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Evaluation and Application of Flowback Effect in deep shale gas Wells

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Fluid Dynamics & Materials Processing 2024年第10期20卷 2301-2321页

作者： Sha Liu Jianfa Wu Xuefeng Yang Weiyang Xie Cheng Chang shale gas Research Institute PetroChina Southwest Oil&Gas field CompanyChengdu610051China

The pivotal areas for the extensive and effective exploitation of shale gas in the Southern Sichuan Basin have recently transitioned from mid-deep layers to deep *** challenges such as intricate data analysis,absence of effective assessment methodologies,real-time control strategies,and scarce knowledge of the factors influencing deep gas wells in the so-called flowback stage,a comprehensive study was undertaken on over 160 deep gas wells in Luzhou block utilizing linear flow models and advanced big data analytics *** research results show that:(1)The flowback stage of a deep gas well presents the characteristics of late gas channeling,high flowback rate after gas channeling,low 30-day flowback rate,and high flowback rate corresponding to peak production;(2)The comprehensive parameter AcmKm1/2 in the flowback stage exhibits a strong correlation with the Estimated Ultimate Recovery(EUR),allowing for the establishment of a standardized chart to evaluate EUR classification in typical shale gas wells during this *** enables quantitative assessment of gas well EUR,providing valuable insights into production potential and performance;(3)The spacing range and the initial productivity of gas wells have a significant impact on the overall effectiveness of gas ***,it is crucial to further explore rational well patterns and spacing,as well as optimize initial drainage and production technical strategies in order to improve their performance.

关键词： deep shale gas flowback characteristic EUR forecast effect evaluation main controlling factors

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

A numerical investigation on deep shale gas recovery

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Energy Geoscience 2021年第4期2卷 274-284页

作者： Changqing Liu Yan Liang Kaiming Wang Research Institute of Exploration and Exploitation SINOPEC East China Oil and Gas CompanyNanjingJiangsu210000China Jiangsu Maritime Institute Nanjing210000China

In recent years,exploration and development of deep shale gas(at a burial depth of 3,500-4,500 m)has become a hotspot in the ***,the state of gas storage and transporting mechanism for deep shale gas under high pressure and temperature have not been thoroughly explored,compared with its shallower counterpart.A numerical model for deep shale gas recovery considering multi-site nonisothermal excess adsorption has been established and applied using Finite Element *** from the simulation reveal the following.(1)Excess desorption significantly impacts early-stage performance of deep shale gas well;the conventional way for shallower shale gas development,in which the density of adsorbed gas is not distinguished from that of free gas,overestimates the gas in place(GIP).(2)Although thermal stimulation can speed up the desorption and transporting of deep shale gas,the incremental volume of produced gas,which is impacted not only by seepage velocity but also density of gas,is insignificant,far from *** an additional 2.03%of cumulative gas would be produced under treatment temperature of 190C and initial reservoir temperature of 90C in a period of 5 years.(3)Matrix porosity,which can be measured on cores in laboratory and/or estimated by using well logging and geophysical data,is the most favorable parameter for deep shale gas *** 60%increase in matrix porosity,an extra 67.25%shale gas on a daily base would be recovered even after 5-year depletion production;(4)Production rate for gas wells in shale reservoirs at 3,500 m and 4,500 m deep would be raised by 5.4%in a 5-year period if the depth of target interval would increase by 340 m without thermal treatment according to the numerical model proposed in the study.

关键词： deep shale gas Excess adsorption Multi-site Langmuir isotherm Non-isothermal Discrete fracture network

Technical Challenges and Countermeasures for deep shale gas Drilling by SINOPEC

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China Oil & gas 2018年第3期25卷 31-39页

作者： Zang Yanbin State Key Laboratory of shale Oil and gas Enrichment Mechanisms and Effective Development SINOPEC Research Institute of Petroleum Engineering

deep shale gas reservoirs being developed by SINOPEC are characterized by significant buried depths, high rock strengths, high temperatures and pressures, multiple layers, low ROPs, prolonged drilling time and prohibitoryhigh costs. All of these factors may negatively affect the economic and effective development of shale gas. Under such circumstances, existing drilling techniques for deep shale gas around the world have been reviewed to highlight technical challenges in deep shale gas drilling in China. With consideration to the previous drilling operations of SINOPEC for deep shale gas, technical solutions for deep shale gas drilling have been proposed with regard to the optimization of casing programs, enhanced drilling, trajectory control, high-density oil-based drilling fluid, cementation for deep shale gas development and other aspects. Some of these research findings have been deployed with great successes in Pingqiao, Jiangdong Block in the 2nd Phase of Fuling Project, Dingshan Block and other blocks with deep shale gas development. Among them, Well JY-74-2HF has had a drilling time of only 54.25d, whereas Well JY-187-2HF has a TVD up to 4024.14m. Relevant research results may provide valuable guidance and references for the optimization of drilling programs andthe enhancement ofdrilling ef^ciency for deep shale gas development.

关键词： deep shale gas Horizontal well Casing program Trajectory control Enhanced drilling

Porosity, permeability and rock mechanics of Lower Silurian Longmaxi Formation deep shale under temperature-pressure coupling in the Sichuan Basin, SW China

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Petroleum Exploration and Development 2023年第1期50卷 85-98页

作者： SUN Chuanxiang NIE Haikuan SU Haikun DU Wei LU Ting CHEN Yalin LIU Mi LI Jingchang State Key Laboratory of shale Oil and gas Enrichment Mechanisms and Effective Development Beijing 102206China Sinopec Petroleum Exploration and Production Research Institute Beijing 102206China Sinopec Key Laboratory of shale Oil/gas Exploration&Production Beijing 102206China School of Energy Resources China University of GeosciencesBeijing 100083China Research Institute of Petroleum Exploration and Development Sinopec Jianghan Oilfield CompanyWuhan 430223China

To investigate the porosity, permeability and rock mechanics of deep shale under temperature-pressure coupling, we selected the core samples of deep shale from the Lower Silurian Longmaxi Formation in the Weirong and Yongchuan areas of the Sichuan Basin for porosity and permeability experiments and a triaxial compression and sound wave integration experiment at the maximum temperature and pressure of 120 ℃ and 70 MPa. The results show that the microscopic porosity and permeability change and the macroscopic rock deformation are mutually constrained, both showing the trend of steep and then gentle variation. At the maximum temperature and pressure, the porosity reduces by 34%–71%, and the permeability decreases by 85%–97%. With the rising temperature and pressure, deep shale undergoes plastic deformation in which organic pores and clay mineral pores are compressed and microfractures are closed, and elastic deformation in which brittle mineral pores and rock skeleton particles are compacted. Compared with previous experiments under high confining pressure and normal temperature,the experiment under high temperature and high pressure coupling reveals the effect of high temperature on stress sensitivity of porosity and permeability. High temperature can increase the plasticity of the rock, intensify the compression of pores due to high confining pressure, and induce thermal stress between the rock skeleton particles, allowing the reopening of shale bedding or the creation of new fractures along weak planes such as bedding, which inhibits the decrease of permeability with the increase of temperature and confining pressure. Compared with the triaxial mechanical experiment at normal temperature, the triaxial compression experiment at high temperature and high pressure demonstrates that the compressive strength and peak strain of deep shale increase significantly due to the coupling of temperature and pressure. The compressive strength is up to 435 MPa and the peak strain e

关键词： Sichuan Basin Longmaxi Formation deep shale gas porosity permeability rock mechanics high temperature and high pressure triaxial compression

Comprehensive Evaluation of Geological and Engineering Sweet Spots of shale gas Reservoir: A Case Study of the Luzhou Block, Sichuan Basin

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International Journal of Geosciences 2021年第11期12卷 1021-1039页

作者： Yuan Wang Jianfa Wu Li Fu Haoyong Huang Gang Chen Cheng Chang CNPC Engineering Technology R & D Company Limited Beijing China Southwest Oil and gas Field Company of CNPC Chengdu China

There is a huge amount of marine shale gas resources in the southern Sichuan Basin in China, and most of the resources are at the buried depth of 3500 - 4500 meters. At present, deep shale gas is in the early stage of exploration and development. In order to achieve large-scale efficient development, in addition to optimizing favorable blocks, it is also to identify the optimal target in the vertical direction combine geology, drilling, and fracturing. Therefore, Taking the Longmaxi formation shale in the Luzhou block as the research object, based on drilling, logging, and core experiment data, through single well and 3D geomechanical modeling methods, analyze the characteristics of organic matter abundance, porosity, pore pressure, collapse pressure, mineral composition and in-situ stress of different layers of shale in Longmaxi formation. Systematically summarized the main controlling factors of the “sweet spot” of deep shale gas and establish the comprehensive evaluation system of deep shale gas “sweet spots”, to clarify the optimal “sweet spots” of geology, drilling, and fracturing in the Longmaxi reservoir. Results show that the total organic carbon content, porosity, and gas saturation of the long111 layer are higher than other layers. The Long111 layer has a low collapse pressure and a high compressive strength, the risk of wellbore instability is relatively low. The stress difference coefficient of All layers is less than 0.3, and the brittleness index of the Long111 layer is 62.35%. A complex fracture network is easier to form after fracturing. The conclusion shows that the Long111 layer is the optimal reservoir section of the Longmaxi Formation. Ensure the drilled rate of the Long111 layer and maximize the length of the horizontal section can obtain higher production.

关键词： deep shale gas Geological Sweet Spots Engineering Sweet Spots Geomechanical Modeling