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01 January 2019, Volume 36 Issue 1 Previous Issue    Next Issue

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Hydrocarbon Accumulation Patterns in Peripheral Uplift Belts of Junggar Basin SUI Fenggui, LIN Huixi, ZHAO Leqiang, ZHANG Kuihua, QIAO Yulei 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150101 Abstract ( 115 )   PDF (300KB) ( 230 )   Save Based on the geological data and seismic information, the geological structures and fill characteristics in peripheral uplift belts of Junggar basin were analyzed and summarized, and the space allocations of traps, source rocks and transport systems were studied. It is pointed out that three vertical evolution types of continuous uplifting, depression followed by uplifting and repeated uplifting and depression occur with corresponding three geological structures. The continuous uplifting type is characterized by the space allocation of “trap beside source rock”, the others by “trap on source rock”, “trap together with source rock” and “trap beside source rock”, and the different trap-source rock allocations are of different transport systems. Under the effects of the development characteristics of trap, source rock, transport system and their space allocations controlled by different geological structures, the peripheral uplift belts have three types of hydrocarbon accumulation patterns. It is concluded that the southern Chepaizi, Hala’alat-Hongqiba and Mulei areas in the peripheral uplift belts of Junggar basin could be the favorable targets for petroleum exploration in the future Related Articles | Metrics

Control Factors and Logging Evaluation Method for Glutenite Reservoir in Mabei Area, Junggar Basin WANG Guiwen1, SUN Zhongchun2, FU Jianwei1, LUO Xingping2, ZHAO Xianling1, PAN Tuo2 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150102 Abstract ( 62 )   PDF (300KB) ( 333 )   Save The fan delta deposit in Mabei area of Junggar basin is characterized by wide distribution of glutenite reservoirs, but various types of sand bodies and unclear control factors on the reservoirs caused the difficulty of related logging evaluations. Based on the core samples’ observation, this paper studied the petrology of the core unit combination controlled by different sedimentary facies, and comprehensively analyzed the core lab and the formation test data. The results show that the rock type, sorting feature and rock cementation type are the main control factors on the glutenite reservoir development. The physical property and reservoir quality tend to become poor from the grey pebbly medium-coarse sandstone in underwater distributary channel to the brown glutenit facies in overwater braded river channel. The log characterization method for the glutenite lithology and lithofacies is as follows: a) using FMI logs to identify the rock texture and structure, and classify the microfacies of glutenite; b) using conventional logs combined with FMI logs to identify the lithology, and c) using the difference between neutron log porosity and NMR effective porosity to evaluate the shale content, sorting coefficient, etc. The case study indicates that this combination method can be applied to classification and evaluation of glutenite reservoirs Related Articles | Metrics

Geochemical Characteristics of Upper Jurassic-Lower Cretaceous Bituminous Vein in Tuonamu Area in Qiangtang Basin DU Baiwei1,2, PENG Qinghua1,2, HE Jianglin1,2 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150103 Abstract ( 72 )   PDF (300KB) ( 146 )   Save Based on the field observation, this paper studied in detail the geochemical characteristics of the Upper Jurassic-Lower Cretaceous bituminous vein in Tuonamu area of Qiangtang basin and discussed the bituminous kerogen origin and the forming environment. And abundant biomarkers such as n-alkanes, isoprenoids, terpanes and steranes were detected from the samples by GC and GC-MS. The carbon number of n-alkane appears as nC17 and nC18, with OEP of 0.81~1.10, Pr/nC17 of 0.73~1.36, Ph/nC18 of 0.80~1.66 and Pr/Ph of 0.64~0.90. The terpanes are dominated by pentacyclic triterpane with tricyclic terpane and gammacerane, in which C30 hopanes are dominant. The steranes are dominated by regular steranes, in which C27-C28-C29ααα20R distributes in asymmetric “V” shape. The C29ααα20S/(20S+20R) value ranges from 0.33~0.45 to 0.15~0.49, respectively. The GC-MS characteristics of saturated hydrocarbons show that the bituminous kerogen is originated from the mixed sources of phytoplankton and higher plants, revealing such a kerogen is formed in anoxic reducing environment with some salinity. The oil source correlation indicates that the bituminous vein’s biomarkers are consistent with those of the Suowa shale in terms of saturated hydrocarbons, terpanes and steranes, confirming that they have close affinity and the hydrocarbon source rocks in this area have better hydrocarbon generation potentials Related Articles | Metrics

Shale Reservoir Characteristics of Qing-1 Member of Cretaceous Qingshankou Formation in Northern Songliao Basin LI Zhandong1a, WANG Yijun2, HU Huiting1b, WANG Haisheng3, ZHANG Haixiang1a, LI Yang4, ZHU Xiaomeng1a 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150104 Abstract ( 84 )   PDF (300KB) ( 199 )   Save The reservoir quality is one of key factors for judgment of existence of the shale reservoir. Taking the Qing-1 member shale of Cretaceous Qingshankou formation in Songliao basin as an example, its geochemical characteristics of source rocks, mineral content and reservoir space characteristics were studied. The results indicate that the shale of this member is characterized by high abundance of organic matter with TOC of 1%-3%, I and II1 types of kerogen, at the peak stage of oil generation, moderate content of brittle minerals, and large number of different types of pores, which not only provide effective channels for hydrocarbon expulsion, but also offer sufficient spaces for the residual oil and gas in the shale. The Qing-1 member shale has a high oil potential on the whole, and the estimated shale oil resource amounts to 78.37×108~97.97×108 t Related Articles | Metrics

Hydrocarbon Accumulation Conditions of North Sub-Sag and Central Sub-Sag in Liaoxi Sag, Liaodong Bay Depression YANG Baolin1, YE Jiaren1, LIU Yiming1, SHAN Chao1, XUE Haiqin2 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150105 Abstract ( 54 )   PDF (300KB) ( 136 )   Save The hydrocarbon accumulation conditions of north sub-sag and central sub-sag in Liaoxi sag of Liaodong Bay depression was correlated and analyzed. It is recognized that the north sub-sag is characterized by large thickness of source rocks, high organic matter abundance, high maturity; the reservoirs are mostly sandstone with high-super high porosity, middle-high permeability, the mud cap rock has large single layer thickness and the overpressure is widely developed, the trap closure amplitude and area are large, the migration force is sufficient, the fluid is mainly transported vertically along the faults that are undeveloped in the late stage of tectonic movement, and the oil conservation condition is good. The central sub-sag is characterized by relatively small thickness of source rocks, medium organic matter abundance, low maturity; the reservoirs are dominated by sandstone with middle porosity and low permeability, the mud cap rock has small single layer thickness, the overpressure is locally developed, the trap closure amplitude and area are relatively small, the migration force is relatively weak, the transport system is complex, the fault in the late stage of tectonic movement is developed, which has a certain of damages to previous existing oil-gas reservoirs. The studied result indicates that the north and central sub-sags do have basic conditions for hydrocarbon accumulation, but the north sub-sag is better than the central sub-sag in reservoir-forming condition, hence it is a favorable area for petroleum exploration in Liaoxi sag Related Articles | Metrics

Deep Gas Accumulation Conditions and Exploration Targets in Central-Eastern Qaidam Basin ZENG Xu1, TIAN Jixian1, ZHOU Fei2, ZHAO Jian2, GUO Zeqing1, LI Jin1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150106 Abstract ( 67 )   PDF (300KB) ( 101 )   Save Yiliping-Sanhu area in Qaidam basin has no major exploration breakthrough for its Neogene strata that have been dilled up to now just have some shows of natural gas. In this paper, the core lab tests of the aboundance, kerogen type and maturity indexes of the organic matter from the Neogene source rocks were presented, by which the deep gas accumulation condition and exploration potential were analyzed. It is recognized that the type of organic matter of the Neogene is dominated by Type Ⅱ2 and Type Ⅲ, and the N22 and N12 have maximum thickness of dark mudstone in vertical in this area; the source rocks get into gas threshold at depth of 2 800 m and generate abundant thermogenic gas starting with 4 000 m, showing that this area has a certain amount of gas resource. In sedimentary facies, the Neogene appears lake and delta developed with shore shallow lake sand bank, delta front sand bank and channel sand, etc., so the physical properties are mainly controlled by sedimentary microfacies, particle size and buried depth. The potential deep gas exploration domain or targets could be in Tahu-Sebei, Jianshishan-Chuanxingqiu and Jianshan-Hongsanhan areas Related Articles | Metrics

Effect of Strata Thickness on Fracture Development in Sand-Mud Interbed SHANG Lin1,2, DAI Junsheng2, FENG Jianwei2, YANG Xuejun3, WANG Ke2, SONG Baoshun1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150107 Abstract ( 71 )   PDF (300KB) ( 289 )   Save In order to study the effect of strata thickness on the fracture development in sand-mud interbed, this paper took the sand-mud interbed reservoir of braided river delta front in Keshen gas field in Tianshan mountain piedmont as an example, analysed the generation mechanism of structural fractures, calculated the density, aperture and porosity of fractures by using numerical simulation method, and then proposed six models for fracture development in the sand-mud interbed. The simulated results show that the thinner the single thickness of sandstone or mudstone, the easier the fracture generation, also, the fracture development of the interbed is influenced by the strata thickness. In the condition of same stress, the fractures with large aperture and long extension may occur in medium-thick（1.5~10 m）sandstone, and be able to extend to or penetrate the mudstone. The fractures in thin (less than 1.5 m) sandstone with small aperture have weak effect on the mudstone. For mudstone of same thickness, the thicker the sandstone in it, the easier the fracture generation, and when the mudstone is less than 1 m in thickness, the loaded mudstone is easy to rupture and generate fractures by itself. In the area with similar regional tectonic deformation, the underwater distributary channels in braided river delta front are of high fracture porosity and good connectivity and could form good reservoirs, followed by mouth bar, distal sand bar, sand sheet and underwater interdistributary sands, they have low fracture porosity and low connectivity, being difficult to become favorable reservoirs. When the mudstone reaches 1 m and its sandstone is less than 5.5 m in thickness, it could become the barrier, enough acting as an effective sealing to oil and gas Related Articles | Metrics

Geochemical Characteristics of Organic-Rich Shales of He-3 Member of Hetaoyuan Formation in Biyang Sag SHANG Fei1a,1b, LIU Zhengjun2, XIE Xinong1a,1b, FAN Zhonghai2, GUO Laiyuan1a,1b 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150108 Abstract ( 37 )   PDF (300KB) ( 76 )   Save Several organic-rich shales with oil and gas were developed in the Paleogene Hetaoyuan formation of deep area in Biyang sag. The trace and rare earth elements’ contents and indexes from the fifth shale were analyzed using ICP-MS method, including the geochemistry, the sedimentary environment and the organic-rich mechanism in this area. The results show that the changes in content of B, Sr, Th and B/Ga have a positive correlation with the change of paleosalinity, reflecting that such shales were deposited in saltwater lakes, and the gradual decline of the paleosalinity from bottom to top was consistent with the content and composition characteristics of the algae. The obvious differentiation of individual rare earth element indicates the enrichment of the light rare earth elements and the loss of the heavy ones, and these facts that the ratio of （La）N/（Yb）N is obvious greater than 1, the value of δCe ranges from 0.93 to 1.17 with an average of 0.99, being of unobvious or positive anomaly, which implies relatively low depositonal rate of the deposit. The value of V/(V+Ni) is between 0.71 and 0.84, and the value of Ce anomaly index of larger than-0.1 indicates the reducing environment. It is suggested that the fifth organic-rich shales of He-3 member of Hetaoyuan formation was developed in saltwater lake environment with low depositional rate and semiarid climate Related Articles | Metrics

Identification of Tight Sandstone Gas Reservoir of T2 Member in Dingbei Block in Ordos Basin ZHANG Wei, JIA Huichong, SUN Xiao 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150109 Abstract ( 40 )   PDF (300KB) ( 70 )   Save The reservoir of T2 member in Dingbei block in Ordos basin is characterized by super-low porosity, super-low permeability, developed intergranular dissolved pores, high quartz content and wide-distribution fractures. The special sandstone reservoir in this area causes the fact that the sensitivity of acoustic transit time to porosity is greatly influenced by shale content, the response of resistivity to petrophysical property conceals the response to pore fluids; distortions of the acoustic logs, density logs and neutron logs often appear in layers or zones with fractures and irregular hole diameter, and the “excavation effect” of neutron logging has to be explained in multiple solutions. This paper proposes a method for hole diameter correction using the resistivity curve, by which, integrated with the acoustic, density and neutron logs, the sandstone porosity of T2 member in this area is interpreted for the purpose of effective identification of the gas reservoir Related Articles | Metrics

Influences of Abnormal High Pressure on Longmaxi Shale Gas Reservoir in Sichuan Basin GUAN Quanzhong1, DONG Dazhong1, LU Hui1,2, LIU Bo3 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150110 Abstract ( 82 )   PDF (300KB) ( 216 )   Save The Longmaxi black shales of the Early Silurian in Sichuan basin is mainly deposited in shallow-deep water shelf sedimentary environment, with big thickness and wide distribution. High-output intervals of the shale gas wells in Longmaxi formation are all in abnormal high pressure. The study suggests that undercompaction pressurization, minerals digenesis, tectonic compression and thermal evolution of organic matter are considered to be the main factors causing the abnormal high pressure. The abnormal high pressure has many effects on the shale gas reservoirs. Firstly, it can restrain the thermal evolution of source rocks, and raise vitrinite reflectance lower limit for gas generation threshold. Secondly, it can slow down the digenesis of compaction for keeping higher porosity and permeability, and form secondary pores and micro-fractures by organic acids corrosion and rock effective stress decrease, hence improve the ability of reservoir seepage and put forward higher requirements for the fracturing modification. Thirdly, the content of absorption gas increases quickly with formation pressure raise, which makes the gas-bearing of the shale reservoir better. In short，comprehensive influences of abnormal high pressure are favorable for enrichment of shale gas Related Articles | Metrics

Research on Ultra-Heavy Oil Development by Steam Stimulation Converting into Steam Drive Combination Process in Fengcheng Oilfield SUN Xingea, MA Hongb, ZHAO Changhonga, DUAN Changb, YANG Zhaochena, XIONG Weia 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150111 Abstract ( 97 )   PDF (300KB) ( 276 )   Save In the late stage of Fengcheng oilfield’s ultra-heavy oil reservoir development by steam stimulation process, steam drive is an effective process for EOR. Research shows that steam drive process is of oil displacement-drainage effect, i.e. injected steam may form steam chamber by the fact of steam overlapping on the upper part of the reservoir and heating oil, then the oil can be produced from production wells under effects of driving force and gravity. By such a process, three replacing steam drive patterns after steam stimulation are presented, such as vertical well steam drive with short well spacing, vertical well-horizontal well combination steam drive, horizontal well-horizontal well combination steam drive. The pilot test has achieved the anticipated result and further broadened the geological conditions and combination patterns suitable for such a steam drive process. It has the reference significance to development of the similar ultra-heavy oil reservoirs Related Articles | Metrics

Evaluation of Measure Well Efficiency in Laojunmiao M Reservoir in Later Period of Oilfield Development ZHANG Shuying1, LI Deshan2, LU Wanghong3, Lü Jianfeng3 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150112 Abstract ( 64 )   PDF (300KB) ( 189 )   Save The operation cost for measure well was increasing and the measure efficiency was declining since Laojunmiao oilfield entered into the later period of development. This paper presented the characteristics of well stimulation in M reservoir of this oilfield during 2008-2012, developed the input-output efficiency evaluation model for the measured wells using data envelope analysis (DEA), and conducted a case study. Research shows that when sampling unit is effective unit, the generalized DEA model is the same as the traditional DEA model in the result; when sampling unit is not a decision making unit, the results from these two models are different. Also, it is suggested that during the period of 2008-2012, the input-output efficiency of the measures available tended to decline, in which the average efficiency of sand control was higher than those of other measures, and the efficiency of sidetrack overhaul was lower than the others’ Related Articles | Metrics

Establishment and Optimization of Two Dimensionless Liquid Production Indexes and Water Cut Relationships GAO Wenjuna, LI Ninga, HOU Chengchenga, ZHANG Ningxianb 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150113 Abstract ( 94 )   PDF (300KB) ( 116 )   Save The variation between dimensionless liquid production index and water cut is the main basic parameters of reservoir productivity evaluation and lift mode selection for waterflooding oilfield. In the various research methods available many problems are existed and lack of percolation theory support for empirical method and numerical simulation method, and using relative permeability curve approach cannot determine the function between dimensionless liquid production index and water cut. This paper improves the relationship of oil relative permeability, introduces two types of relationships between oil-water relative permeability ratio and outlet end water saturation proposed by Dr. Yu Qitai, and establishes the models for their dimensionless liquid production indes and water cut, respectively. By comparison with the results from different oilfield in oil-water permeability experiments, it is concluded that Type II model is in accord with the experimental results, worthy of reference for other oilfields Related Articles | Metrics

Mechanism and Practice of Nitrogen Injection for EOR in Fractured-Vuggy Carbonate Reservoir in Tahe Oilfield, Tarim Basin HUI Jian, LIU Xueli, WANG Yang, YANG Zhanhong, CHEN Yong 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150114 Abstract ( 88 )   PDF (300KB) ( 247 )   Save The fractured-vuggy carbonate reservoirs in Tahe oilfield are characterized by special reservoir types and difficult exploitation. The previous single well water injection and element pattern water flooding obtained better oil incremental effects to some extent. However, the development effect was getting poor with the continuous water flooding for the plentiful oil that water flooding can’t sweep was remained in high parts of fractured-vuggy units. This paper studied and proved the possibility of nitrogen huff and puff process for the remained oil by means of numerical simulation technique. When injecting nitrogen gas into the formation, it will mix up with the crude oil and appear gravitational segregation to replace downward and produce the oil, also, the injected nitrogen dissolved in the remained oil can play a role of reducing the oil viscosity and complementing the formation energy or pressure. This technology has been applied to 123 wells in Ordovician fracture-vuggy carbonate reservoirs in Tahe oilfield since 2012, and the cumulative oil production amounted to 16.13×104 t. It is verified that it is a feasible EOR technology for such a reservoir Related Articles | Metrics

Well Controlled Reserve Calculation for Fractured-Vuggy Carbonate Reservoirs in Tahe Oilfield, Tarim Basin ZHENG Songqing1, LIU Dong2, LIU Zhongchun1, KANG Zhijiang1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150115 Abstract ( 72 )   PDF (300KB) ( 124 )   Save Nazalov water flooding characteristic curve (Type-D curve for short) was derived from the relationship between oil-water relative permeability ratio and water saturation. It was proved that there was a good linear relation between the reciprocal of the slope of the linear part in Type-D curve and the original oil in-place (OOIP). This conclusion was verified through the statistics of 12 units in Tahe oilfield, and the proportional coefficient of 6.4 was determined for the fractured-vuggy reservoir. Using this method, the single well controlled reserve was calculated for wells of T7-607 unit and T7-615 unit in Tahe oilfield. The results are consistent with the geological knowledge, which shows that the method proposed in this paper is feasible for calculation of such a carbonate reservoir’s well controlled reserves in Tahe oilfield Related Articles | Metrics

Laws for Gas Well Production Decline in East Area of Sulige Gas Field, Ordos Basin LIU Zhanliang1, WANG Qi2, ZHANG Lin1, JIANG Chuanjie1, GUO Haipeng2 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150116 Abstract ( 65 )   PDF (300KB) ( 128 )   Save Taking the east area of Sulige gas field in Ordos basin as an example, the Arps decline curves were used to calculate the production decline and explain the processes of exponential, hyperbolic and harmonic decline curves in detail in this area. The studies suggest that the east area of Sulige gas field is characterized by low yield, low permeability, low abundance, rapid decline of pressure drop in gas wells, short or no for stable production period, so its decline belongs to hyperbolic decline; the decline rate is greatly influenced and controlled by initial production allocation; the production wells in 2008 in this area entered into decline period in two years later in average, with month decline rate of 1.7%~2.4%. the proration of ClassⅠ, Ⅱ, Ⅲ wells in this area of Sulige gas field are all in the reasonable ranges, indicating this analytical method is accurate and reliable. According to the formula for depletion decline, the net production time is predicted as 15~30 years for the producing wells in this area Related Articles | Metrics

Water Coning Laws of Horizontal Well Production in Bottom Water Reservoirs LIU Zhenping, LIU Qiguo, WANG Hongyu, YUAN Lin 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150117 Abstract ( 79 )   PDF (300KB) ( 164 )   Save The position of the bottom water breakthrough in horizontal well production was studied by means of the reservoir numerical simulation software. Based on the production formulas for horizontal wells, the production pressure difference corresponding to the vertical plane radial seepage resistance was deduced. Assuming the vertical plane production pressure drop to satisfy the logarithmic distribution, the bottom water coning rate with consideration of effect of gravity can be obtained, by which the equation of water breakthrough time of oil well is derived.This method’s reliability was verified by the case study. The research shows that bottom water breakthrough starts from the middle of horizontal well section, and the longer the production time, the faster the rate of bottom water coning. Reasonably increasing the length of horizontal well section and the height of water avoidance can postpone the time of water breakthrough in oil wells Related Articles | Metrics

Application of Self-Emulsification Viscosity Reducing Technology to Linpan Heavy Oilfield DONG Yuanjun1, ZHANG Ziyu1, HAN Wei1, DONG Shuangping1, WANG Zaihua2, XIAO Xianming3 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150118 Abstract ( 78 )   PDF (300KB) ( 187 )   Save Linpan heavy oil reservoir is dominated by conventional heavy oil with viscosity of 1 350~11 980 mPa·s (at 50℃). In view of such problems as high water cut, low production, low recovery, etc, the self-emulsification viscosity reducing technology was studied to solve these problems. The viscosity reducing agent was firstly optimized in the lab, then the influences of temperature, concentration, salinity and reaction time on the oil displacement efficiency and the physical model displacement were evaluated, and finally the viscosity reducing agent for this oilfield with low temperature and high salinity formation condition and its implementation condition was obtained. The small field tests show that MB-5034A agent can be used to effectively enhance the recovery of Linpan heavy oil Related Articles | Metrics

Application of Streamline Numerical Simulation Technique to Optimization of Water Injection Allocation in LIU Yanhong1, WAN Wensheng1, WANG Xiaoqiang1, GUO Xinjiang2, GAO Jingshan1, LUO Qiang1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150119 Abstract ( 0 )   PDF (300KB) ( 8 )   Save The traditional production performance analysis is not used for optimization of water injection allocation, realizing rapid and rational allocation for the well group. Using the pattern flood management (PFM) of FrontSim simulator in Eclipse software, such a problem can be well solved. This method avoids the uncertainty and complexity of artificial water injection allocation in well group. The case study shows that using this method can rapidly achieve water injection allocation optimization of the entire well pattern and thus enhance the water flood sweep efficiency Related Articles | Metrics

Application of Streamline Numerical Simulation Technique to Optimization of Water Injection Allocation in Huoshaoshan Oilfield, Junggar Basin LIU Yanhong1, WAN Wensheng1, WANG Xiaoqiang1, GUO Xinjiang2, GAO Jingshan1, LUO Qiang1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150119 Abstract ( 0 )   PDF (300KB) ( 9 )   Save The traditional production performance analysis is not used for optimization of water injection allocation, realizing rapid and rational allocation for the well group. Using the pattern flood management (PFM) of FrontSim simulator in Eclipse software, such a problem can be well solved. This method avoids the uncertainty and complexity of artificial water injection allocation in well group. The case study shows that using this method can rapidly achieve water injection allocation optimization of the entire well pattern and thus enhance the water flood sweep efficiency Related Articles | Metrics

Application of Streamline Numerical Simulation Technique to Optimization of Water Injection Allocation in Huoshaoshan Oilfield, Junggar Basin LIU Yanhong1, WAN Wensheng1, WANG Xiaoqiang1, GUO Xinjiang2, GAO Jingshan1, LUO Qiang1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150119 Abstract ( 0 )   PDF (300KB) ( 8 )   Save The traditional production performance analysis is not used for optimization of water injection allocation, realizing rapid and rational allocation for the well group. Using the pattern flood management (PFM) of FrontSim simulator in Eclipse software, such a problem can be well solved. This method avoids the uncertainty and complexity of artificial water injection allocation in well group. The case study shows that using this method can rapidly achieve water injection allocation optimization of the entire well pattern and thus enhance the water flood sweep efficiency Related Articles | Metrics

Method for Harmonic Noise Suppression of Slip Scan Data Based on Energy Difference LIU Hongjie, JIANG Li, ZHANG Zhonghu, CHEN Yong, ZHANG Jin 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150120 Abstract ( 49 )   PDF (300KB) ( 28 )   Save With the increasing of demand for high-density acquisition, the vibroseis prospecting technologies of high-efficiency, high-fidelity and environmental protection have come into use, of which, the sliding scan acquisition can shorten the slip time between two neighboring shots and improve the efficiency of acquisition, but its harmonic distortion can reduce the quality of seismic data for the impact of the latter shot on the former one. This paper presents the mechanism of vibroseis harmonic noise and proposed a method for frequency-division harmonic noise suppression based on energy difference. The seismic data processing and superposition imaging results show that this method can obviously suppress the harmonic noise, protect effective signals and improve the signal/noise ratio Related Articles | Metrics

Method for Detailed Reservoir Sands Identification Based on Diffraction Imaging LI Xiaofeng, LI Zhenchun, HUANG Jianping 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150121 Abstract ( 57 )   PDF (300KB) ( 107 )   Save There exist obvious differences of the event shapes between diffracted wave and reflected wave in dip angle gather, that is, the reflection event appears as a concave curve while diffracted wave as quasi-linear event. In view of this, a new diffraction separation and imaging method based on reflection prediction is proposed in dip angle domain, by which the diffraction imaging on Sigsbee2a model was conducted. The results show that using this method can effectively suppress the specular reflection, improve the resolution of diffraction imaging, and enhance the identification accuracy of diffraction targets. It is proven by applying it to a complex reservoir sands model in a prospecting area that this method is of better adatability Related Articles | Metrics

Application of 13C NMR Spectroscopy to Analysis of Kerogen Pyrolytic Structure in Badaowan Coal of Jurassic in Tuha Basin QU Zhenya1,2, GUO Juanhong1,2, SUN Jianan1,2, WANG Xiaofeng3, ZOU Yanrong1 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150122 Abstract ( 51 )   PDF (300KB) ( 130 )   Save Turpan-Hami (Tuha) basin is one of large coal-measure petroliferous basins in China, in which the kerogen of most source rocks is in low-matured stage. By means of 13C NMR spectroscopy analysis and pyrolytic experiment, this paper studied the characteristics and variation of the kerogen structures in different heating rates and maturities from the Badaowan coal and carbonaceous mudstone of the Jurassic in Tuha basin. The results show that such a kerogen is in fact that the aliphatic structure carbons are significantly reduced, the oxygen-aromatic carbons are cracked out and the aromatic structures are slightly condensed, especially in the low-matured evolution stage. The amount of methylene groups is more than that of methyl groups, which could be the main reason for the basin’s light and low-matured crude oil reserves are more than low-matured natural gas Related Articles | Metrics

Application of Array Dielectric Tool to Complex Carbonate Reservoir Evaluation LAI Qiang1, XIE Bing1, LIANG Tao1, HUANG Ke1, GUO Hongbo2, CAO Jiangning2 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150123 Abstract ( 70 )   PDF (300KB) ( 176 )   Save Longwangmiao gas reservoir in Sichuan basin is the largest integrated marine carbonate gas reservoir in China. It is characterized by various types of reservoir spaces, strong heterogeneity, high background resisitivity, and strongly influenced by its lithology. So it is difficult to accurately calculate the gas saturation and identify the fluid types. This paper presents the array dielectric tool (ADT), a new dielectric log developed from Schlumberger, including the basic principle and the approach, and makes the exploratory studies of the pore structure, gas saturation and fluid property of this reservoir by means of the ADT-collected data from Longwangmiao gas reservoir, such as the dielectric constant, water-bearing porosity and the continuously variable cementation index (m) obtained by dielectric dispersion inversion. The results are in accordance with those from the semi-permeable barrier experiment of cores, the sealed coring and the oil production test Related Articles | Metrics

Controlling Factors of Petroleum Accumulation in Pre-Salt Strata in South Uplift of Pre-Caspian Basin TIAN Naxin1, YAN Shaobin2, HUI Guanzhou3 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150124 Abstract ( 66 )   PDF (300KB) ( 216 )   Save The pre-salt strata in south uplift of Pre-Caspian basin is of advantageous conditions for hydrocarbon accumulation. Two sets of high quality source rocks and three sets of carbonate reservoirs with good reservoir properties are found in its Middle Devonian-Upper Carboniferous. This paper studied its petroleum geological conditions and reservoir-forming controlling factors, in view of the regional structure and sedimentary evolution integrated with the latest drilling data. The result shows that the distribution and maturity of the source rocks control the framework of “gas in the west and oil in the east” in this area; the large-scale paleo-uplift belt controls the development of the carbonate rocks and reefs, and the weathering leaching effect greatly improves the reservoir property in the carbonate reservoir of the Visean-Bashkirian (KT-2), which control the hydrocarbon accumulation Related Articles | Metrics

Hydrocarbon Enrichment Characteristics and Exploration Potentials in Salt Basins of South Atlantic WU Changwu 2015, 36 (1):  1-1.  doi: 10.7657/XJPG20150125 Abstract ( 86 )   PDF (300KB) ( 154 )   Save The salt basins in the South Atlantic are characterized by rich hydrocarbon resources, same tectonic evolution history and similar stratigraphic features as well as very uneven distribution of oil and gas. This paper suggested from studies of the tectonic evolutions, strata, hydrocarbon accumulation conditions and petroleum distribution characteristics that these basins had experienced three evolution stages of rifting, transition and passive continental margin, with corresponding development of pre-salt, salt and post-salt sequences. And the pre-salt and post-salt source rocks, pre-salt and post-salt carbonate rocks and post-salt clastic rocks as reservoir rocks formed three sets of hydrocarbon accumulation combinations. The development of post-salt turbidite sand reservoir and the maturity of post-salt source rocks controlled the hydrocarbon enrichment of the post-salt combination, which is found in Lower Congo-Congo Fan basin; the oil-gas migration channels and the development of post-salt reservoir rocks controlled the hydrocarbon enrichment of the pre-salt to post-salt combination, which appears in Campos basin; and the rift basin scale, basement uplift and salt cap rock controlled the pre-salt combination, which occurs in Santos basin. Hence, the Kwanza basin’s pre-salt sequence, the Santos basin’s and the Campos basin’s pre-salt carbonate rocks in their outside high-swell zones and middle low-swell zones as well as the post-salt carbonate rock sequences in extending areas of each salt basin are all new domains with great exploration potentials Related Articles | Metrics