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56th U.S. Rock Mechanics/Geomechanics Symposium

作者： Qian, Wang Shengxian, Zhao Chenxi, Ye Wenbao, Zhai Chao, Fang Peng, Tan CNPC Engineering Technology R&D Company Limited Beijing China Petrochina SourthWest Oil&Gas field Company Shale Gas Research Institute Sichuan Chengdu China

ISBN: (纸本)9780979497575

Horizontal drilling and large-scale hydraulic fracturing are currently used to increase artificial fracture networks and per well production in unconventional reservoirs. due to the differences of regional geological characteristics, natural fracture characteristics and geomechanical characteristics, different wellbore directions may lead to different hydraulic fracturing effects and post-frac productivity. If the well orientation is not correct, it can result in poor hydraulic fracturing propagation and inefficient production. The high precision geological model and geomechanical model of platform of typical shale gas blocks in Sichuan were established. First, considering the interaction of hydraulic fracture and natural fracture, interaction of hydraulic fracture each other, hydraulic fracturing network distribution in different in-situ stress orientation, natural fracture azimuth, wellbore azimuth combination cases were simulated. Second, high-precision unstructured grid numerical model was established on the basis of hydraulic fracturing fractures to accurately characterize fracture network morphology and fracture conductivity. The flow characteristics of hydraulic fracturing network was simulated, and post-frac productivity were predicted. Finally, the optimal wellbore orientation under various in-situ stresses and natural fracture combination cases was obtained by combining the fracturing effect and post-frac productivity. The research results show that, under the typical fracturing construction and production conditions in Sichuan shale gas block, the optimal well orientation is not affected by the natural fracture orientation. The fracturing effect and production within the range of 0-30 degrees of horizontal minimum in-situ stress are better. When the angle between natural fracture orientation and horizontal minimum in-situ stress is more than 50º, the overall production becomes better in various well directions. © 2022 ARMA, American Rock Mechanics Associa

关键词： Hydraulic fracturing

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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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Study on Matrix Acidizing of Low-permeability Hybrid Sediment Rocks Using Microemulsion Retarded Acid 57

Study on Matrix Acidizing of Low-permeability Hybrid Sedimen...

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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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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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Coupling Prediction Model and Influencing Factors Analysis of Injection and Production Gas Flow Rate and Wellhead Pressure for Compressed Air Energy Storage in Salt Cavern

SSRN

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SSRN 2024年

作者： Ren, Qianyu Wang, Jiangshuai Fu, Pan School of Energy School of Oil and Gas Engineering Changzhou University China CNPC Engineering Technology R&D Company Limited National Engineering Research Center for Oil & Gas Drilling and Completion Technology

In order to accurately predict the injection and production gas flow rate and wellhead pressure for compressed air energy storage in salt cavern, a coupled prediction model of injection and production gas flow rate and wellhead pressure based on gas pipe flow theory was established in this paper. And, a high-precision and high-speed iterative solution algorithm was proposed to achieve accurate and rapid prediction of injection and production gas flow rate, wellhead pressure, and total pressure loss. Furthermore, the influences of factors such as cavity connectivity, number of cavities, cavity pressure, depth of injection and production wells, number of injection and production columns, size of injection and production columns, and injection and production medium on injection and production gas flow rate, wellhead pressure, and total pressure loss were discussed. The research results indicate that: ① There are good stability, fast convergence speed, and good consistency between the predicted results and on-site measured data for the model. ② Under the condition that cavity is connected, the total injection production flow rate will be evenly distributed to each injection production well, and the wellhead pressure and total pressure loss of each injection production well are consistent. Under the condition that cavity is not connected, injection production wells with higher cavity pressure have greater injection production gas flow rate and total pressure loss. ③ With the increase in the number of chambers, the decrease in chamber pressure, the increase in injection production well depth, the increase in the number of injection production columns, and the decrease in the size of injection production columns, the single tube injection production gas flow rate decreases. However, the changes in wellhead pressure and total pressure loss are not only influenced by various factors, but also closely related to operating conditions. ④ When other conditions remain unchanged,

关键词： Compressed air

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Sand Production Prediction of depleted-reservoir Underground Gas Storage - An experimental study 56

Sand Production Prediction of Depleted-reservoir Underground...

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56th U.S. Rock Mechanics/Geomechanics Symposium

作者： Ma, Lijun dong, Jingnan Wang, Jinzhong Zhang, Yuda Li, Guotao Li, Jingcui Department of Well Engineering Supervise Changqing Oil Field Company Shaanxi China CNPC Engineering Technology R&D Company Limited Beijing China Jidong Oilfield Company PetroChina Hebei Tangshan China Research Institute of Petroleum Exploration & Development PetroChina Beijing China

ISBN: (纸本)9780979497575

depleted-reservoirs underground gas storage are playing an increasingly important role in seasonal demanding of natural gas, ensuring stable gas supply and strategic reserves. However, due to the physical properties of the reservoir, the problem of sand production in the wellbore cannot be ignored. This research is based on the high-pressure sand production experiment simulation device system. Using the in-situ core, through experiments to simulate the sand production of the high-pressure gas storage reservoir, the sand production is systematically and quantitatively studied. The experimental results show that there are two key pressures for sand production caused by the destruction of the inner wall of the wellbore, namely, the equivalent initial sand production pressure (critical confining pressure) and the strength of the thick-walled barrel (collapse pressure). After the confining pressure exceeds the equivalent initial sand production pressure, the core begins to produce sand, and the sand has a relatively smaller particle size. The sand production is found to increases linearly with the equivalent confining pressure. After the confining pressure exceeds the strength of the thick-walled barrel, the core body is damaged and a large amount of sand is produced. The sand body has a relatively large particle size. The particle size distribution indicates the increase of sand particle size during the sand production of the gas storage well. This experiment provides guidance for the operation and completion of gas storage in depleted oil reservoirs, and also provides a quantitatively experimental method for the study of wellbore sand production. © 2022 ARMA, American Rock Mechanics Association.

关键词： Sand

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Lithology-controlled stress variations of Longmaxi shale–Example of an appraisal wellbore in the Changning area

Rock Mechanics Bulletin

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Rock Mechanics Bulletin 2022年第1期1卷 53-68页

作者： Xiaodong Ma Shihuai Zhang Xiaowen Zhang Jiandong Liu Juan Jin Wei Cheng Weidong Jiang Guangming Zhang Zhaowei Chen Mark d.Zoback ETH Zürich Department of Earth SciencesSwitzerland Research Institute of Petroleum Exploration&Development PetroChinaChina Key Laboratory of Oil&Gas Production CNPCChina CNPC Engineering Technology R&D Company Limited China Stanford University Department of GeophysicsUnited States

The Longmaxi shale is an extensive,prolific unconventional play in southwestern *** development in the Changning area is affected by ineffective hydraulic fracturing(HF)stimulation,fault reactivation and casing *** is suspected that the stress contrast within and between the shale reservoirs and the formations above and below matters to hydraulic fracture propagation and reservoir *** this end,the Longmaxi shale in the Changning area deserves a dedicated quantification of the in situ stress state and its *** this study,we re-visit the available data from one of the play’s first appraisal wellbores(X01)for an integrated geomechanics study,focusing on profiling the stress across the Longmaxi and its adjacent *** geophysical logs and other stress indicators,we re-interpret its stress profile in the context of lithological *** resulting stress variations are modeled primarily through a viscoplastic stress relaxation framework,compared with the results via the frictional equilibrium and an elastic theory(the Extended Eaton model).We offer some discussions on the differences and similarities of these stress profiling methods,and examine their applicability to Longmaxi shale in the Changning *** objective is to connect the lithology-controlled stress variations to the first-order complexities(HF ineffectiveness and fault reactivation)that have been observed in the area to date.

关键词： China shale formations

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Coupling Prediction Model and Influencing Factors Analysis of Injection and Production Gas Flow Rate and Wellhead Pressure for Compressed Air Energy Storage in Salt Cavern

SSRN

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SSRN 2024年

作者： Ren, Qianyu Wang, Jiangshuai Fu, Pan School of Energy School of Oil and Gas Engineering Changzhou University China CNPC Engineering Technology R&D Company Limited China National Engineering Research Center for Oil & Gas Drilling and Completion Technology China

关键词： Compressed air

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determination of critical fracturing spacing affecting the simultaneous growth of multiple hydraulic fractures from a horizontal wellbore 57

Determination of critical fracturing spacing affecting the s...

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57th US Rock Mechanics/Geomechanics Symposium

作者： Cheng, Shaoyi Wu, Bisheng Han, Yanhui Zhang, Xi Chen, Zhaowei Tan, Peng Yang, Liu State Key Laboratory of Hydroscience and Engineering Department of Hydraulic Engineering Tsinghua University Beijing100084 China Aramco Americas: Aramco Research Center HoustonTX77084 United States Faculty of Engineering China University of Geosciences Wuhan430074 China CNPC Engineering Technology R&D Company Limited Beijing102206 China Beijing100083 China

ISBN: (纸本)9780979497582

The multi-stage hydraulic fracturing and horizontal well have become the most important technologies in extracting oil and gas from unconventional reservoirs. However, the stress shadow effect often hinders the simultaneous growth of multiple fractures when design parameters such as fracture spacing and injection parameters are not set properly. Therefore, one of the key issues in a fracturing treatment is the determination of the fracture spacing within a fracturing stage under different combinations of geomechanical and injection parameters. This paper presents a numerical study by using the in-house code, deepFrac, a fully coupled hydraulic fracturing simulator based on the dual boundary element method and finite volume method. The evolution of the optimal fracture spacing with the geomechanical and injection parameters is investigated. The results demonstrate the dependence of the optimal fracture spacing on the energy dissipation and in-situ stress contrast. A dimensional analysis is carried out, and two dimensionless groups are determined including the dimensionless toughness and dimensionless in-situ stress difference. A critical fracturing spacing is proposed based on the dimensionless groups, which can capture the combined role of different parameters in the fracture growth. The effectiveness of the proposed critical fracturing spacing determination criterion is verified by a few additional numerical experiments. © 2023 57th US Rock Mechanics/Geomechanics Symposium. All Rights Reserved.

关键词： Hydraulic fracturing

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Simulation Experiment of Sediment Sealing in Old Well of Underground Gas Storage (Ugs)

SSRN

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SSRN 2024年

作者： Zhang, Yuda dong, Jingnan Liu, Tianen Guan, Yueyang Ban, Fansheng Yuan, Guangjie Research Institute of Petroleum Exploration & Development PetroChina Beijing100083 China CNPC Engineering Technology R&D Company Limited Beijing102206 China National Engineering Laboratory of Petroleum Drilling Technology Beijing102206 China National Elite Institute of Engineering CNPC Beijing100096 China

UGS is the key place to ensure the stable supply of natural gas, and the plugging effect of old wells will be seriously affected due to its characteristics of strong and alternating injection and withdrawal. In order to study the plugging of old wells with fishing and buried by sediment, a full-scale wellbore sediment sealing simulation experiment and a small-scale core permeability experiment were designed. Considering the factors such as sediment composition, compaction degree and metal surface roughness, the compaction law of fillers and the change law of permeability with rock cuttings content under different top hydraulic conditions were analyzed. The experimental results show that there are two kinds of sealing failure in old wells. One is gas breakthrough, the breakthrough pressure difference is 1.3-2.7 MPa, the breakthrough time is about 30 s, and the dominant channel is the interface between sediment and casing and fishing. The other is gas leakage. The permeability range of the sediment is 0.0024-0.031 d, and the reservoir gas flows along the pore channel of the sediment. This study simulates the sediment plugging old wells in the range of gas storage site, and provides reference for the sealing failure process and mechanism of old wells. © 2024, The Authors. All rights reserved.

关键词： Sediments

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