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01 January 2019, Volume 35 Issue 5 Previous Issue    Next Issue

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Controlling Factors and Occurrence Prediction of High OilGas Production Zones in Lower Triassic Baikouquan Formation of Mahu Sag in Junggar Basin LEI Dewen1, Abulimiti1, TANG Yong1, CHEN Jing1, CAO Jian2 2014, 35 (5):  1-1.  Abstract ( 171 )   PDF (300KB) ( 286 )   Save The breakthrough of hydrocarbon exploration often depends on the change of explorative strategy and the innovation of exploration cognition, it is by which that a significant discovery in Junggar basin has been made recently. It is a continuous oil play in Baikouquan glutenite reservoir of the Lower Triassic in Mahu sag of northwestern margin of Junggar basin. In this play the integral a hundred?millionton oil reservoir with light?oil accumulation far from source sequences has been proven. The oil?gas distribution in this reservoir is characterized by integral oil bearing, local enrichment and“dessert”high production. The high production of hydrocarbon is dominantly controlled by three factors: (1) A large?sized and effective fan delta front facies reservoir with more micro?fractures; (2) high maturity of light crude oil and commonly producing gas, and (3) abnormal high pressure. This favorable facies belt is mostly distributed in the superimposed zones with abnormal high pressure and light hydrocarbons, showing the internal connection of hydrocarbon accumulation and enrichment. It is predicted that the area of future favorable exploration target could be about 2 800 km2 and the total oil?gas resources amount to 14.7×108 t. It will not only be a new base for incremental hydrocarbon reserves and production of Xinjiang oilfield, but also an important supplement to global continuous oil play explorations and researches Related Articles | Metrics

Accumulation Conditions and GasBearing Characteristic Analysis of Longmaxi Shale Gas in Northwestern Hunan Province LIN Tuo1, ZHANG Jinchuan1, LI Bo2, TANG Xuan1, HE Wei1, PEI Songwei1 2014, 35 (5):  1-1.  Abstract ( 91 )   PDF (300KB) ( 394 )   Save For evaluating accumulation conditions and gas content characteristics of the Lower Silurian shale in northwestern Hunan province, Well Yongye?1 was optimally selected and drilled, and it revealed the Lower Silurian dark shale of 131.2 m in thickness, including 19.3 m thick black shale. The black shale of Longmaxi formation is characterized by high TOC (2.0% in average), medium organic maturity (2.4% in average), high brittle mineral content (50.3% quartz in average), low clay content (31.3% in average) and low porosity (1.7% in average), showing good shale gas accumulation conditions. Although the the result of isothermal adsorption simulation test shows that the black shale have a good adsorption capacity (2.52 m3/t in average), the gas content from well site desorption test is very low. This is presumably due to the shallow depth of it, the intense tectonic activity in northwestern Hunan province and the poor preservation condition. The sedimentary thickness of the black shale reflects that The sedimentary environment of Well Yongye?1 is located at the edge of deep water shelf, so Huayuan-Baojing-Longshan areas with 30~40 m thick black shale that are close to the sedimentary center could be as the targets for further shale gas exploration in this area Related Articles | Metrics

Development Characteristics of Reef Reservoir in Changxing Gas Pool, Yuanba Gas Field,Northeastern Sichuan Basin PENG Guangming1, LIU Yan2, LI Guorong3, HE Zurong1 2014, 35 (5):  1-1.  Abstract ( 61 )   PDF (300KB) ( 401 )   Save Related Articles | Metrics

Tectonic Evolution and Controls on Hydrocarbon Accumulation in Huoerguosi-Manasi-Tugulu Anticline Belt in Southern Junggar Basin WEI Lingyun, XIAO Lixin, XIA Yu, JI Dongsheng 2014, 35 (5):  1-1.  Abstract ( 89 )   PDF (300KB) ( 223 )   Save Related Articles | Metrics

Fracture Characteristics and Formation Period of Feixianguan Reservoir in Puguang Gas Field ZHANG Chong1a, LIU Hongbo1a,2, YAO Yong1a, XIE Runcheng1a,1b, ZHOU Wen1a,1b, GONG Gaofei1a 2014, 35 (5):  1-1.  Abstract ( 64 )   PDF (300KB) ( 274 )   Save In order to definitely understand the fracture characteristic and formation period in oolitic dolomite reservoir of Feixianguan No.1 and No.2 members of Lower Triassic in Puguang gas field, this paper presents detailed description and statistical analysis of the fractures of cores and thin?section, including the fractural occurrence, pack density and fracture opening, etc., and discusses the fractural group system and direction using paleomagnetic thin?section orientation technology. It is suggested that the NEE-SWW direction is the advantageous group system, while the fractures of different group systems reflect that the strata may undergo multistage tectonic activities. Based on the fracture cutting limit matching relationship, the iridium content and the filling carbon and oxygen isotopes, it is determined that there exist three periods of fracture formation, such as Late Indosinian period (the secondary formation period), Yanshan period (the major formation period）and Late Yanshan-Himalayan period (the effective fractures major formation period nowadays). Such a study can provide the important geological information for geological modeling and oil?gas accumulation of target zones in this area Related Articles | Metrics

Mechanism of Coal Lithotypes Control on Microfissure Development in Coal Seams inHancheng Area, Shaanxi Province FANG Yuan, TANG Dazhen, XU Hao, YU Tingxu, TANG Shuling, ZHAO Junlong 2014, 35 (5):  1-1.  Abstract ( 56 )   PDF (300KB) ( 191 )   Save The production horizons in Hancheng area of Shaanxi province are characterized by longitudinally alternating coal lithotype changes and strong heterogeneity in the coal seams. The relationship between the coal lithotype and the microfissure development are analyzed by means of microscopic observation and fractal approach, combined with X-ray CT and NMR T2 spectrum analysis technologies.The results show that the microfissures are dominated by the dendritic and orthogonal types with length of over 300μm and width of less than 5 μm, and much more developed in bright coal and semibright coal. The NMR T2 spectrum analysis indicates that from bright and semibright coal to semidull and dull coal, the trimodal pore-size distribution of adsorption pore, seepage pore and fissure is changed to bimodal distribution of adsorption pore and seepage pore. The development degree of microfissure and the connectivity between adsorption pore and seepage pore are gradually weaken, with the trend of the adsorption pore increase, showing a good consistency between the NMR T2 and the X-ray CT results. It is suggested from the microfissure development characteristics of different lithotypes and the correlations to coal macerals that hydrocarbon generation potential and its diffusion ability are the key factors of the microfissure development Related Articles | Metrics

Characteristics and Evaluation of Chang71 Reservoir in Maling Area of Ordos Basin NING Wenyu1a, 1b, WEN Zhigang1a, 1b, HU Youqing,2 2014, 35 (5):  1-1.  Abstract ( 68 )   PDF (300KB) ( 210 )   Save This paper presents in?depth studies of Chang?71 reservoir in Maling area of Ordos basin in petrology, physical property and pore throat characteristics by core sampling analysis, well logs, SEM, casting thin section and rock slice data as well as mercury injection test information. The results show that this reservoir is dominated by lithic feldspar sandstone and feldspar lithic sandstone, intergranular pore and feldspar dissolved pore, and characterized by low and ultra?low porosity, ultra?low permeability and strong heterogeneity. The comprehensive classification and evaluation suggest that the major reservoirs belong to Type?Ⅲ and Type?Ⅳ, Type?Ⅰ reservoir is undeveloped, and Type?Ⅱ ones are developed locally in this area Related Articles | Metrics

Characteristics of Fan Delta Deposits and Cycles of Baodaowan Formation in Shichang Section in Southern Margin of Junggar Basin QU Jianhua1, YANG Rongrong1, TAN Chengpeng2, LI Hui1, AN Zhiyuan1, SHAN Xin2 2014, 35 (5):  1-1.  Abstract ( 93 )   PDF (300KB) ( 204 )   Save With the guidance of sedimentology and high resolution sequence stratigraphy, a detailed study on the characteristics of fan delta deposits and cycles of Baodaowan formation in Shichang section in the southern margin of Junggar basin is conducted by means of the outcrop observation and measurement. The nine types of lithofacies and four kinds of typical lithofacies associations developed in the Bad?aowan formation respectively represent the braided channel of fan delta plain, the braided distributary channel of fan delta inner front, the underwater distributary channel of fan delta outer front and the sheet sand of pre?fan delta. The fan delta plain of Badaowan formation is characterized by that the sand bodies in multistage braided channels of fan delta plain are vertically superposed into a thick sand body, in which the thick and fine grained barrier layers are deposited at the bottom and the top. The braided channels with better physical properties are the main reservoir sand bodies. In the outcrop, two long?term base?level cycles are identified, namely LSC1 and LSC2, and the Bad?aowan formation can be subdivided into four medium?term cycles and a number of short?term cycles.On the basis of control factors of the tectonic movement, accommodation and sedimentary provenance, the base?level cycles of Shichang section could be compared with that of Sikeshu River section Related Articles | Metrics

Geochemical Characteristics of Pinghu Crude Oils in Pingbei Area of Xihu Sag YIN Shiyan1,2, YE Jiaren2, LEI Chuang3, SHAN Chao2, TIAN Yang2, LIU Fangyuan2 2014, 35 (5):  1-1.  Abstract ( 55 )   PDF (300KB) ( 476 )   Save Based on the analysis of the light hydrocarbons, saturated hydrocarbons and aromatic hydrocarbons from crude oil in Pingbei area of Xihu sag, the C7 light hydrocarbon compound of the Pinghu crude oil are characterized by (1) high methylcyclohexane content, low dimeth?ylcyclopentane and pentane content, and paraffin wax index and heptane value ranging from 3 to 13 and 10%~18%, respectively; (2) wide distribution of carbon number of the n?alkanes without odd?even predominance, the Pr/Ph ratios in most samples distributing between 3.6 and 8.2; (3) steranes mainly consisted of regular sterane, with highest C29 sterane, and relatively high degree of isomerization; (4) relatively high hopane content, the hopane/sterane ratio of 1.5~6.7, low gammacerane content and abundant diterpene; and (5) some Reteneis detected from the aromatic components, the methylphenanthrene index being between 0.71 and 1.42, the highest fluorenehas content among the three series of fluorenecompounds. A comprehensive analysis shows that the oil?forming matrix in Pinghu formation is dominated by terrestrial organic matter, most formed in the oxidation?strong oxidation limnetic facies sedimentary environment, with minority parent material formed in weak oxidizing semi?deep lake facies environment, and the kerogen is mainly in stage of mature to high?mature evolution Related Articles | Metrics

Determination Methods of Geological Resources, Recoverable Resources and WellControlled Recoverable Reserves in Shale Gas Reservoir CHEN Yuanqian1, LI Jian1, QI Yadong1, ZHANG Xiaotao2 2014, 35 (5):  1-1.  Abstract ( 93 )   PDF (300KB) ( 224 )   Save The main component of shale gas is methane accounting for 98.5%, with minor amounts of ethane, propane, helium, oxygen and carbon dioxide gas. Shale gas reservoir is a kind of special closed gas reservoir, and it is composed of extra?dense matrix and micro?fracture system. Gas in matrix is stored in a state of saturated adsorption on the surface of particles ranging from nanometers (10-9m) to micrometer(10-6m); natural gas in micro?fracture is existed in a free state into the micro?fractures, and they belong to one pressure?balanced system. Shale has larger density, while fracture has small porosity, therefore, adsorbed gas is the main reserves of shale gas. Currently, the evaluation methods for shale gas resources reported in the literatures are incorrect, hence the results are unreliable. This paper presents the volume method for geological resources, the dynamic balance method for recoverable resources and the production decline method for wellcontrolled recoverable reserves in shale gas reservoirs Related Articles | Metrics

Study on OilWater Relative Permeability Curves in Water Flooding Oilfields GAO Wenjun1, YAO Jiangrong2, GONG Xuecheng2, XIONG Qingyong2 2014, 35 (5):  1-1.  Abstract ( 76 )   PDF (300KB) ( 430 )   Save The methods for calculation of oil?water relative permeability by water?oil displacement experiment are complex, by which the oil?water relative permeability and outlet water saturation are of few discrete data points commonly, and mainly concentrated in the end of the high water saturation. If using Willhite model to match or calculate the curves of oil?water relative permeability and outlet water saturation, the deviations or errors are usually bigger. This paper presents the improved model and makes case studies. The results indicate that it has high matching accuracy and very small errors. The standardized oil?water relative permeability curves are generally concentrated in the middle range of the core experimental curves, basically consistent with the trend of core data changes, worthy of reference and promotion Related Articles | Metrics

Well Infill Adjustment Test of Xishanyao UltraLow Permeability Reservoir in High Water Cut Stage in Wellblock Cai9 of Cainan Oilfield, Junggar Basin DONG Xuemei1,2, XU Huaimin1, Madina Mawutihan2, ZHANG Wu2, LI Guanghua2 2014, 35 (5):  1-1.  Abstract ( 62 )   PDF (300KB) ( 259 )   Save The Xishanyao formation in Cai?9 well block of Cainan oilfield in Junggar basin is a low?porosity and ultra?low permeability sandstone reservoir, which is now faced with cessation of production and to be abandoned due to its high water cut and very low production. This paper studied its percolation feature and remained oil distribution, and then proposed the adjustment system for infill injectors in inter?well remaining?oil enrichment zones in order to decrease the injector?producer spacing, increase the ratio of injection?production wells and improve reserves producing degree, and obvious successful effects have been obtained in such pilot testing well groups in this reservoir. It provides technical support and ideas for rest reservoirs adjustment and development in this area Related Articles | Metrics

Research on Calibration Methods of Recovery Factor for Reservoirs with Over 98% Water Cut ZHENG Qianga, SHI Junb, SUN Chaoa , MA Chongyaoa, LI Shufenga, WANG Yana 2014, 35 (5):  1-1.  Abstract ( 91 )   PDF (300KB) ( 233 )   Save According to the national standard of China’s oil and gas industry, the recovery factor is calibrated with the waterflooding characteristic curve for the developed sandstone reservoir based on the water?cut limit of 98%. For reservoirs with over 98% of ultra?high water cut, the calculation method listed in the national standard of China’s oil and gas industry is no longer available. Based on the calculation of water?cut limit for the reservoirs, this paper presents the calibrated recovery factors of the reservoirs with ultra?high watercut in OBJ1 reservoir of KS oilfield in Kazakhstan , by using the oil?water relative permeability curve derived from the A?type waterflooding characteristic curve, generalized Tong’s chart and the production data, as well as the numerical simulation method. The results show that the recovery factors calibrated by the former three methods are very close to, so these methods can be used. Whereas the recovery factor calibrated by thenumerical simulation method is a bit high, and can be used as reference Related Articles | Metrics

Comprehensive and Quantitative Prediction of Tectonic Fractures in Damintun Sag, Liaohe Field LI Chunlin1, WANG Lei1, LI Liangfeng2 2014, 35 (5):  1-1.  Abstract ( 60 )   PDF (300KB) ( 226 )   Save The distribution of reservoir fractures in Damintun sag in Liaohe field is quantitatively predicted by analysis of the regional tectonic stress field feature and establishment of rational geologic and mechanical model in this study area based on finite element approach.Through 3D tectonic stress field numerical simulation and analysis, the distribution diagram of the first, second and third principle stresses and the maximum shear stress in the Archeozoic reservoirs in the buried hill are obtained. And the composite fracture density value (β) is given based on rupture value (I) and energy value (u) evaluation indices. The case study shows that the fracture density predicted by using βindex is more identical with statistical density of cores fracture from drilled wells. Comparing with previous single evaluation index, the accuracy of fracture prediction is greatly increased Related Articles | Metrics

Early Exploitation Characteristics of Lucaogou Tight Oil of Permian in Jimusaer Sag, Junggar Basin WU Chengmei, GUO Zhineng, TANG Fuping, XIE Jianyong, LIANG Chenggang, ZHANG Leyuan 2014, 35 (5):  1-1.  Abstract ( 76 )   PDF (300KB) ( 334 )   Save The Lucaogou tight oil of the Permian in Jimusaer sag in eastern Junggar basin are in its early stage of exploration and development. In this paper, the tight oil’s characteristics such as production test, pressure, seepage flow and decline, etc. are analyzed, by which the recovery factor of Lucaogou tight reservoir is estimated. It is suggested that the horizontal well and the multistage fracturing are two kinds of key technologies for economically and effectively developing the tight oil; the Lucaogou formation belongs to normal pressure system, with pressure factor of 1.05~1.20; it has an obvious feature of non-Darcy flow and starting pressure; the oil well production performance is accordant with hyperbolic decline pattern; the annual natural production decline rate is about 60%, and the predicted ultimate recovery factor is 5.5% Related Articles | Metrics

Impact of Reservoir Heterogeneity on UltraHeavy Oil Development Effect by SAGD Process HE Wanjun1aWANG Yanjie1aWANG Tao1b, YANG Zhi1aMuhetaer1aZHANG Lijian2 2014, 35 (5):  1-1.  Abstract ( 61 )   PDF (300KB) ( 243 )   Save The ultra?heavy oil development effect by steam assisted gravity drainage (SAGD) process mainly depends on the size of steam chamber, which is greatly influenced by reservoir heterogeneity. Based on the typical heterogeneous geological model of Wellblock?Z32 and Wellblock?Z37 pilot areas in Fengcheng oilfield of Junggar basin, the influences of reservoir permeability, intercalation physical properties and intercalation distribution on the SAGD process was studied using numerical simulation approach. The results show that the intercalations above the horizontal gas injector mainly affect the vertical migration of steam during the production stage of SAGD, and impede the normal vertical development of the steam chamber, and lead to a lateral extension of the steam chamber along the bottom of the intercalation and postpone the peak of oil production. The intercalations between injectors and producers would cause low producing degree of the horizontal section and lower the efficiency of circulation preheating, increasing the preheating time. As a result, the hot fluid can not be recovered as expected and the production effect is poor. In order to obtain a better result, the SAGD horizontal well groups should be deployed in horizontal sections where permeability difference is less than 3.0 and avoid intercalations with a permeability less than 100 mD; moreover, the discontinuous intercalations should be more than 3.0 m away from horizontal injectors, the intercalation closures between injectors and producers should be less than 40%, and those above the gas injectors less than 50% Related Articles | Metrics

Estimation of Quality Factor Q Using Combination of Statistical Frequency Attributes Based on S Transform TAN Jia1 , MAO Haibo1, XIAO Yanling1, TANG Jianhua1, ZHANG Jin1, CAO Siyuan2 2014, 35 (5):  1-1.  Abstract ( 51 )   PDF (300KB) ( 255 )   Save Quality factor（Q）is an important parameter for hydrocarbon detection and reservoir characterization, which reflects the subsurface seismic wave attenuation. The accuracy of Q value estimation greatly depends on the extraction of the time?varying seismic wavelet spectrum and the Q value estimating method. S transform can be used to accurately extract the time?varying seismic wavelet spectrum, and the combination of statistical frequency attributes (CSFA) can be applied to estimate the Q value in order to get the stable Q value. By this method, the regional oscillation of centroid frequency curve from real data and Q?value instability can be well solved. Application of this technology to the eastern and western Junggar basin allows the target zones’ resolutions to be obviously improved, of which the bandwidth can be increased by 5~10 Hz Related Articles | Metrics

Application of Reservoir Property Prediction Based on Probabilistic Neural Network (PNN) in Y3 Block ZHANG Jianzhi, LIN Xiaohua 2014, 35 (5):  1-1.  Abstract ( 62 )   PDF (300KB) ( 202 )   Save PNN is a mathematical interpolation method for seeking the smallest error between true value and predicted value through training sampled data. At first, the original seismic data volume is treated using log reconstruction?impedance inversion technology for improving the identification accuracy of the reservoirs. The filtering parameters is then selected using conjugate gradient algorithm to calculate the smallest test error and select the best convolution operator and number of attributes, allowing the seismic attributes and target parameters to keep the best match and avoid the overtraining of neural network. The case study by applying this technology to Y3 block has shown a good predicted effect and higher prediction precision compared with linear regression and traditional neural network methods Related Articles | Metrics

Logging Evaluation and Application of Brittleness Index in Tight Sandstone Reservoir A case study of Chang7 tight sandstone reservoir in Longdong area of Ordos basin LI Huayang1, ZHOU Cancan1, LI Changxi1, LI Chaoliu1, SHI Yujiang2, WANG Changsheng2 2014, 35 (5):  1-1.  Abstract ( 93 )   PDF (300KB) ( 400 )   Save Brittleness index of rock is an important factor for volume fracturing design of tight sandstone reservoir. This paper presents two logging evaluation methods for brittleness index—the rock elastic parameter method and the mineral composition method, and by means of rock mechanics experiment and whole?core X?ray diffraction analysis calibration, develops conventional logging?based multi?mineral model to get the brittleness index of tight sandstone reservoir. The processing result of data from Chang?7 tight sandstone reservoir in Longdong area of Ordos basin shows that using conventional logging data to evaluate the brittleness index of rock could provide technical support for optimizing selection of“dessert”of the tight sandstone reservoir by making up the shortages in difficult study of plane distribution of rock brittleness index due to fewer wells collecting array acoustic or acoustic scanning logging data Related Articles | Metrics

Feasibility Study on Application of Volume Fracturing Technology to Coalbed Methane (CBM) Development CEHNG LinlinCHENG YuanfangZHU DongfengDENG WenbiaoCHEN Chong 2014, 35 (5):  1-1.  Abstract ( 60 )   PDF (300KB) ( 307 )   Save China is rich in coalbed methane (CBM) reserves, but the production efficiency is very low due to the occurrence state, unique output mechanism, low CBM saturation, low permeability, low reservoir pressure and high CBM content. In order to get high recovery of CBM, this paper uses the successful experiences of North American shale gas pools development by volume fracturing process for reference, proposes the control conditions for volume fracturing in natural fracture, rock composition and fractural network structural mechanism, presents the similarity between CBM and shale gas in exploration approach and geological feature, and analyzes the validity and locality of the volume fracturing technology application to CBM development. The study results show that the volume fracturing process can be used to greatly improve the flow environment of coal reservoir and increase production; the incremental or stimulation response is closely related with the degree of development of natural fracture, fissure and bedding in a coal reservoir, rock brittleness index and horizontal principal stress difference, etc. Within the scope of such a fracturing process permissibility, the greater the volume modified, the more significant the stimulation response. In case study, this paper uses MEYER software to simulate a well in CBM well group in Linfen of Shanxi province, and the result indicates that the application of volume fracturing process to the coal reservoir for CBM development is feasible, which is of great significance and practical value for domestic CBM development and studies in the future Related Articles | Metrics

Natural Gas Origin and Exploration Potential in Eastern Zaysan Basin, Kazakhstan LIU Deguanga, GONG Hongyana, LU Binb, LI Shihonga, HE Yunshenga 2014, 35 (5):  1-1.  Abstract ( 89 )   PDF (300KB) ( 196 )   Save The analysis of the natural gas organic geochemical characteristics and the comprehensive study of the gas reservoirs?forming geological conditions in Sarybulak area in eastern Zaysan basin of Kazakhstan show that the gas in this area belongs to biodegraded gas of the Permian and the Jurassic heavy oils, with gas accumulation occurring in Late Neogene to Quaternary. It is suggested that the biodegraded gas in this area is characterized by abundant resources, high abundance and huge potentials for exploration. A series of anticlinal and faulted anticlinal traps formed during Himalayan orogenic period could be the major targets for natural gas exploration in this area Related Articles | Metrics

Geological Characteristics and Hydrocarbon Accumulation of Arab-Hith Play in Persian Gulf Basin LI Haowu1, TONG Xiaoguang2, WANG Jianjun1, WEN Zhixin1, ZHANG Yongjun3 2014, 35 (5):  1-1.  Abstract ( 89 )   PDF (300KB) ( 375 )   Save Arab-Hith play is one of the most important plays in Persian Gulf basin, in which the Jurassic Arab carbonate reservoir and Hith anhydrite constitute its basic reservoir?cap rock combination. Most of the hydrocarbons in it are provided by the source rocks of Jurassic Tuwaiq Mountain formation, Hanifa formation and Diyab formation. These source rocks with high TOC and very good oil generation potentials have entered into oil windows during the Middle?Late Eocene in large scale, while many traps had already been formed at Episode I of Alpine orogeny. So the generated oil and gas could be charged or migrated directly into the traps. Arab reservoir is characterized by wide distribution,grain limestone and seldom destruction of primary porosity during the early diagenesis, followed by widespread dolomitization and leaching during the late diagenesis, witch allowed it to have superior petrophysical property. Hith formation is characterized by thick anhydrite, broad distribution and weak damage by faulting, which allowed the hydrocarbons hardly to be migrated through it toward the upper reservoirs. The petroleum loss may only occur in phase change/pinch?out belt or near large?scale faults. Most of the hydrocarbons generated from Jurassic source rocks in this play were proximal accumulation and the lateral migrations were short in distance, so the most potential areas should range around the Jurassic intraplatform basins, while Arab reservoir’s hydrocarbon abundance depend on the sealing ability of Hith cap rock Related Articles | Metrics

Optimization of MediumRank CBM Development by SIS Horizontal Well in M Gasfield of Bowen Basin in Australia DING Wei1XIA Zhaohui1HAN Xueting2SUN Huachao1WANG Ping1 2014, 35 (5):  1-1.  Abstract ( 78 )   PDF (300KB) ( 216 )   Save Taking M medium?rank coalbed methane (CBM) field of Bowen basin in Australia as an example, this paper proposed corresponding approaches for development of the medium?rank CBM by SIS (surface into seam) horizontal wells, based on the well group model developed by the reservoirs with four types of petrophysical properties classified by permeability and CBM content. For Type I and Type II reservoirs with high permeability and high gas content, the approach is to optimize the well controlled area, design the horizontal wells thatare perpendicular to cleat and put infill wells in the late stage of production, by which the drilling footage and well number can be greatly decreased. For Type III reservoir with medium permeability and high gas content, the approach is to properly increase the well controlled area and optimize the branch length and angle of SIS wells by considering the influence of early production wells on the regional pressure in this area. For Type IV reservoir with low permeability and high gas content, the development effects by SIS well and multi?branch horizontal well are poor or uneconomical, due to the well controlled area is smaller, suggesting not to develop it at present Related Articles | Metrics