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57th US rock Mechanics/Geomechanics Symposium

作者： Liu, Shiduo Liu, Yong Xiong, Tingsong Zhang, Yang Shang, Litao Xie, Guiqi Zhang, Haining Sun, Xun Sui, Guojie Zhao, Endong Wang, Qing Zhou, Fujian Drilling and Production Technology Research Institute PetroChina Qinghai Oilfield Company Dunhuang China CNPC Engineering Technology R&D Company Limited Beijing China The Exploration Enterprise Department of Qinghai Oilfield Company Dunhuang China State Key Laboratory of Petroleum Resource and Prospecting China University of Petroleum Beijing China

ISBN: (纸本)9780979497582

The high reaction rate of hydrochloric acid, the low dissolution rate of organic acids, and the difficulty of injection of highly viscous gelled acids are all unsuitable for the acidification of low-permeability hybrid sediment reservoirs. The lithology of hybrid sediment rock reservoir is complex, and the dissolution rate of single acid is low. In this paper, an oil-in-water (O/W) microemulsion retarded acid is developed, and acidizing performance is studied. The microemulsion can be diluted in the acid system, and the structure of the microemulsion is not destroyed. The average particle size is less than 10 nm. The microemulsion acid can effectively reduce the oil-water interfacial tension, reducing the resistance to enter low-permeability cores. By adding microemulsion to the multi-hydrogen acid system, the dissolution rate is greater than 45 %. The retarded mechanism is that the polyhydric acid gradually releases hydrogen ions, then the microemulsion adsorbs on the rock surface. At the same time, the corrosion rate of microemulsion retarded acid and N80 steel is only 1.07 g/m2·h. Microemulsion retarders can adjust the surfactant composition according to the rock mineral composition to achieve the effect of high acid dissolution and substantial retardation and provide guidance for the stimulation of hybrid sediments rock reservoirs in the field. © 2023 57th US rock Mechanics/Geomechanics Symposium. All rights reserved.

关键词： Particle size

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High-Speed Wired drill Pipe and its Corresponding Manufacture & Test technology research

High-Speed Wired Drill Pipe and its Corresponding Manufactur...

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2021 Abu dhabi International Petroleum Exhibition and Conference, AdIP 2021

作者： Han, Haochen Zhang, Yong Chen, Jia Sun, Qi Fang, Zhimeng Li, Hexiang Liu, Zeng Zhang, Guobin CNPC Engineering and Technology R&D Company CNPC Materials Procurement Center

ISBN: (纸本)9781613998342

High-speed wired drill pipe and its corresponding communication technology not only can achieve high-speed transmission rate and high-capacity, but also can realize real-time monitoring and dual-way communication in whole section, which can prevent downhole problems effectively. As a series system, the homogeneity and robustness of these wired drill pipes are crucial. This paper focuses on how to overcome the difficulty in manufacturing process of information drill pipe and complete the validation test. In order to guarantee the quality of information drill pipe and satisfy the technological requirements of mass production, we optimize the manufacturing process and put forward reasonable test techniques. The optimizations of manufacturing process include the analysis on constant tension of pressure pipe, quantitative cutting pipe and perforation in pipe nozzle. The testing techniques includes magnetic coupling coil impedance test, high pressure test, communication performance test of both single pipe and series system. The test result can be judged and evaluated by the attenuation value of the signal attenuation test and the signal reflection waveform as well as sealing reliability. With the help of the optimization of the manufacturing process and the application of new tooling, the quality and robustness of information drill pipe is improved obviously. Pass rate in primary assembly is increased from 70% to 92%. After the second assembly, pass rate can be increased to 99.5%. Besides, the work efficiency is greatly improved and the process requirements of mass production are satisfied. The validation test can screen out the drill pipe with poor quality and performance effectively thus to improve the reliability of the whole system. By means of the improvement of manufacturing and the validation test, the comprehensive pass rate of information drill pipes is increased from 84% to 95%. during three field tests in Jilin and daqing Oilfield, the information drill pipes

关键词： drills

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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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Exploring the synergistic effects and mechanistic insights of ionic and polyionic liquid combinations as shale inhibitors

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Petroleum Science 2025年第04期 1566-1577页

作者： Jia-Jun dai Kai-He Lv Jin-Sheng Sun Han Jia Xian-Bin Huang Jian Li Shandong Key Laboratory of Oilfield Chemistry School of Petroleum Engineering China University of Petroleum (East China) Key Laboratory of Unconventional Oil & Gas Development (China University of Petroleum (East China)) Ministry of Education CNPC Engineering Technology R & D Company Limited

Ionic liquids（ILs）, recognized for their negligible vapor pressure, thermal stability, and structural tailorability, offer targeted inhibition of clay expansion. Compared to ILs, polyionic liquids（PILs） possess stronger mechanical properties and adsorption capabilities, showing even greater potential in inhibiting clay swelling. In this work, we synthesized and characterized an imidazole-based ionic liquid（IL-NH2）, a polyionic liquid（PIL-ABHIm）, and a PIL/IL combination. Their inhibitory performance was rigorously evaluated under simulated drilling conditions through immersion tests, linear swelling tests, among others. Additionally, the mechanisms underlying their interaction with clay minerals were elucidated through contact angle measurements, Fourier-transform infrared spectroscopy, X-ray diffraction（Xrd）,Zeta potential analysis, and molecular electrostatic potential（MEP） analysis. This work demonstrates that IL-NH_ 2inhibits osmotic hydration by altering the interlayer structure of the clay, while PIL-ABHIm reduces surface hydration by forming a hydrophobic barrier on the clay surface. PIL/IL combines both mechanisms, significantly enhancing the stability of clay through the dual mechanisms of cation exchange and hydrophobic barriers. These findings reveal an innovative mechanism by which PIL/IL combination inhibits clay hydration and swelling, providing a scientific foundation for their application in drilling fluids.

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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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Application of digital rock technology in Carbonate Tight Gas development 12th

Application of Digital Rock Technology in Carbonate Tight Ga...

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12th International Field Exploration and development Conference, IFEdC 2022

作者： Qi, Chun-Yan Zhang, Les-Lie Li, Jia-Ying deng, Hui Gu, Ye Yan, You-Jun CNPC Engineering Technology R & D Company Limited Beijing China CNPCUSACorporation HoustonTX United States Exploration and Development Research Institution PetroChina Southwest Oil and Gas Field Company Sichuan Chengdu China

ISBN: (纸本)9789819919635

With the continuous development of unconventional oil resources such as tight oil and gas in China, it is becoming increasingly more important to understand the microscopic characteristics and flow mechanism of tight oil and gas reservoirs through lab studies. It is both time consuming and costly to perform core flow tests in the very low permeability rock samples for field development. This paper described the application of high-resolution digital rock technology performed in North America in the microscopic description and flow mechanism study of the dengsi carbonate tight gas formation in the central Sichuan area. The study mainly includes: (1) The design and application of multi-scale, multi-resolution different imaging techniques to re-construct a full-diameter digital rock model to realize the three-dimensional characterization of the microscopic pores, vugs and fractures distribution of different reservoir types in the tight matrix;(2) Constructing digital rock models of different resolution and digital fluid models based on field sample and data;(3) Characterizing the permeability and porosity of digital rock models of different resolution and benchmarked against lab measurements to determine the best combination of imaging techniques;(4) Simulation of gas-water relative permeability and recovery from primary depletion at reservoir conditions. Comparing the digital core analysis with experimental results shows that the digital rock technology can be used for the evaluation of tight gas formations and flow mechanisms with high resolution, low cost, and much reduced time. digital rock models can also be reused which most time is not possible in the lab. © The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd. 2023.

关键词： Tight gas

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A Construction Method of Complex Fractures in Marine Carbonate reservoir

A Construction Method of Complex Fractures in Marine Carbona...

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Offshore technology Conference, OTC 2022

作者： Wang, Wenzhi Yang, Guang Cui, Meng Wang, Haige Zhou, Zhou Kao, Jiawei Liu, Yuqing Wang, Lian CNPC Engineering Technology R&D Company Limited China China University of Petroleum Beijing China Sinopec Research Institute of Petroleum Engineering China CNOOC Research Institute Beijing China

ISBN: (纸本)9781613998526

Marine fractured-vuggy carbonate reservoirare important oil and gas reservoirs in China, the Middle East, and North America. In the development process, it is necessary to connect hydraulic fractures and as many karst cavities as possible, which are the main geological components of oil and gas storage. However, the systematic theoretical of how to build complex fractures in fractured-vuggy carbonate reservoirs is scarce. Facing this situation, this paper presents a method that can improve the accuracy of fracturing effect prediction and optimize fracturing process design parameters so as toachieve the purpose of increasing production. It studies the factors that could affect that connection. It is found that the density of natural fractures and cavitiesin the reservoir is the main factor affecting the fracture propagation shape. Meanwhile, the liquid containing cavitiesin the reservoir will attract or repel the fractures. Furthermore, natural fractures will cause the migration of fracture propagation path and hydraulic fractures are easy to continue to expand along the direction of large natural fractures. This methodology could be used in future studies for the marine fracture–vuggy carbonate formation. In addition, the research conclusion could be used to design and evaluate hydraulic fracturing operation. © 2022, Offshore technology Conference. All rights reserved.

关键词： Offshore oil well production

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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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Improvement of rheological and filtration properties of water-based drilling fluids using bentonite-hydrothermal carbon nanocomposites under the ultra-high temperature and high pressure conditions

Improvement of rheological and filtration properties of wate...

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SPE/IATMI Asia Pacific Oil and Gas Conference and Exhibition 2021, APOG 2021

作者： Zhong, Hanyi Guan, Ying Qiu, Zhengsong Feng, Jie Liu, Wenlei Wan, Yuan Zhang, Yubin China University of Petroleum East China China CNPC Engineering Technology R&D Company Limited

ISBN: (纸本)9781613997833

With the depletion of the conventional shallow oil/gas reservoirs and the increasing demand for oil and gas, deep drilling become more and more essential to extract the oil/gas from deep formations. However, deep drilling faces many complex challenges. One of the complexities is the degradation of polymers and flocculation of bentonite particles, leading to hardly control the rheological and filtration properties of water-based drilling fluids, especially under ultra-high temperature and high pressure (HTHP) conditions. Therefore, an experimental investigation is performed to study how bentonite-hydrothermal carbon nanocomposites will influence the rheological and filtration properties of water-based drilling fluids under ultra-HTHP conditions. Bentonite-hydrothermal carbon nanocomposites are proposed as non-polymer additives to solve the ultra-HTHP challenge in water-based drilling fluid. The nanocomposites are synthesized by facile hydrothermal reaction, in which biomass starch and sodium bentonite are used as the precursor and template, respectively. In this study, the effect of the nanocomposites on the rheology and filtration properties of water-based drilling fluid are investigated before and after hot rolling at 220 °C and 240 °C. The structure characterization indicates that carbon nanospheres can successfully deposit on the bentonite surface after hydrothermal reaction and finally form as nanocomposites. The elemental carbon content, zeta potential and particle size distribution of the nanocomposites could be adjusted according to the reaction conditions. After thermal aging at 220 °C and 240 °C, addition of nanocomposites can improve the rheological properties significantly where a stable and minor change of rheological properties is observed, which is desirable for ultra-HTHP drilling. regarding filtration control, after adding 1.0 wt% nanocomposite materials, the filtration loss is reduced by 41% and 44% respectively after aging at 220 °C and 240 °C, whi

关键词： Nanocomposites

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Machine Learning Based CBM Well Multimodal Productivity Prediction and drainage Optimization 12th

Machine Learning Based CBM Well Multimodal Productivity Pred...

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12th International Field Exploration and development Conference, IFEdC 2022

作者： Fang, Ye-Xin Wu, Jia-Yi Chen, Zan Yang, Xiang-Tong Ma, ru-Tao Lian, Zhi-Long Qiao, Yan CNPC Engineering Technology R & D Company Limited Beijing China Institute of Exploration and Development SINOPEC Shanghai Offshore Oil and Gas Company Shanghai China Sinopec Petroleum Exploration and Production Research Institute Beijing China

ISBN: (纸本)9789819919635

Low permeability in most Chinese coalbed methane (CBM) reservoir would cause stress sensitivity and pulverized coal blockage. These damages seriously lower well productivity. The rationality of drainage system is one of the most important subjective factors that affect well productivity. This paper analyzes and processes the production data of an actual CBM reservoir in Sichuan province and establishes a machine learning based multimodal productivity prediction model for CBM wells. Using different parameter combinations to characterizes the drainage system and establishes a quantitative drainage Bayesian optimization model. The application in the actual CBM reservoir of this method shows that it can accurately predict the average daily gas production, gas breakthrough time and stable gas production. It can optimizes a close to platform period of bottom hole pressure, so that the pressure drop can be effectively propagated and the total production of CBM wells can be increased. The machine learning based multimodal productivity prediction model and drainage optimization model can be popularized and applied in Chinese CBM reservoirs and guide production. © The Author(s), under exclusive license to Springer Nature Singapore Pte Ltd. 2023.

关键词： Coal bed methane

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