacity is primarily affected by micro–nano pore structures. However, there has been a notable gap in research on the precise and quantitative pore structure of deep, organic-rich marine shales, particularly regarding pore genetic mechanisms and evolutionary patterns. In response to this situation, this study focused on the first submember of the first member from the lower Silurian Longmaxi Formation in the Luzhou Block, Sichuan Basin, specifically through wells L1 and L2. Through a comprehensive analysis, including organic geochemistry, mineral composition, CO2 adsorption, N2 adsorption–desorption, high-pressure mercury intrusion, focused ion beam scanning electron microscopy (FIB-SEM) and nuclear magnetic resonance (NMR) experiments, this study sought to fill the aforementioned gaps. The results show that pyrobitumen is the main contributor to pores in the shale reservoir (contributing approximately 59.95%–62.00% of the pores). From the over-mature stage to the semi-graphitised stage, there was a reduction in the storage capacity, adsorption capacity and connectivity of the shale pores;however, in terms of pore storage capacity, the reduction was less for mesopores (approximately 8.37%–9.14%) than that for micropores and macropores (approximately 25.02%–52.86%), and in terms of connectivity, pores that are 100–1000 nm in diameter decreased more considerably (approximately 33.46%–62.09%). In the mature to high-mature stage, the retained oil filling in the pores between rigid mineral particles transformed into pyrobitumen, and with the ongoing compaction, the surface porosity of shale decreased. In the over-mature stage, under the joint effect of diagenesis and thermal evolution, pyrobitumen produced many gas-filled pores. As the support force between rigid mineral particles and gaseous hydrocarbons in pyrobitumen pores reached a balance with the overlying formation pressure, the pyrobitumen pores were preserved, thereby increasing the surface porosi

关键词： Pore structure

Fracturing parameters optimizing simulation of horizontal well in WeiYuan shale gasfield 7

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Fracturing parameters optimizing simulation of horizontal we...

7th International Conference on Energy technology and Materials Science, ICETMS 2021

作者： Che, Mingguang Wang, Meng Zeng, Bo Song, Yi Jiang, Wei Zhang, Xiaofeng Dong, Kai Department of Modern Mechanics University of Science and Technology of China Anhui Hefei230026 China Research Institute of Petroleum Exploration and Development PetroChina Beijing100083 China XiNan Oil and Gas Field Co. Ltd. PetroChina Sichuan Chengdu610041 China CNPC Chuanqing Drilling Engineering Company Limited Sichuan Chengdu610031 China CNPC Great Wall Drilling Engineering Company Limited Beijing100101 China

Multistage fracturing and multi-clusters with long lateral fracturing were applied during developing the WeiYuan shale gas field, and the fracturing parameters were variable obviously for the fracturing lateral, perforating clusters, pumping rate, fracturing fluid volume and proppant quality. In this paper, the 3D geological model of a WeiYuan shale gas pad was used to simulate and optimize the fracturing parameters of the shale gas horizontal wells. The simulating results show that there is a reasonable matching relationship between different fracturing lateral length and the perforating clusters, and there is an optimal fluid volume and proppant quality. As the length of the fracturing lateral and the number of clusters increase, the spacing of horizontal wells need to be reduced reasonably. With the purpose of fracturing parameters optimization for WeiYuan shale gas horizontal wells, it is recommended to increase the number of perforation clusters, increase the treating rate, and use the reasonable fluid volume and proppant quality for different fracturing lateral. The research results of this paper have guiding significance for the optimization and treatment of fracturing shale gas horizontal well. © 2021 Institute of Physics Publishing. All rights reserved.

关键词： Horizontal wells

Enrichment characteristics and exploration directions of deep shale gas of Ordovician-Silurian in the Sichuan Basin and its surrounding areas,China

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Petroleum Exploration and development 2022年第4期49卷 744-757页

作者： NIE Haikuan LI Pei DANG Wei DING Jianghui SUN Chuanxiang LIU Mi WANG Jin DU Wei ZHANG Peixian LI Donghui SU Haikun State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development Beijing 102206China Sinopec Petroleum Exploration and Production Research Institute Beijing 102206China School of Earth Sciences and Engineering Xi’an Shiyou UniversityXi’an 710300 CNPC Engineering Technology R&D Company Limited Beijing 102206China Research Institute of Petroleum Exploration and Development Sinopec Jianghan Oilfield CompanyWuhan 430223China Sinopec East China Company Nanjing 210019China School of Energy Resources China University of GeosciencesBeijing 100083China

The enrichment characteristics of deep shale gas in the Ordovician Wufeng-Silurian Longmaxi formations in the Sichuan Basin and its surrounding areas are investigated through experiments under high temperature and high pressure,including petrophysical properties analyses,triaxial stress test and isothermal adsorption of methane experiment.(1)The deep shale reservoirs drop significantly in porosity and permeability compared with shallower shale reservoirs,and contain mainly free gas.(2)With higher deviatoric stress and axial strain,the deep shale reservoirs have higher difficulty fracturing.(3)Affected by structural location and morphology,fracture characteristics,geofluid activity stages and intensity,deep shale gas reservoirs have more complicated preservation conditions.(4)To achieve the commercial development of deep shale gas reservoirs,deepening geological understanding is the basis,and exploring reservoir simulation technology befitting the geological features is the key.(5)The siliceous shale and limestone-bearing siliceous shale in the Metabolograptus persculptus-Parakidograptus acuminatus zones(LM1-LM3 graptolite zones)are the high-production intervals for deep shale gas and the most favorable landing targets for horizontal *** water areas such as Jiaoshiba,Wulong,Luzhou and Changning with deep shale reservoirs over 10 m thickness are the most favorable areas for deep shale gas *** is recommended to carry out exploration and development practice in deep-water shale gas areas deposited deep with burial depth no more than 5000 m where the geological structure is simple and the shale thickness in the LM1-LM3 graptolite zone is greater than 10 *** is better to increase the lateral length of horizontal wells,and apply techniques including high intensity of perforations,large volume of proppant,far-field and near-wellbore diversions to maximize the stimulated deep reservoir volume.

关键词： deep shale gas enrichment conditions reservoir characteristics exploration direction Ordovician Wufeng Formation Silurian Longmaxi Formation Sichuan Basin

Effect of Sds on the Formation and Blockage Characteristics of Ch4 Hydrate in a Flow Loop

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SSRN 2022年

作者： Zang, Chunyang Ma, Guiyang Huang, Shaochang Qin, Yue Ao, Di Liu, Chaoguang Zhang, Yuda College of Petroleum Engineering Liaoning Petrochemical University Liaoning Fushun113001 China Research Institute of Petroleum Exploration & Development Beijing100083 China CNPC Engineering Technology R&D Company Limited Beijing102206 China

Anti-agglomeration is an ideal solution for the reduction of gas hydrate risks in deep-sea pipelines. Currently, the ineffectiveness of water-based systems limits their application. To ensure safe flow within a pipeline, a high-pressure flow loop with observation windows was designed, and SDS was used as an anti-agglomerant (AA). A series of CH 4 hydrate formation and slurry flow experiments was carried out under horizontal and inclined flow loops. The growth and blockage rules of hydrates in SDS solution and the effects of different factors on the hydrate induction period and blockage time were obtained. The experimental results show that SDS has a good anti-agglomeration effect in the water-based system. After the addition of SDS, the hydrate can only minimally deposit on the wall, allowing the hydrate slurry to flow stably for a long time and a higher volume fraction. Increasing the flow rate can prolong the hydrate slurry flow time. With the increase in the inclination angle of the loop, hydrate particles with larger particle sizes are more likely to appear, and the time until blockage is decreased. The flow rate in the loop decreases with increasing hydrate particle size. Understanding the flow process and blockage trend of hydrate slurry in a pipeline transportation system can, to an extent, provide a reference for the industrial application of CH 4 hydrate slurry flow. © 2022, The Authors. All rights reserved.

关键词： Agglomeration

Identification of Rock Cracks in Outcrop Areas Based on Improved DeepLab V3+

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Identification of Rock Cracks in Outcrop Areas Based on Impr...

New Trends in Computational Intelligence (NTCI), International Conference on

作者： Yaowei Zhang Senlin Yin Zhangming Hu Kai Bai Ting Xiong College of Computer Science and Technology Yangtze University Jingzhou Hubei China Hubei Provincial Key Laboratory of Southern Complex Shale Oil and Gas Geology and Development Wuhan Hubei Province China Research Institute of Mud Logging Technology and Engineering Yangtze University Jingzhou Hubei China Engineering and Technology Division CNPC Xibu Drilling Engineering Company Limited Xinjiang Urumqi China Shenzhen Branch of CNOOC (China) Co. Ltd. Shenzhen China

ISBN: (数字)9798331517021

ISBN: (纸本)9798331517038

The study of reservoir fractures has always been a key focus in oil and gas exploration and development, and the most intuitive method is to observe rock fractures in outcrop areas. Manual surveying has low efficiency and strong subjectivity, so identifying rock fractures in outcrop areas has always been a difficult task. In response to this difficulty, this article utilizes drone oblique photography technology to significantly improve surveying efficiency, and proposes an improved DeepLabv3+ semantic segmentation model to achieve accurate segmentation of rock fractures. The experimental results showed that the MAP (Mean Average Precision) of the improved DeepLabv3+ model reached 83.77%, which was 12.44% higher than the original DeepLabv3+ model; MIoU (Mean Intersection over Union) has increased from 68.21 % to 78.84%; The accuracy has increased from 74.83% to 91.66%; The parameter count is only 15.14M. The experimental results show that the improved DeepLabv3+ model in this paper exhibits superior segmentation performance in rock fracture segmentation tasks in field outcrop areas, and has good mobile deployment performance.

关键词： Performance evaluation Training Accuracy Convolution Semantic segmentation Rocks Reservoirs Stability analysis Robustness Real-time systems