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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

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New technology for Improving Water Flooding Efficiency by Adjusting Advantage Channels 8th

New Technology for Improving Water Flooding Efficiency by Ad...

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8th International Field Exploration and development Conference, IFEdC 2019

作者： Shao, Li-ming Fang, Ping-liang Wei, Fa-lin dai, Ming-li Li, Wei-tao Research Institute of Petroleum Exploration and Development PetroChina Beijing100083 China CNPC Engineering Technology R&D Company Limited PetroChina Beijing100083 China

ISBN: (纸本)9789811524844

Underground cross-linking profile control and water shutoff and deep fluid flow to chemical agent system are usually composed of main agent, cross-linking agent and additives. The cost of cross-linking agent and additives generally accounts for 30–50% of the total cost of the system. Many inorganic salt ions are widely used as cross-linking agent or additives. In this paper, using Ca2+ and Mg2+ scale forming ion source in CaCl2 water type oilfield high salinity formation water (as water injection) as crosslinking agent, cross-linking of original inorganic microgel is carried out to reduce the cost of steering agent. The formation of nano microscale inorganic microgel with density similar to that of environmental water source can be formed by cross-linking of the steering agent with scale forming ions in formation water. The microgel can be dispersed or suspended in water, and gradually adsorbed on the rock skeleton of the dominant channel such as hole or crack to form a micro gel coating in order to narrow the flow dominant channel and form resistance to flow. The passage of plugging does not die, achieving the purpose of adjusting the dominant channel, expanding the volume and improving the efficiency of water flooding. At the same time, the particle size of the micro gel can prevent it from entering the low permeability matrix to contaminate the oil layer. The diversion agent has the characteristics of rapid dissolution, temperature resistance, salt resistance, environmental protection, long-term effectiveness and no construction risk. Field tests of deep profile control and flooding have been carried out in reservoirs with different temperature and salinity at home and abroad. After profile control diversion in test blocks or well groups, the effect of improving water flooding is good. The average increase of water injection pressure is 2–3 MPa, and the effective rate of increasing oil production and precipitation in oil wells is more than 80%, and the validity p

关键词： Chlorine compounds

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Investigation of hydraulic fracture propagation in conglomerate reservoirs using discrete element method

Investigation of hydraulic fracture propagation in conglomer...

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ARMA-CUPB Geothermal International Conference 2019

作者： Shentu, Junjie Lin, Botao dong, Jingnan Yu, Huiyong Shi, Shanzhi Ma, Junxiu State Key Laboratory of Petroleum Resources and Prospecting and College of Petroleum Engineering China University of Petroleum Beijing102249 China CNPC Engineering Technology R&D Company Limited Beijing China PetrolChina Xinjiang Oilfield Company Engineering Technology Research Institute Karamay834000 China

Hydraulic fracturing has been widely used in the development of conglomerate reservoirs in the Karamay oilfield Xinjiang, China. Understanding the influences of large and irregular conglomerate particles on the fracture propagation behavior is crucial for the fracturing design of reservoirs of this type. This study numerically captured the associated fracturing process and thoroughly analyzed the impact of conglomerate particles by adopting the discrete element method. The simulation results indicated that the existence of conglomerate particles conspicuously increase the breakdown pressure of the conglomerate formations. Several scenarios were designed to investigate the influence of content and strength of conglomerate particles, respectively. It was found the fitting relationship was nonlinear between breakdown pressure and particle content and was linear between breakdown pressure and particle strength. Conglomerate particles affected fracture behavior in two patterns, namely penetration and circumvention. However, under certain in-situ stress condition, the conglomerate particles had negligible impact on the principal direction of fracture propagation. The simulation results are advantageous to instruct the field fracturing operations, such as the selection of hydraulic fracturing site and injection parameters. Copyright © ARMA-CUPB Geothermal International Conference *** rights reserved.

关键词： Fracture

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Experimental investigation of geometric effects on rock mechanical behaviors

Experimental investigation of geometric effects on rock mech...

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ARMA-CUPB Geothermal International Conference 2019

作者： Li, Hui Lai, Bitao Cai, Xiao Lele, Cao Tian, Lu Li, Ben State Key Laboratory of Petroleum Resources and Engineering Beijing China China University of Petroleum Beijing China Aramco Services Company-Houston Research Center Houston United States CNPC Engineering Technology R&D Company Limited Beijing China

Rock mechanical properties introduced terms such as strength, elastic modulus and Poisson's ratio, etc. which are important in petroleum engineering. The determination of reservoir's mechanical properties is critical to reduce drilling risk and maximize well and reservoir productivity. Estimates of rock mechanical properties are crucial to drilling programs, well placement, and well-completion design. Rocks are heterogeneous and anisotropic materials. Therefore, rock mechanical properties vary not only with rock types, but also with measurement method, samples geometric dimension (sample length to diameter ratio and size), and other factors. In this study, uniaxial compressive tests were conducted on 31 different dimensions of Berea sandstone samples and 16 different dimensions of Eagle Ford shale cores to investigate the sample geometric effects on rock mechanical properties, including unconfined compressive strength, Young's Modulus and Poisson's ratio. The results show that sample geometry has significant impacts on rock mechanical properties: (1) For Berea sandstones, UCS decrease with increase of length to diameter ratio, and the UCS standardize factor is between 0.8 and 1.2, which means ±20% variation of UCS with length to diameter change. For Eagle Ford shale, UCS significantly decrease with increase of length to diameter ratio, and the UCS standardize factor is between 0.6 and 1.7, which illustrates up to 70% variation of UCS caused by length to diameter ratio change. For Berea sandstones, UCS exhibits the positive relationship with sample size, while for the tested Eagle Ford shale cores, the relationship of UCS and sample size is not clear. (2) For Berea sandstones, Young's modulus slightly increases with length to diameter ratio increase. However, the relationship of Young' modulus and length to diameter ratio of Eagle Ford shale is not clear in this research. (3) For both Berea sandstone and Eagle Ford cores, Poisson's ratio decreases with increasing len

关键词： Poisson ratio

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Controllable Synthetic Carbon dots: A Promising Method for Reducing Injection Pressure in Matrix by Regulating Oil/Water/Rock Interface Properties

SSRN

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SSRN 2023年

作者： Cao, Mengjiao Li, Yuan Song, Xuguang Chen, Yesheng Sun, Linghui Shi, Xin dai, Caili Yuan, Bin School of Petroleum Engineering China University of Petroleum（East China） Qingdao266580 China Sinopec Research Institute of Petroleum Engineering Fracturing & Acidizing and Natural Gas Production Research Institute Dongying257000 China Department of Chemical and Materials Engineering University of Alberta EdmontonABT6G 1H9 Canada CNPC Engineering Technology R&D Company Limited Beijing Petroleum Machinery Company China China Academy of Science Institute of Porous Flow & Fluid Mechanics Beijing100083 China Sinopec Northwest China Petroleum Bureau Urumqi830011 China

Effective development of unconventional resources is impeded by water flooding-related challenges, such as high pressure and under-injection, which hinder the replenishment of formation energy. Nanofluids have shown promise in reducing injection pressure, but traditional nanoparticles (NPs) face limitations in unconventional reservoirs due to their unsuitable size for micro-nano pores and aggregation tendencies. In this paper, novel carbon dots (Cds) with a simple, environmentally benign, and controllable synthetic approach have been developed, and their pressure-reduction performance and mechanism have been systematically explored. The particle size of the Cds could be tailored by a well-timely quenching reaction. Cds nanofluid demonstrated superior stability, dispersibility, and temperature/salinity resistance. In addition, Cds can regulate interfacial properties, including oil/rock and oil/water interfaces. It was found that Cds could be partially absorbed onto pore walls, reducing oil adhesion sites by 39%, altering wettability from oil-wet to neutral, and reducing rock surface roughness by 29.25%. Furthermore, Cds were rapidly adsorbed onto the remaining oil film in the pore space, reducing interfacial tension while solidifying the oil surfaces, increasing shear force around the oil surface by 1.7 times during subsequent water scouring, which makes the oil film break up more readily and remain smaller in size to migrate in the channeling. The modulation of the interface properties by Cds improved the stripping efficiency of the attached oil film and ameliorated the homogeneity and smoothness of flow channel, resulting in a significant reduction in injection pressure. Core displacement tests showed that a 0.1wt% Cds nanofluid could achieve a pressure reduction rate of 35%. The developed Cds nanofluid represents a promising solution for reducing injection pressure and improving oil recovery in unconventional reservoirs. © 2023, The Authors. All rights reserved.

关键词： Particle size

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A three dimensional visualized physical simulation for natural gas charging in the micro-nano pore system

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Petroleum Exploration and development 2022年第2期49卷 349-362页

作者： QIAO Juncheng ZENG Jianhui XIA Yuxuan CAI Jianchao CHEN dongxia JIANG Shu HAN Guomeng CAO Zhe FENG Xiao FENG Sen- State Key Laboratory of Petroleum Resources and Prospecting China University of PetroleumBeijing 102249.China College of Geosciences China University of PetroleumBeijing 102249China Institute of Geophysics and Geomatics China University of GeosciencesWuhan 430074China Key Laboratory of Tectonics and Petroleum Resources of Ministry of Education China University of GeosciencesWuhan 430074China Dagang Oilfield Company PetroChinaTianjin 300280China Sinopec Petroleum Exploration and Production Research Institute Beijing 102206China CNPC Engineering Technology R&D Company Limited Beijing 102206China

A micro-nano pore three-dimensional visualized real-time physical simulation of natural gas charging, in-situ pore-scale computation, pore network modelling, and apparent permeability evaluation theory were used to investigate laws of gas and water flow and their distribution, and controlling factors during the gas charging process in low-permeability(tight) sandstone reservoir. By describing features of gas-water flow and distribution and their variations in the micro-nano pore system, it is found that the gas charging in the low permeability(tight) sandstone can be divided into two stages, expansion stage and stable stage. In the expansion stage, the gas flows continuously first into large-sized pores then small-sized pores, and first into centers of the pores then edges of pores;pore-throats greater than 20 μm in radius make up the major pathway for gas charging. With the increase of charging pressure, movable water in the edges of large-sized pores and in the centers of small pores is displaced out successively. Pore-throats of 20-50 μm in radius and pore-throats less than 20 μm in radius dominate the expansion of gas charging channels at different stages of charging in turn, leading to reductions in pore-throat radius, throat length and coordination number of the pathway, which is the main increase stage of gas permeability and gas saturation. Among which, pore-throats 30-50 μm in radius control the increase pattern of gas saturation. In the stable stage, gas charging pathways have expanded to the maximum, so the pathways keep stable in pore-throat radius, throat length, and coordination number, and irreducible water remains in the pore system, the gas phase is in concentrated clusters, while the water phase is in the form of dispersed thin film, and the gas saturation and gas permeability tend stable. Connected pore-throats less than 20 μm in radius control the expansion limit of the charging pathways, the formation of stable gas-water distribution, and the ma

关键词： low permeability(tight)sandstone gas charging three-dimensional visualization physical simulation micro-nanometer pore network gas and water flow and distribution

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Pore-Scale Understandings for Steady-State Two-Phase Flow in Natural Porous Media from Pore Connectivity Quantification

SSRN

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SSRN 2023年

作者： Qiao, Juncheng Zeng, Jianhui An, Ting Jiang, Shu Ma, Yong Liu, Yazhou Chen, dongxia Cai, Jianchao Zhang, Yongchao Feng, Xiao Cao, Zhe Sun, Chenhao State Key Laboratory of Petroleum Resources and Prospecting China University of Petroleum Beijing102249 China College of Geosciences China University of Petroleum Beijing102249 China Fengcheng Oilfield operation District Xinjiang Oilfield Company CNPC Karamay834000 China Energy & Geosciences Institute Department of Chemical Engineering University of Utah UT84108 United States Key Laboratory of Tectonics and Petroleum Resources of Ministry of Education School of Earth Resources China University of Geosciences Wuhan430074 China The Key Laboratory of Gas Hydrate Ministry of Natural Resources Institute of Marine Geology Qingdao266071 China CNPC Engineering Technology R&D Company Limited Beijing102206 China Sinopec Petroleum Exploration and Production Research Institute Beijing102206 China

Fluid and chemical transport in the connected pore system of various natural porous sandstone governs numerous energetic and industrial activities. A nanometer-millimeter pore connectivity quantification is compiled,on the basis of which steady-state two-phase flow physics are explored. Connectivity evaluation indicates that high permeable sandstone shares a reticular connection network with scale-invariant connected ratio stays at around 0.60, low-permeability sandstone exhibits branch-like pattern with the ratio ranging from 0.53 to 0.60, while tight sandstone is characterized by local chain-like pattern with an average ratio of 0.31. With decreasing connectivity degree, differed deviated linear and power-law flows present in the fractional non-wetting phase flow of steady-state two-phase flow. A coupled phase’s mobility, dynamic phase’s interactions, and dynamic non-wetting phase flow paths evaluations based on the connectivity quantification, incorporating dLVO theory, augmented Young-Laplace equation, and effective hydraulic radius model, explain the reasons for flow regime distinctions. It indicates that the full-range connected pore size distribution determines multiphase mobility potential and dynamic multiphase interaction force, which successively control the dynamic expansion of non-wetting phase pathway. differences in preferential non-wetting phase flow path expansions and accompanying non-wetting phase flow resistances in the connected pores © 2023, The Authors. All rights reserved.

关键词： Two phase flow

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Study on rock breaking efficiency of special shaped cutters

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IOP Conference Series: Earth and Environmental Science 2022年第1期983卷

作者： Qi Peng Yingcao Zhou Jiaqing Yu Xiongwen Yang Yu Liu Chi Ma Chris Cheng Xiaohua Ke CNPC Engineering Technology R & D Company Limited Beijing China Research Institute of Petroleum Exploration & Development Beijing China CNPC USA Corporation (Houston TX USA)

The optimization of cutter shape has become one of the main innovation direction of PdC bit technology. At present, both domestic and foreign bit manufacturers have put forward various special shaped cutters to improve rock breaking efficiency. However, there are relatively few researches which focus on the rock breaking efficiency of special-shaped cutters. Therefore, three kinds of typical cutters (flat cutter, convex cutter and concave cutter) are selected as the study object in this paper. Based on the single cutter test, the relationship of axial cutting force, cutting area and cutting specific energy under different working conditions will be provided. The experimental results show that the axial cutting force and specific energy of concave cutter and convex cutter are lower than that of flat cutter in most test cases. The results are almost the same for both Vosges sandstone and Marcellus shale cases. In other words, the tested concave cutters are easier to intrude into rock and obtain higher rock brea king efficiency under the same cutting conditions, when compared with flat cutter and convex cutter. The experimental method provides a technica l reference for studying the rock breaking efficiency of three-dimensional cutters with different shapes.

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Measurement device for near-bit dynamic parameters while drilling 26

Measurement device for near-bit dynamic parameters while dri...

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26th International Congress on Sound and Vibration, ICSV 2019

作者： Li, Ning Jia, Hengtian Teng, Xueqing Zhang, Quan Bo, Zhou Gao, Wenkai PetroChina Tarim Oilfield Company Research Institute of Oil and Gas Engineering Korla841000 China CNPC Engineering Technology R and D Company Limited Downhole Control Engineering Department Beijing102206 China

ISBN: (纸本)9781999181000

In the process of oil and gas drilling engineering, measurement of downhole parameters while drilling is very important. Especially for the drilling of multi-branch wells and horizontal wells, the downhole condition is more complex, which leads to the increase of the incidence of drilling accidents. Accidents such as damage of drill tools and sticking often occur in the process of oil drilling. The occurrence of these accidents is closely related to the real-time engineering parameters of drilling. Therefore, real-time monitoring of downhole torque, drill-fluid pressure, rotation rate, annular pressure, vibration and other parameters are of great significance for well drilling and the prevent of accidents. Here we developed a kind of near-bit measurement system for dynamic parameters while drilling, which can measure the torque and weight on bit, pressure of drilling mud, rotational speed and triaxial vibration in real time while drilling. Real-time analysis of the downhole data can be used to evaluate the performance of the downhole tools and prevent drilling accidents. The paper briefly introduced the work principles, composition and application of the system © Proceedings of the 26th International Congress on Sound and Vibration, ICSV 2019. All rights reserved.

关键词： Infill drilling

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A dynamic model and application of the downhole drilling system with fluid-structure interaction 26

A dynamic model and application of the downhole drilling sys...

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26th International Congress on Sound and Vibration, ICSV 2019

作者： Li, Ning Hong, difeng Zhang, Quan Bo, Zhou Zhao, Li Gao, Wenkai PetroChina Tarim Oilfield Company Research Institute of Oil and Gas Engineering Korla841000 China CNPC Engineering Technology R and D Company Limited Downhole Control Engineering Department Beijing102206 China

ISBN: (纸本)9781999181000

It is intended to present dynamic model of the drilling system consists of drillstring and drilling fluid. The drillstring is a sequence of Euler-Bernoulli beam elements with some constraints and loads. Its dynamic model is established by using the absolute nodal coordinate formulas (ANCF). The drilling fluid is composed of three sequences of one-dimensional compressible fluid elements. The three sequences represent internal, annulus and under-bit fluid each. The drilling fluid is modeled by using the Arbitrary Lagrangian-Eulerian (ALE) description, where the force of the drillstring acting on the drilling fluid is introduced through the drilling fluid transport motion, meanwhile, the reaction force acting on the drillstring is taken as an external load. The model also considers the boundary conditions in usual drilling engineering at the bit, at the top, at the connection and at the inner surface of the wellbore. Using this model, the coupled vibration of the drillstring and the effects of the drilling fluid are investigated through several examples © Proceedings of the 26th International Congress on Sound and Vibration, ICSV 2019. All rights reserved.

关键词： drilling fluids

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