Journal of Unconventional Oil and Gas Resources最新文献_第10页

Life cycle greenhouse gas emissions from Barnett Shale gas used to generate electricity 巴内特页岩气用于发电的生命周期温室气体排放

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-12-01 DOI: 10.1016/J.JUOGR.2014.07.002

G. Heath, James R. Meldrum, N. Fisher, D. Arent, M. Bazilian

引用次数: 37

Comparisons of pore size distribution: A case from the Western Australian gas shale formations 孔隙尺寸分布的比较:以西澳大利亚页岩气地层为例

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-12-01 DOI: 10.1016/J.JUOGR.2014.06.002

A. Hinai, M. Rezaee, L. Esteban, Mohammad Mahdi Labani

引用次数: 207

Development of innovative and efficient hydraulic fracturing numerical simulation model and parametric studies in unconventional naturally fractured reservoirs 非常规天然裂缝性储层水力压裂创新高效数值模拟模型及参数化研究

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-12-01 DOI: 10.1016/j.juogr.2014.06.003

Chong Hyun Ahn , Robert Dilmore , John Yilin Wang

{"title":"Development of innovative and efficient hydraulic fracturing numerical simulation model and parametric studies in unconventional naturally fractured reservoirs","authors":"Chong Hyun Ahn , Robert Dilmore , John Yilin Wang","doi":"10.1016/j.juogr.2014.06.003","DOIUrl":"10.1016/j.juogr.2014.06.003","url":null,"abstract":"<div>The most effective method for stimulating unconventional reservoirs is using properly designed and successfully implemented hydraulic fracture treatments. The interaction between pre-existing natural fractures and the engineered propagating hydraulic fracture is a critical factor affecting the complex fracture network. However, many existing numerical simulators use simplified model to either ignore or not fully consider the significant impact of pre-existing fractures on hydraulic fracture propagation. Pursuing development of numerical models that can accurately characterize propagation of hydraulic fractures in naturally fractured formations is important to better understand their behavior and optimize their performance.In this paper, an innovative and efficient modeling approach was developed and implemented which enabled integrated simulation of hydraulic fracture network propagation, interactions between hydraulic fractures and pre-existing natural fractures, fracture fluid leakoff and fluid flow in reservoir. This improves stability and convergence, and increases accuracy, and computational speed. Computing time of one stage treatment with a personal computer is now reduced to 2.2min from 12.5min than using single porosity model.Parametric studies were then conducted to quantify the effect of horizontal differential stress, natural fracture spacing (the density of pre-existing fractures), matrix permeability and fracture fluid viscosity on the geometry of the hydraulic fracture network. Using the knowledge learned from the parametric studies, the fracture–reservoir contact area is investigated and the method to increase this factor is suggested. This new knowledge helps us understand and improve the stimulation of naturally fractured unconventional reservoirs.</div>","PeriodicalId":100850,"journal":{"name":"Journal of Unconventional Oil and Gas Resources","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-12-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.juogr.2014.06.003","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87151667","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 23

Logical depth modeling of a reservoir layer with the minimum available data-integration geostatistical methods and seismic attributes 利用最小可用数据集地质统计方法和地震属性进行储层逻辑深度建模

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/j.juogr.2014.03.003

Mehdi Rezvandehy

{"title":"Logical depth modeling of a reservoir layer with the minimum available data-integration geostatistical methods and seismic attributes","authors":"Mehdi Rezvandehy","doi":"10.1016/j.juogr.2014.03.003","DOIUrl":"10.1016/j.juogr.2014.03.003","url":null,"abstract":"<div>For rational depth modeling of a prominent reservoir layer in north of Iran (Gorgan plain, Chelekan top), geostatistical methods were proposed to use with the minimum available data. This data consisted of ten wells, five 2D seismic lines (three vertical lines perpendicular to two horizontal ones) which covers the area, and one small 3D seismic area, which was applied solely for evaluation of findings and optimizing our choices. Because the expansion of this area was limited as opposed to region aimed for modeling. Hence, for a reasonable geostatistical modeling, an appropriate secondary variable (soft data) was crucial. Initially, the reservoir layer should be pursued in five seismic lines with a suitable seismic attribute and achieved its time model (TWT) all over the Gorgan plain due to existing a few number of lines, linear form of data set (located on the seismic lines) and the smoothing effect of kriging, the estimate and average simulated realizations (E-type) could not give acceptable results in time modeling of the layer based on merely five seismic lines. Therefore, one of 100 realizations related to sequential quassian simulation (SGS) selected as the best secondary data after probing their correlation and similarity with the real 3D seismic data and obtaining a proper correlation coefficient. Moreover, this realization revealed the best correlation with the depth amounts of 10 wells, reproducing geostatistical and statistical parameters of input data. For this reason, it was utilized as secondary data in kriging with an external drift method (KED). Having been applied it, the smoothing effect was diminished dramatically in comparison with one variable model and consequences of final modeling, investigation of uncertainty and estimate error prior to using secondary data and after that, all of them signified the final model was much more reasonable than initial one (without secondary data).</div>","PeriodicalId":100850,"journal":{"name":"Journal of Unconventional Oil and Gas Resources","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.juogr.2014.03.003","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"87438484","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 2

Significance of compressional tectonic on pore pressure distribution in Perth Basin 珀斯盆地挤压构造对孔隙压力分布的意义

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/j.juogr.2014.01.001

Abualksim Ahmad, Reza Rezaee, Vamegh Rasouli

{"title":"Significance of compressional tectonic on pore pressure distribution in Perth Basin","authors":"Abualksim Ahmad, Reza Rezaee, Vamegh Rasouli","doi":"10.1016/j.juogr.2014.01.001","DOIUrl":"10.1016/j.juogr.2014.01.001","url":null,"abstract":"<div>The Perth Basin is one of the major tectonic structures along the western continental margin of Australia and was initially formed through the rifting and break-up of the Indian and Australian plates. The severe tectonic movements accompanied and occurred after the break-up are responsible for the most structural elements and for the distribution of pore pressure in the basin.Investigations on the well log data from the Perth Basin have identified shale intervals which are characterised as overpressured in some parts of the basin, whereas similar shale intervals found to be normally pressured in other parts of the basin. The phenomena of overpressure have frequently been reported while drilling the same intervals. Based on this research, sections with overpressure were observed in the majority of the wells in the basal section of the Kockatea shale where there were less tectonic activities have been recorded. Normal pore pressure was observed in shallower wells in the Kockatea shales which were located within uplifted sections that were more tectonically active areas.Based on the results of this research, the pore pressure distribution in the Kockatea Shale varied significantly from one part of the Perth Basin to another as a result of compressive tectonic stress. Compressional tectonic activities either induced fracturing in shallower localities (e.g. Beagle Ridge, Cadda Terrace and the adjacent terraces) or removed part of the Kockatea Shale as a result of faulting resulting in overpressures being released. Regions with less intensity of the tectonic activities showed an increase in pressure gradients as approaching away from the centre of uplift.</div>","PeriodicalId":100850,"journal":{"name":"Journal of Unconventional Oil and Gas Resources","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.juogr.2014.01.001","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"86806123","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 4

A numerical study of CO2 flow through geopolymer under down-hole stress conditions: Application for CO2 sequestration wells 井下应力条件下CO2通过地聚合物流动的数值研究:在CO2固井中的应用

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/j.juogr.2014.01.002

M.C.M. Nasvi , P.G. Ranjith , J. Sanjayan

{"title":"A numerical study of CO2 flow through geopolymer under down-hole stress conditions: Application for CO2 sequestration wells","authors":"M.C.M. Nasvi , P.G. Ranjith , J. Sanjayan","doi":"10.1016/j.juogr.2014.01.002","DOIUrl":"10.1016/j.juogr.2014.01.002","url":null,"abstract":"<div>The well cement used in injection/production wells plays a major role in the success of a carbon capture and storage project. Ordinary Portland cement (OPC)-based well cement has been used in injection/production wells and it has been found to be unstable in CO2-rich environments. In recent times, geopolymers have been tested as an alternative to OPC, and it has been found that geopolymers perform better than OPC under CO2-rich down-hole conditions. In this research work, a numerical study was performed to model CO2 flow through geopolymer under down-hole stress conditions using COMSOL multiphysics. First, the model was validated using experimental flow results under drained triaxial conditions for various injection and confining pressures. The model was then extended to predict the flow characteristics such as permeability, Darcy’s velocity, CO2 pressure and CO2 concentration distributions in geopolymer under high injection and confining pressures. The CO2 permeability values predicted by the model were in good agreement with the experimental permeability values for various injection (3–13MPa) and confining pressures (10–25MPa). The CO2 permeability of geopolymer varies between 0.008 and 0.014μD for injection pressures of 15–40MPa and confining pressures of 30–45MPa. The flow parameters including Darcy’s velocity, CO2 pressure and CO2 concentration in geopolymer reduces with increase in confining pressures due to the reduction of pore volume with increase in confinement. Pressure-driven advection is the dominant CO2 transport mechanism during the injection period compared to concentration-driven diffusion. CO2 transport through geopolymer can be modelled using COMSOL multiphysics.</div>","PeriodicalId":100850,"journal":{"name":"Journal of Unconventional Oil and Gas Resources","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.juogr.2014.01.002","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"79262319","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 6

Lessons learned from the Floyd shale play 从Floyd页岩井获得的经验教训

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/j.juogr.2014.03.001

Harry Dembicki Jr., Jonathan D. Madren

引用次数: 9

Editorial Board (IFC) 编辑委员会(IFC)

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/S2213-3976(14)00027-5

引用次数: 0

The fate of residual treatment water in gas shale 气页岩中残余处理水的命运

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/j.juogr.2014.03.002

Terry Engelder , Lawrence M. Cathles , L. Taras Bryndzia

{"title":"The fate of residual treatment water in gas shale","authors":"Terry Engelder , Lawrence M. Cathles , L. Taras Bryndzia","doi":"10.1016/j.juogr.2014.03.002","DOIUrl":"10.1016/j.juogr.2014.03.002","url":null,"abstract":"<div>More than 2×104 <!-->m3 of water containing additives is commonly injected into a typical horizontal well in gas shale to open fractures and allow gas recovery. Less than half of this treatment water is recovered as flowback or later production brine, and in many cases recovery is <30%. While recovered treatment water is safely managed at the surface, the water left in place, called residual treatment water (RTW), slips beyond the control of engineers. Some have suggested that this RTW poses a long term and serious risk to shallow aquifers by virtue of being free water that can flow upward along natural pathways, mainly fractures and faults. These concerns are based on single phase Darcy Law physics which is not appropriate when gas and water are both present. In addition, the combined volume of the RTW and the initial brine in gas shale is too small to impact near surface aquifers even if it could escape. When capillary and osmotic forces are considered, there are no forces propelling the RTW upward from gas shale along natural pathways. The physics dominating these processes ensure that capillary and osmotic forces both propel the RTW into the matrix of the shale, thus permanently sequestering it. Furthermore, contrary to the suggestion that hydraulic fracturing could accelerate brine escape and make near surface aquifer contamination more likely, hydraulic fracturing and gas recovery will actually reduce this risk. We demonstrate this in a series of STP counter-current imbibition experiments on cuttings recovered from the Union Springs Member of the Marcellus gas shale in Pennsylvania and on core plugs of Haynesville gas shale from NW Louisiana.</div>","PeriodicalId":100850,"journal":{"name":"Journal of Unconventional Oil and Gas Resources","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.juogr.2014.03.002","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74727280","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 159

Liquid uptake of gas shales: A workflow to estimate water loss during shut-in periods after fracturing operations 页岩的液体吸收:在压裂作业后的关井期间估算失水的工作流程

Journal of Unconventional Oil and Gas Resources Pub Date : 2014-09-01 DOI: 10.1016/j.juogr.2014.04.001

K. Makhanov, A. Habibi, H. Dehghanpour, E. Kuru

{"title":"Liquid uptake of gas shales: A workflow to estimate water loss during shut-in periods after fracturing operations","authors":"K. Makhanov, A. Habibi, H. Dehghanpour, E. Kuru","doi":"10.1016/j.juogr.2014.04.001","DOIUrl":"10.1016/j.juogr.2014.04.001","url":null,"abstract":"<div>The imbibition of fracturing fluid into the shale matrix is identified as one of the possible mechanisms leading to high volumes of water loss to the formation in hydraulically fractured shale reservoirs. In an earlier study (Makhanov et al, 2012), several spontaneous imbibition experiments were conducted using actual shale core samples collected from Fort Simpson, Muskwa and Otter Park formations, all belonging to the Horn River shale basin. This study provides additional experimental data on how imbibition rate depends on type and concentration of salt, surfactants, viscosifiers and sample orientation with regard to the bedding plane. The study also proposes and applies a simple methodology to scale up the laboratory data for field-scale predictions.The data show that an anionic surfactant reduces the imbibition rate due to the surface tension reduction. The imbibition rate is even further reduced when KCl salt is added to the surfactant solution. Surprisingly, viscous XG solutions show a considerable spontaneous imbibition rate when exposed to organic shales, although their viscosity is much higher than water viscosity. This observation indicates that water uptake of clay-rich organic shales is mainly controlled through preferential adsorption of water molecules by the clay particles, and high bulk viscosity of the polymer solution can only partly reduce the rate of water uptake.The field scale calculations show that water loss due to the spontaneous imbibition during the shut-in period is a strong function of fluid/shale properties, fracture-matrix interface, and soaking time. The presented data and analyses can be used to explain why some fractured horizontal wells completed in gas shales show poor water recovery and an immediate gas production after extended shut-in periods.</div>","PeriodicalId":100850,"journal":{"name":"Journal of Unconventional Oil and Gas Resources","volume":null,"pages":null},"PeriodicalIF":0.0,"publicationDate":"2014-09-01","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"https://sci-hub-pdf.com/10.1016/j.juogr.2014.04.001","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"74916653","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}

引用次数: 217