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Spatial-temporal coupling between high-quality source rocks and reservoirs for tight sandstone oil and gas accumulations in the Songliao Basin, China

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International Journal of Mining Science and Technology 2019年第3期29卷 387-397页

作者： Laixing Cai Guolin Xiao shuangfang lu Jiao Wang Zhiqiang Wu Qingdao Institute of Marine Geology Qingdao 266071China Laboratory for Marine Mineral Resources Pilot National Laboratory for Marine Science and Technology (Qingdao)Qingdao 266237China Research Institute of Unconventional Petroleum and Renewable Energy China University of Petroleum (East China)Qingdao 266580China

The spatial-temporal relationship between high-quality source rocks and reservoirs is a key factor when evaluating the formation,occurrence,and prospectivity of tight oil and gas reservoirs.In this study,we analyze the fundamental oil and gas accumulation processes occurring in the Songliao Basin,contrasting tight oil sand reservoirs in the south with tight gas sand reservoirs in the north.This is done using geochemical data,constant-rate and conventional mercury injection experiments,and fluid inclusion analyses.Our results demonstrate that as far as fluid mobility is concerned,the expulsion center coincides with the overpressure zone,and its boundary limits the occurrence of tight oil and gas accumulations.In addition,the lower permeability limit of high-quality reservoirs,controlled by pore-throat structures,is 0.1×10^-3μm^2 in the fourth member of the Lower Cretaceous Quantou Formation(K1q^4)in the southern Songliao Basin,and 0.05×10^-3μm^2 in the Lower Cretaceous Shahezi Formation(K1sh)in the northern Songliao Basin.Furthermore,the results indicate that the formation of tight oil and gas reservoirs requires the densification of reservoirs prior to the main phase of hydrocarbon expulsion from the source rocks.Reservoir“sweet spots”develop at the intersection of high-quality source rocks(with high pore pressure)and reservoirs(with high permeability).

关键词： Spatial-temporal coupling High-quality source rock High-quality sandstone Tight sandstone reservoir Songliao Basin

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Carbon isotope fractionation during shale gas transport: Mechanism, characterization and significance

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Science China Earth Sciences 2020年第5期63卷 674-689页

作者： Wenbiao LI shuangfang lu Junqian LI Pengfei ZHANG Siyuan WANG Wenjun FENG Yongbo WEI School of Geosciences China University of Petroleum(East China)Qingdao 266580China College of Earth Science and Engineering Shandong University of Science and TechnologyQingdao 266590China

The gas in-place(GIP)content and the ratio of adsorbed/free gas are two key parameters for the assessment of shale gas resources and have thus received extensive attention.A variety of methods have been proposed to solve these issues,however none have gained widespread acceptance.Carbon isotope fractionation during the methane transport process provides abundant information,serving as an effective method for differentiating the gas transport processes of adsorbed gas and free gas and ultimately evaluating the two key parameters.In this study,four stages of methane carbon isotope fractionation were documented during a laboratory experiment that simulated gas transport through shale.The four stages reflect different transport processes:the free gas seepage stage(Ⅰ),transition stage(Ⅱ),adsorbed gas desorption stage(Ⅲ)and concentration diffusion stage(Ⅳ).Combined with the results of decoupling experiments,the isotope fractionation characteristics donated by the single effect(seepage,adsorption-desorption and diffusion)were clearly revealed.We further propose a technique integrating the Amoco curve fit(ACF)method and carbon isotope fractionation(CIF)to determine the dynamic change in adsorbed and free gas ratios during gas production.We find that the gases produced in stage Ⅰ are primarily composed of free gas and that carbon isotope ratios of methane(δ13C1)are stable and equal to the ratios of source gas(13C 10).In stage Ⅱ,the contribution of free gas decreases,while the proportion of adsorbed gas increases,and the δ13C1 gradually becomes lighter.With the depletion of free gas,the adsorbed gas contribution in stage Ⅲ reaches 100%,and the δ13C1 becomes heavier.Finally,in stage Ⅳ,the desorbed gas remaining in the pore spaces diffuses out under the concentration difference,and the δ13C1 becomes lighter again and finally stabilizes.In addition,a kinetic model for the quantitative description of isotope fractionation during desorption and diffusion was established.

关键词： Shale gas Carbon isotope fractionation Seepage Adsorption-desorption Diffusion Gas in-place content Adsorbed/Free gas ratio

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Scale-Dependent Nature of Porosity and Pore Size Distribution in Lacustrine Shales: An Investigation by BIB-SEM and X-Ray CT Methods

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Journal of Earth Science 2019年第4期30卷 823-833页

作者： Junqian Li Pengfei Zhang shuangfang lu Chen Chen Haitao Xue Siyuan Wang Wenbiao Li School of Geosciences China University of Petroleum (East China)

Due to heterogeneous pore distributions within shales,petrophysical properties of shales determined by scanning electron microscopy(SEM) and X-ray computed tomography(CT) methods strongly depend on the observed domain size(analysis scale). In this paper,the influence of the analysis scale on areal and bulk porosities and pore size distribution(PSD) for lacustrine shales from the Dongying sag of Bohai Bay Basin,China were investigated using broad ion beam(BIB)-SEM and X-ray CT methods.The BIB-SEM cross-sections with high imaging resolution(10 nm/pixel) and a large field of view(>1 mm2)mainly describe the 2 D nanoscale pore system in the two shales(samples F41#-2 and Y556#-1),while CTbased 3 D reconstructions with resolutions of 0.42(F41#-1) and 0.5 μm/pixel(H172#-1) reflect the 3 D submicron pore system. The results indicate that the areal(bulk) porosity exhibits a multiple power-law distribution with increasing analysis area(volume),which can be used to extrapolate the porosity of a given area(volume). Based on SEM and CT investigations,the sizes of the minimum representative elementary areas(REAs) and volumes(REVs) were determined respectively,which are closely associated with the heterogeneousness of the pore system. Minimum REAs are proposed to be 2.93×10~4(F41#-2) and 0.91×10~4μm2(Y556#-1),and minimum REVs are 0.016(F41#-1) and 0.027 mm^3(H172#-1). As the analyzed areas(volumes) are larger than the minimum REA(REV),obtained 2 D(3 D) PSDs are comparable to each other and can be considered to reflect the shale PSD. These results provide insights into the porosity and PSD characterization of shales by SEM and X-ray CT methods.

关键词： lacustrine shale porosity pore size distribution BIB-SEM X-ray CT

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Water Role and Its Influence on Hydrogen Isotopic Composition of Natural Gas during Gas Generation

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Acta Geologica Sinica(English Edition) 2011年第5期85卷 1203-1210页

作者： Jijun LI shuangfang lu Wei WU Haitao XUE Qingxia XU Jie GENG Yinghua YU College of Earth Sciences Northeast Petroleum University Daqing Heilongjiang 163318 China luliang Operating District of Xinjiang Oilfield Company Karamay Xinjiang 834000 China Exploration and Development Research Institute Daqing Oilfield Company Ltd. Daqing Heilongjiang 163712 China

In order to discuss the role and influence of water during the generation of natural gas,the participation mechanism of water during the evolution of organic matter and its influences were summarized.In addition,we carried out an anhydrous cracking experiment of oil extracted from the Feixianguan Formation source rock in a closed system,which led to the establishment of the kinetic models for describing carbon and hydrogen isotopic fractionation during gas generation from organic matter.The models were calibrated and then applied to the northeastern Sichuan Basin.By combining a series of gas generation experiments from octadecane pyrolysis without water or with distilled water in varying mass proportions,several results were proved:(1) the hydrogen isotopic composition of natural gas becomes lighter with the participation of formation water;(2) we can quantitatively study the hydrogen isotopic fractionation with the kinetic model for describing carbon isotopic fractionation; (3) more abundant and reliable geological information can be obtained through the combined application of carbon and hydrogen isotopic indices.

关键词： natural gas formation water free radical carbonium ion carbon and hydrogen isotopic fractionation kinetics

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Lacustrine Shale Oil Resource Potential of Es3L Sub-Member of Bonan Sag, Bohai Bay Basin, Eastern China

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Journal of Earth Science 2017年第6期28卷 996-1005页

作者： shuangfang lu Wei Liu Min Wang Linye Zhang Zhentao Wang Guohui Chen Dianshi Xiao Zhandong Li Huiting Hu Research Institute of Unconventional Petroleum and Renewable Energy (RIUP & RE) China University of Petroleum Qingdao 257015 China Geology Scientific Research Institute of Shengli Oilfield Co. Ltd. Dongying 257015 China Shandong Geological Environmental Monitoring Station Jinan 250014 China College of Petroleum Engineering Northeast Petroleum University Daqing 163318 China

Following shale gas, shale oil has become another highlight in unconventional hydrocarbon exploration and development. A large amount of shale oil has been produced from a host of marine shale in North America in recent years. In China, lacustrine shale, as the main source rock of conventional oil and gas, should also have abundant oil retained in place. In this study, geochemical and geologic characteristics of lacustrine shale from Es3L sub-member in Bonan sag were characterized by using total organic carbon（TOC）, Rock-Eval pyrolysis, X-ray diffraction, and ？log R method. The results show that the Es3L sub-member shale have TOC contents ranging from 0.5 wt.% to 9.3 wt.%, with an average of 2.9 wt.%. The organic matter is predominantly Type I kerogen, with minor amounts of Type II1 kerogen. The temperature of maximum yield of pyrolysate（Tmax） values ranges from 424 to 447 ℃, with an average of 440 ℃, and vitrinite reflectance（Ro%） ranges from 0.7% to 0.9%, indicating most of shales are thermally mature. The dominant minerals of Es3L shale in Bonan sag are carbonates（including calcite and dolomite）, averaging 51.82 wt.%, and the second minerals are clay（mostly are montmorillonite-illite-mixed layer and illite） and quartz, averaging about 18 wt.%. Finally, its shale oil resources were evaluated by using the volumetric method, and the evaluation result shows that the shale oil resource is up to 5.94 billion tons, and mostly Class I resource. Therefore, the exploration of the lacustrine shale oil of Es3L in Bonan sag should be strengthened.

关键词： shale oil resource potential EsL sub-member Bonan sag Bohai Bay Basin.

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基于耦合沉积动力学模拟与多点地质统计学方法的河口湾储层三维建模

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地球科学 2024年第1期49卷 174-188页

作者：唐佳凡唐明明卢双舫刘雪萍张克鑫何涛华韩迪中国石油大学深层油气重点实验室山东青岛266580 中国石化胜利油田分公司滨南采油厂山东东营256606 中国石油勘探开发研究院北京100871

为提高潮控河口湾储层中少井区三维建模精度,以南美Oriente盆地J油田M1层为研究对象,采用沉积动力学模拟与多点统计学建模方法,设定地形坡折高度、潮汐幅度,河口流速、沉积物粒径等参数建立了研究区三维沉积模型.结合M1层储层特征将沉... 详细信息

为提高潮控河口湾储层中少井区三维建模精度,以南美Oriente盆地J油田M1层为研究对象,采用沉积动力学模拟与多点统计学建模方法,设定地形坡折高度、潮汐幅度,河口流速、沉积物粒径等参数建立了研究区三维沉积模型.结合M1层储层特征将沉积模拟结果转换为三维训练模板,联合井上测井数据,使用多点地质统计学方法构建沉积动力学模拟约束下的潮控河口湾储层三维精细地质模型.结果表明在沉积动力学建立的三维训练模板约束下,模型中取心井结果与岩心拟合程度高,验证井与井上测井数据相对误差为7.6%,高于序贯高斯模拟方法模拟的精度.在潮控河口湾储层中,通过沉积动力学建立三维训练模板约束储层模型,能够在少井区有效提高模型精度,并得到了验证井交叉验证的结果,这将为潮控河口湾含油储层的勘探与开发提供指导.

关键词：河口湾沉积动力学模拟多点地质统计学三维建模 Oriente盆地石油地质

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Prediction of decline in shale gas well production using stable carbon isotope technique

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Frontiers of Earth Science 2021年第4期15卷 849-859页

作者： Shengxian ZHAO Shujuan KANG Majia ZHENG shuangfang lu Yunfeng YANG Huanxu ZHANG Yongyang LIU Ziqiang XIA Chenglin ZHANG Haoran HU Di ZHU Key Laboratory of Deep Oil and Gas China University of Petroleum(East China)Qingdao 266580China School of Geosciences China University of Petroleum(East China)Qingdao 266580China Key Laboratory of Earth and Planetary Physics Institute of Geology and GeophysicsChinese Academy of SciencesBeijing 100029China Shale Gas Institute of PetroChina Southwest Oil&Gasfield Company Chengdu 610000China Suzhou Grand Energy Technology Ltd. Suzhou 215129China

Prediction of shale gas production is a challenging task because of the complex fracture-pore networks and gas flow mechanisms in shale reservoirs.Empirical methods,which are used in the industry to forecast the future production of shale gas,have not been assessed sufficiently to warrant high confidence in their results.Methane carbon isotopic signals have been used for producing gas wells,and are controlled by physical properties and physics-controlling production;they serve as a unique indicator of the gas production status.Here,a workable process,which is combined with a gas isotope interpretation tool(also known as a numerical simulator),has been implemented in Longrnaxi shale gas wells to predict the production decline curves.The numerical simulator,which takes into account a convection-diffu-sion-adsorption model for the matrix and a convection model for fractures in^(13)CH_(4) and ^(12)CH_(4) isotopologues,was used to stabilize the carbon isotope variation in the produced gas to elucidate gas recovery.Combined with the production rates of the four developing wells,the total reserves ranged from 1.72×10^(8) to 2.02×10^(8) m^(3),which were used to constrain the trend of two-segment produc-tion decline curves that exhibited a transition from a hyperbolic equation to an exponential one within 0.82-0.89 year.Two-segment production decline curves were used to forecast future production and estimate ultimate recovery.

关键词： shale gas production decline Longmaxi formation carbon isotope

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致密砂砾岩成储界限及分级评价标准——以松辽盆地徐家围子断陷白垩系沙河子组为例

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石油实验地质 2024年第3期46卷 553-564页

作者：王军杰卢双舫林子智周能武张鹏飞黄宏胜郅琪李柏知东北石油大学三亚海洋油气研究院海南三亚572025 东北石油大学陆相页岩油气成藏及高效开发教育部重点实验室黑龙江大庆163318 中国石油大学(华东)地球科学与技术学院山东青岛266580 山东科技大学地球科学与工程学院山东青岛266590

徐家围子断陷下白垩统沙河子组砂砾岩储层是松辽盆地深部重要的致密气藏储层,其孔渗关系复杂,给成储界限的厘定和储层分级评价带来挑战。针对沙河子组砂砾岩储层,采用水膜厚度法、充注动力法、试气产能法和力学平衡法厘定了理论下限、... 详细信息

徐家围子断陷下白垩统沙河子组砂砾岩储层是松辽盆地深部重要的致密气藏储层,其孔渗关系复杂,给成储界限的厘定和储层分级评价带来挑战。针对沙河子组砂砾岩储层,采用水膜厚度法、充注动力法、试气产能法和力学平衡法厘定了理论下限、成藏下限、有效渗流下限和成储上限,根据不同成岩作用主控因素下的孔渗关系确定成储界限物性值。在此基础上,结合储层微观孔隙结构差异划分储层类型,建立致密储层分级评价标准,并利用测井资料将分级评价标准进行应用,为研究区致密气甜点区优选提供依据。将沙河子组砂砾岩分为常规储层、Ⅰ—Ⅳ级致密砂砾岩储层和非储层,成储界限与分级评价结果具有很好的匹配关系。其中,常规储层孔隙度大于9%,渗透率大于0.05×10^(-3)μm^(2);Ⅰ级致密储层孔隙度为8%~9%,渗透率为(0.01~0.05)×10^(-3)μm^(2);Ⅱ级致密储层孔隙度为5%~8%,渗透率为(0.001~0.01)×10^(-3)μm^(2);Ⅲ级致密储层孔隙度为3.5%~5%,渗透率为(0.2~1)×10^(-6)μm^(2);Ⅳ级致密储层孔隙度为2%~3.5%,渗透率为(0.05~0.2)×10^(-6)μm^(2);非储层的孔隙度小于2%,渗透率小于0.05×10^(-6)μm^(2)。致密砂砾岩气产量受控于致密储层类型;Ⅰ级、Ⅱ级致密储层是致密气高产的有利层段;徐家围子断陷北部安达—宋站地区有利储层厚度较大,为致密气勘探开发甜点区。

关键词：致密砂砾岩气成储界限分级评价甜点评价徐家围子断陷沙河子组松辽盆地

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Economic feasibility and efficiency enhancement approaches for in situ upgrading of low-maturity organic-rich shale from an energy consumption ratio perspective

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地学前缘 2023年第1期30卷 281-295页

作者： lu shuangfang WANG Jun LI Wenbiao CAO Yixin CHEN Fangwen LI Jijun XUE Haitao WANG Min Sanya Offshore Oil&Gas Research Institute Northeast Petroleum UniversitySanya 572025China Ministry of Education Key Laboratory of Continental Shale Hydrocarbon Accumulation and Efficient Development Northeast Petroleum UniversityDaqing 163318China Key Laboratory of Deep Oil and Gas School of GeosciencesChina University of Petroleum(East China)Qingdao 266580China

The technical feasibility of in situ upgrading technology to develop the enormous oil and gas resource potential in low-maturity shale is widely acknowledged.However,because of the large quantities of energy required to heat shale,its economic feasibility is still a matter of debate and has yet to be convincingly demonstrated quantitatively.Based on the energy conservation law,the energy acquisition of oil and gas generation and the energy consumption of organic matter cracking,shale heat-absorption,and surrounding rock heat dissipation during in situ heating were evaluated in this study.The energy consumption ratios for different conditions were determined,and the factors that influence them were analyzed.The results show that the energy consumption ratio increases rapidly with increasing total organic carbon(TOC)content.For oil-prone shales,the TOC content corresponding to an energy consumption ratio of 3 is approximately 4.2%.This indicates that shale with a high TOC content can be expected to reduce the project cost through large-scale operation,making the energy consumption ratio after consideration of the project cost greater than 1.In situ heating and upgrading technology can achieve economic benefits.The main methods for improving the economic feasibility by analyzing factors that influence the energy consumption ratio include the following:(1)exploring technologies that efficiently heat shale but reduce the heat dissipation of surrounding rocks,(2)exploring technologies for efficient transformation of organic matter into oil and gas,i.e.,exploring technologies with catalytic effects,or the capability to reduce in situ heating time,and(3)establishing a horizontal well deployment technology that comprehensively considers the energy consumption ratio,time cost,and engineering cost.

关键词： shale gas content in situ upgrading energy consumption ratio high-efficiency heating efficient organic matter transformation

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四川盆地仪陇—平昌地区侏罗系凉高山组页岩油地质特征及富集条件

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岩性油气藏 2024年第2期36卷 52-64页

作者：白雪峰李军辉张大智王有智卢双舫隋立伟王继平董忠良中国石油大学(华东)地球科学与技术学院山东青岛266580 多资源协同陆相页岩油绿色开采全国重点实验室黑龙江大庆163712 中国石油大庆油田有限责任公司勘探开发研究院黑龙江大庆163712

基于钻井岩心的地球化学及其他实验分析结果,结合生产测试资料,对四川盆地仪陇—平昌地区侏罗系凉高山组页岩油地质特征及富集条件进行研究,并划分了勘探有利区。研究结果表明:(1)仪陇—平昌地区凉高山组为早侏罗世第3次湖盆扩张期的沉... 详细信息

基于钻井岩心的地球化学及其他实验分析结果,结合生产测试资料,对四川盆地仪陇—平昌地区侏罗系凉高山组页岩油地质特征及富集条件进行研究,并划分了勘探有利区。研究结果表明:(1)仪陇—平昌地区凉高山组为早侏罗世第3次湖盆扩张期的沉积产物,整体经历了凉下段滨湖—浅湖、凉上段中—下部深湖—半深湖及浅湖、凉上段上部三角洲前缘和浅湖的沉积环境变化。(2)研究区凉高山组页岩可分为长英质页岩、钙质页岩、黏土质页岩等3种;页岩有机质丰度高,TOC值为0.50%~3.39%,平均值为1.30%,有机质类型以Ⅱ_(1)和Ⅱ_(2)型为主,热演化程度高,镜质体反射率(Ro)为1.00%~1.90%,处于高—过成熟阶段。(3)凉高山组页岩物性较好,孔隙度为0.48%~7.17%,平均为3.61%,发育无机成因孔、有机孔和构造缝等储集空间类型;含油性较好,以轻质组分为主,整体呈零散状、点状分布,局部呈团块状富集;凉上段下部富有机质页岩更发育,是目前勘探的重点层位。(4)凉高山组页岩油气的富集受控于前陆盆地过渡期的弱沉降环境、大面积分布的深湖相沉积、较高的热演化程度以及普遍发育的微裂缝。中南部为页岩油气潜力区,页岩储层厚度一般大于15 m,TOC值大于1.50%,孔隙度大于4.00%,R_(o)大于1.30%;凉高山组页岩油资源量为26.75×10^(8)t、页岩气资源量为1.72×10^(12)m^(3),有望成为四川盆地石油产量增加的主力层系。

关键词：页岩油轻质油湖盆扩张期前陆盆地弱沉降环境深湖相高—过成熟阶段微裂缝凉高山组侏罗系仪陇—平昌地区四川盆地

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