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An intelligent completion and artificial lift technology to develop large carbonate reservoirs: Novel completion and zonal water injection via remote control methods to develop horizontal wells

An intelligent completion and artificial lift technology to ...

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SPE Trinidad and Tobago Section Energy resources Conference 2021, TTCE 2021

作者： Fu, Jin Wang, Xi Yang, Guobin Zhang, Shunyuan Chen, Chen Han, Haochen CNPC Engineering Technologies R&D Company Ltd.

ISBN: (纸本)9781613997130

There are several large carbonate reservoirs that have drawn great attention of researchers in recent years. After optimization of drilling technologies, how to deploy artificial lift technologies to develop them more efficiently is another concern. Conventional zonal water injection technologies require repetitive operation with wirelines and cables, causing extensive tests and low efficiency. However, an intelligent zonal water injection string consisting of several preset cable packers, water injection pressure gauges, formation pressure gauges and downhole flow meters has simply optimized water injection parameters and efficiently developed all reservoirs in some China's mature oilfields, especially when the string is integrated with remote monitoring and control methodologies. With the rapid development of horizontal drilling and extended reach well drilling technologies, borehole conditions are becoming more and more complicated, which has brought more challenges to water adsorption testing of horizontal intervals and deployment of zonal water injection instruments. Compared with vertical wells, the water adsorption test and string running are more challenging for horizontal wells, in which we are faced by many a problem during zonal water injection, such as competitive slack off and tight pull, excessive or inadequate water injection, complicated operation process. Besides, well deviation, dog leg and horizontal section length shall be all taken into consideration during zonal water injection for horizontal wells. Therefore, novel strings and tools should be deployed. Now tight pull, slack off and long operation periods are common problems during zonal water injection of horizontal intervals. After dedicated research, a set of wireless intelligent water injection strings for horizontal wells has been invented. Based on pressure pulse water distribution technique, the water injection string is eligible for 32-stage adjustment, so one strip may accomplish testi

关键词： Horizontal wells

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research on the Correlation Analysis Between Logging Parameters and rock drillability Based on random Forest

Research on the Correlation Analysis Between Logging Paramet...

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Frontiers technology of Information and Computer (ICFTIC), IEEE International Conference on

作者： Congyue Lv Fei Zhao Yan ding Yi Cui reyu Gao Ge Wang Yumeng Tian Wenting Jia Boyang Lin Linfeng Li CNPC Engineering Technology R&D Company Limited Beijing China College of Petroleum Engineering China University of Petroleum (Beijing) Beijing China

ISBN: (数字)9798331541750

ISBN: (纸本)9798331541767

The rock drillability grade value is a comprehensive parameter that measures the ease or difficulty of rock fragmentation during drilling. determining this parameter is crucial for guiding bit selection and predicting drilling speed. There exists a strong correlation between certain logging parameters and the rock drillability grade value. To explore this correlation, a common practice is to use the Pearson correlation coefficient method, which mainly investigates the linear relationship between variables. However, relationships among complex formation characterization parameters are often nonlinear. To evaluate the pros and cons of the two analytical methods when dealing with nonlinear and complex data, a comparison was made, and the random forest algorithm was preferentially selected as the analytical tool to enhance the precision of the prediction model. Thus, this paper analyzes the correlation between logging parameters and the rock drillability grade value based on Pearson correlation analysis and the random forest algorithm. Using the Matlab programming language, logging parameter correlation analysis software named Correlation 1.0 was developed. The random forest algorithm was preferred to screen out logging parameters with high correlation to the drillability grade value (drilling depth and formation density), providing a new approach for establishing a high-precision formation rock drillability model.

关键词： drilling Analytical models Correlation Software algorithms rocks Prediction algorithms Mathematical models Software MATLAB random forests

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Stability Analysis of Underground-gas-storage Salt Cavern Based on Similarity Criterion 55

Stability Analysis of Underground-gas-storage Salt Cavern Ba...

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55th U.S. rock Mechanics / Geomechanics Symposium 2021

作者： dong, Jingnan Li, Guotao Liu, Tianen Li, Jingcui Zhang, Yingbin CNPC Engineering Technology R&D Company Limited Beijing China HydroChina-ITASCA R&D Center Hangzhou China

ISBN: (纸本)9781713839125

Underground gas storage using salt cavern is becoming popular due to the rising problem of the seasonal gas demand peaking. The salt cavern stability analysis is an indispensable part of the salt cavern design. The aim of the research is to study the stability of the two-well-horizontal caverns and establish the universal similarity criteria controlling the creep of the cavern. The WIPP-drucker model is investigated. The mechanical properties of the formation generally follow the geo data from Pingding Mountain. The creep simulation is performed over a period of 30 years under different and cycling cavern gas pressures simulating the gas demand peak over the whole year. The similarity criteria regarding salt cavern stability are established based on dimensional analysis. The dimensional relationships between surface subsidence, cavern volume reduction, in-situ stress, cavern gas pressure, steady-state creep rate, creep time and characteristic length of the cavern are founded. results show that the simulated cavern volume reduction due to creep corresponds to the measured real cavern volume change over years. The results also show that a total of 9 dimensional physical quantities control the whole creep system. There are 4 simple criteria and 2 composed criteria, which correspond to 6 scaling criterions. The numerical simulation results verify the accuracy of the scaling criterions. The study provides guidance to the salt cavern design and operation process in the term of the mechanical stability of the cavern. © 2021 ArMA, American rock Mechanics Association

关键词： Creep

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Field Application of Slickline Fishing Well Intervention technology in Ultra-deep HTHP Gas reservoirs

Field Application of Slickline Fishing Well Intervention Tec...

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2022 SPE/ICoTA Well Intervention Conference and Exhibition, CTWI 2022

作者： Liu, Huifeng ding, Mingming Li, Cheng Ling, Zongfa Yuan, Zebo Liu, Qi Qin, Zhengli CNPC Engineering Technology R&D Company Limited China China National Oil & Gas Exploration & Development Company China PetroChina Tarim Oilfield Company China College of Petroleum Engineering China University of Petroleum Beijing China

ISBN: (纸本)9781613998496

Kelasu gas field in Tarim Basin is characterized by ultra-deep (6500-8000m), ultra-high temperature (160-19°C) and ultra-high reservoir pressure (110-136MPa). The wellhead pressure during production is also as high as 80-100MPa. rigless well intervention is always difficult to perform because of the high well control risks. Slickline testing, electric line testing and optical fiber monitoring have all been tried, but problems like breaking of slickline, loss of signal, falling of instruments into well, etc. were encountered. A slickline fishing technology has been used for bottom hole well surveillance in this area with many optimizations on the instruments. Grease injection sealing assisted by packing sealing is used to reduce friction of slickline and to guarantee well safety during operation;a choke tube stabilization device is invented to deal with the eccentric wearing of slickline and choke tube;self-supporting lever together with 8 anchor ropes are used to stabilize the blowout prevention tube assembly to withstand the high wind in the mountainous area;grease collection device is used to avoid the discharge of grease into the environment. The technology has been successfully used in more than 70 wells in Kelasu gas field. The interventions include production testing, pressure built up (PBU) testing and well interference test. The maximum setting depth of the manometer reaches 7189 m. The highest wellhead pressure during testing reaches 90 MPa. Longest pressure survey time comes up to 52 days. No surface or downhole problems have been encountered and all the required data have been acquired. The wells were not killed during the intervention so the reservoir is well protected. Well interference tests were conducted in Keshen 8 block using this technology. The results showed very good interwell connectivity and suggested that well spacing should be enlarged. The development program of this block was adjusted accordingly and it turned out that the expected produc

关键词： Surveys

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Twenty Years’ Offshore Polymer Flooding Field Tests and Practices in Shallow Sea 22

Twenty Years’ Offshore Polymer Flooding Field Tests and Pra...

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22nd European Symposium on Innovative and Optimised resource Utilisation, IOr+ 2023

作者： Guo, H. Wang, Z. Lyu, X. Liu, S. Liu, H. China University of Petroleum China SINOPEC Research Institute of Petroleum Engineering Co. China SINOPEC Northwest Oilfield Company China CNOOC EnerTech China CNPC Research Institute of Petroleum Exploration and Development China CNPC R&D DIFC China

ISBN: (纸本)9789462824881

due to the harsh reservoir conditions and environment as well as limited knowledge about the mechanisms, first polymer flooding field test in offshore reservoir in China was 7 years after the commercial application of polymer flooding in onshore reservoirs. The polymer flooding field test was gradually enlarged and expanded to six oilfields in Bohai. The water depth in Bohai oil fields were low. Among the six offshore polymer flooding projects, three were surfactants based (surfactant/polymer flooding). different from onshore polymer flooding field practices in China, the associative polymer (AP) was injected in two offshore reservoirs to meet the requirement of high polymer solution viscosity in high salinity sea water. Because of the hydrophobic monomer in molecular structure, the AP has much better salinity-resistance performance and produced higher solution viscosity than conventional polymer partially hydrolyzed polyacrylamide (HPAM). The molecular size of AP was also larger than that of HPAM which may affect its formation transportation. The polymer flooding performances were different in terms of incremental oil recovery factor (IOrF), injection pressure and produced fluids treatment. The limited space and processing time in offshore platforms constrained the selection of polymers and the injection schemes. The injection rate ( © IOr+ 2023 - 22nd European Symposium on Innovative and Optimised resource Utilisation.

关键词： Oil well flooding

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Overcoming complex near-surface conditions for improved seismic imaging in Tarim Basin, China

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Leading Edge 2025年第3期44卷 206-213页

作者： Zhao, ruirui Zheng, duoming Yang, Shanshan Zuo, Anxin Chen, Yangyang Zhu, Xianhuai Xu, Ken Gray, Sam PetroChina Tarim Oilfield Company Research Institute of Exploration and Development Xinjiang Korla China CNPC R&D Center for Ultra-Deep Complex Reservoir Exploration and Development Xinjiang Korla China Engineering Research Center for Ultra-Deep Complex Reservoir Exploration and Development Xinjiang China Forland Geophysical Services HoustonTX United States Viridien CalgaryAB Canada

Seismic imaging in the Tarim Basin, China, presents significant challenges due to complex near-surface conditions, including desert environments, foothills, and loess mountains. These challenges are comparable to those found in regions such as the Arabian Peninsula, North Africa, the Andes Mountains, and other complex terrains worldwide. recent advancements in seismic imaging aimed at overcoming these obstacles include: (1) advanced constrained near-surface tomography, which has significantly enhanced the robustness of near-surface velocity-depth model estimation, leading to improved resolution of deep reservoir images;(2) a recent ultra-long-offset (greater than 15 km) experiment in the foreland basin of the Tarim Oilfield, demonstrating that more accurate and deeper near-surface velocity models can be generated on land using turning-ray tomography;(3) finite-frequency wavepath tomography, which has been proven through field data examples to be a robust alternative to traditional full-waveform inversion for land seismic data;and (4) integrated tomography, which combines diving waves and reflected seismic data to develop a comprehensive velocity model from shallow to deep sections for anisotropic prestack depth migration from topography. These technologies, developed for and applied to the Tarim Basin, can be applied, with modifications, to other land basins around the world. © 2025 by The Society of Exploration Geophysicists.

关键词： Watersheds

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Integrated Well Network design Mode for CO2 EOr and Storage and its Application in L reservoir

Integrated Well Network Design Mode for CO2 EOR and Storage ...

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2025 International Petroleum technology Conference, IPTC 2025

作者： Wu, Zangyuan Tang, Yongliang Lian, Liming Zhou, daiyu Zhao, Haitao Shao, Guangqiang Feng, Qihong Zhou, Wei Li, Hong Bian, Wanjiang Zhang, Liang du, Hongbao Luo, Min Huang, Xingning Tarim Oilfield Company PetroChina Xinjiang Korla China R&D Center for Ultra-Deep Complex Reservoir Exploration and Development CNPC Xinjiang Korla China School of Petroleum Engineering China University of Petroleum East China Qingdao China Research Institute of Petroleum E&D Petrochina CNPC Beijing China Chengdu CK Energy Technology Co. Ltd. Sichuan Chengdu China

ISBN: (纸本)9781959025436

This paper addresses the challenge of difficulty in adjusting late-stage production in water-flooded reservoirs and proposes an integrated well network design mode for CO2 enhanced oil recovery (EOr) and storage. The well network is designed according to the full life cycle of carbon capture, utilization, and storage (CCUS), meeting the requirements of both CO2 EOr and storage phases. It extends the implementation time of CO2 EOr schemes to enhance oil recovery while ensuring effective CO2 storage, aligning with the overall strategy of global green and low-carbon development. The overall approach involves the use of a three-dimensional CO2 flooding injection and recovery well network, with progressive development in the vertical stratigraphic layers to maximize the utilization of existing old wells. The stratigraphic reconstruction involves the CO2 flooding injection and recovery well network, ensuring that new gas injection wells meet the requirements for CO2 injection processes and production rates, while also serving as replacements for gas injection in other stratigraphic layers. Production wells make use of the original old wells, and well completion methods are adjusted to achieve the development of replacement layers. The "top injection, middle production, bottom support" three-stage development method is designed to fully utilize the high points of reservoir microstructures and bottom water energy. Finally, well network optimization is achieved through streamline tracking simulation methods. The proposed technology has been applied in the CO2 enhanced oil recovery plan for the L reservoir. Initially focusing on CO2 flooding for oil recovery and shifting to CO2 storage later, it is projected to achieve a cumulative CO2 injection of tens of millions of tons over 46 years (including 40% recycled injection), with a displacement factor reaching 1.57PV. After deducting the recycled carbon amount, the cumulative carbon storage exceeds 6 million tons, affecting a vo

关键词： Crude oil

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Study on the Multiphase Flow Behavior in the Jet Pump Lifted Natural Gas Hydrate Wells with Combined depressurization and Heat Injection Method

Study on the Multiphase Flow Behavior in the Jet Pump Lifted...

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International Petroleum and Petrochemical technology Conference 2024, IPPTC 2024

作者： Ping, Xiaolin Han, Guoqing Zhang, Jiqun Wang, Hongliang Liu, Changchun Liu, Jungang China Research Institute of Petroleum Exploration & Development PetroChina China Artificial Intelligence Technology R&D Center for Exploration and Development CNPC China PetroChina Changqing Oilfield Company China Exploration & Development Research Institute of Changqing Oilfield China

Natural gas hydrate production tests have been carried out successfully with different exploitation methods and gas recovery drainage technologies. The purpose of this study is to elucidate the fluid flow behavior in the jet pump lifted natural gas hydrate wells and optimize hot water injection parameters for the jet pump drainage gas recovery technology. The mechanism of jet pump drainage recovery of natural gas hydrate wells was analyzed and its applicability to natural gas hydrate exploitation with combined depressurization and heat injection method was demonstrated. In addition, multiphase flow models of tubing and annulus were established respectively for the phenomenon of countercurrent flow of heat exchange in the jet pump drainage gas recovery process, and the corresponding multiphase flow laws were derived. Based on the study of multiphase flow, sensitivity analysis and optimization of heat injection parameters were performed. It has been demonstrated that jet pump drainage gas recovery technology is suitable for the exploitation of onshore natural gas hydrate with combined depressurization and heat injection method. The multihphase flow behavior in the tubing and annulus of the jet pump lifted natural gas hydrate wells was disclosed in this study. Numerical simulation results show that the temperature and pressure distribution in the wellbore of the jet pump lifted natural gas hydrate wells during the recovery process are affected by the injection conditions. This study provides theoretical guidance for the production optimization and hydrate prevention and control in the wellbore of the jet pump lifted natural gas hydrate wells. © 2024 Institute of Physics Publishing. All rights reserved.

关键词： Sensitivity analysis

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Mechanism of Polycrystalline diamond Compact and diamond Impregnated Cutter Hybrid Bit Composite rock Breaking

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Journal of engineering Science and technology review 2023年第2期16卷 189-196页

作者： Yu, Jinping Ji, Guodong Wu, Qiang Wang, Qing Hu, Huaigang CNPC Engineering Technology R&D Co. Ltd Beijing102206 China

rock breaking efficiency of drill bits is an important index for measuring the drilling efficiency in the oil and gas drilling field, and it is influenced by many factors, such as structure and material. This study developed a calculation model and an experimental model of rock breaking of polycrystalline diamond compact (PdC) and diamond impregnated cutter (dIC) hybrid bit to reveal the influence of bit structure and material on tangential force, axial force and wear height. On the basis of the calculation model of the co-rail arrangement of the PdC–dIC hybrid bit and the rock breaking mode, a rock breaking mechanical parameter prediction model and a rock breaking performance test model were established. rock stress calculation method, rock failure criterion, and mechanical specific energy (MSE) calculation method were used to analyze the rock stress and the relationship between MSE and tangential force, axial force, and wear height during combined rock breaking. The accuracy of the model was verified by experiments. results show that the specific work of rock breaking of the PdC-dIC hybrid bit is less than that of PdC, and a reverse nonlinear relationship exists between specific work of rock breaking and wear height. The energy required for hybrid bit to break rock is less than that of PdC bit. A positive nonlinear relationship exists between the energy of PdC-dIC hybrid bit and the wear height, whereas the cutting depth and the wear height show a negative nonlinear relationship. The stress distribution of PdC rock breaking is uniform, and the maximum equivalent stress is up to 104 MPa. The stress distribution of rock breaking of the hybrid PdC-dIC is extremely nonuniform, and stress concentration occurs with a minimum equivalent stress of 84 MPa and a maximum stress of 161 MPa, which is beneficial to rock breaking. rock breaking of PdC-dIC hybrid bit can promote the generation and development of rock cracks, thereby reducing the crushing strength of the rock. The

关键词： rocks

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removing Water Blocking damage in HTHP Tight Gas reservoir Using Alternative Fracturing Fluid

Removing Water Blocking Damage in HTHP Tight Gas Reservoir U...

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2022 SPE Conference at Oman Petroleum and Energy Show, OPES 2022

作者： Liu, Huifeng Zhang, Jianli Liu, Jiangyu Yang, Zhanwei Chen, Tie Gu, Yixin Baletabieke, Bahedaer CNPC Engineering Technology R&D Company Limited China National Oil & Gas Exploration & Development Company China PetroChina Tarim Oilfield Company China Research Institute of Petroleum Exploration and Development PetroChina China

ISBN: (纸本)9781613997062

Tight gas reservoir is easily damaged by liquid phase because of the small pores and throats in the formation. Hydraulic fracturing is usually used in this kind of reservoir to improve well productivity;however, sometimes the productivity declines instead of increasing after treatments because of the damage of the water-based stimulation fluids. This paper introduces a production decline case in the HTHP tight gas reservoir in Tarim Basin, Western China, and provides a new solution. dixi gas reservoir belongs to the formation of Jurassic Ahe Group, with burial depth of about 5000m. The formation porosity is between 3.0-7.0%, and the permeability is less than 0.1md. The average dST production rates of three wells in this area were more than 30×104 m3/d. However, the production declined by 40% after completion. Acidizing and proppant fracturing were both conducted to regain their productivities;however, the production rates were reduced even further after the treatments. One of these wells’ daily production rate declined by 78% compared to dST production after use of acid fracturing and hydraulic fracturing. A series of core flow tests were carried out to find out the causes and solutions. The results showed that the retention of fracturing fluid in the formation caused "water blocking damage", which leaded to a significant increase of water saturation and rapid decline of gas phase permeability. This is considered the main cause of well productivity decline. Therefore, minimizing the capillary force in the formation is considered the main approach to remove the damage. Three series of alternative fracturing fluids were developed and evaluated. The first one is fracturing fluid with methanol. 5%-20% methanol was added to the fracturing fluid to relieve water blocking damage. The results showed that most of the wells fractured by methanol fracturing fluid gained good post-fracturing productivity. Fluorocarbon surfactant fracturing fluid was also developed, in which the

关键词： Fracturing fluids

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