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01 February 2010, Volume 31 Issue 1 Previous Issue    Next Issue

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Distribution of Overpressure Zones in Deep Sub-Sag Area in Hinterland of Junggar Basin LIU Chuan-hu, DONG Chen-qiang, WANG Xue-zhong, WANG Jun, MA Li-qun 2010, 31 (1):  1-3.  Abstract ( 137 )   PDF (420KB) ( 462 )   Save The drilling data and the history of organic matter thermal evolution and overpressure evolution show that the deep sub-sag in hinterland of Junggar basin area is characterized by overpressure caused by thermal pressurization of hydrocarbon generation and the fluid transmission communicating with the deep overpressure system. And its top interface of overpressure is closely related to the hydrocarbon accumulation. Application of the distribution of stratigraphic overpressure to guidance of oil-gas exploration has been confirmed by the drilling information, providing a new method for strengthening the exploration in this area. The overpressure fluid in this deep sub-sag area flows toward the top interface of high-pressure compartment followed by breakthrough and accumulation, which may occur in range from 200 m obove the top interface and 100 m below it as a favorable interval for hydrocarbon accumulation. The outside of the compartment is favorable for crude oil accumulation and the inside of it for natural gas accumulation. References | Related Articles | Metrics

Distribution and Types of Buried Hill Oil-Gas Reservoir in Jizhong Depression ZHAO Xian-zheng, WU Zhao-hui, YAN Bao-yi, ZHOU Cong-an 2010, 31 (1):  4-6.  Abstract ( 186 )   PDF (324KB) ( 859 )   Save With the progress of buried hill exploration in Jizhong depression, the subtle buried hill hydrocarbon reservoirs have been focused as targets in this area. This paper analyzes the tectonic evolution and hydrocarbon accumulation conditions of such a reservoir and classifies it into four types: the reservoir inside step-fault block buried hills, the reservoir inside ridge-fault block hills, the reservoir inside residual-fault block buried hills and the reservoir inside residual buried hills, among which the former two types of reservoirs are of greater potentials. Also, the study shows that different reservoirs inside buried hills are distributed in different structural belts of second order, with characteristics of near-source distribution and differential accumulation. References | Related Articles | Metrics

Favorable Reservoir Prediction of Carboniferous Igneous Rock in Kelameili Gas Field in Junggar Basin WANG Yan-jie, ZHANG Yu-liang, LIU Nian-zhou, WU Shun-wei, YANG Zuo-ming, LI Dao-qing 2010, 31 (1):  7-9.  Abstract ( 141 )   PDF (674KB) ( 404 )   Save Kelameili gas field in Junggar basin is rich in oil and gas resources of Carboniferous, but its igneous rock is complex in the spatial distribution of reservoir. Based on the previous seismic data and existing seismic interpretation results, there is a risk of arrangement for production well due to low signal-to-noise ratio, limited resolution and unclear image in interior of Carboniferous. Using linked 3D seismic data volume that is processed by pre-stack time migration, the signal-to-noise ratio and the event continuity can be improved, and the composite wave reflection of the top interface of Carboniferous becomes clear, with distinct characteristics of its interior and lithofacies. This paper presents the development and distribution patterns of the Carboniferous igneous rock in Well Block Dixi-14 and Dixi-18 by fine calibration, the seismic attribute analysis and integrating with drilling and well logging data. Also, this paper describes the igneous reservoir of Carboniferous using SMT software, showing the distribution characteristics of favorable igneous rock body, which provides reliable foundation for the implementation of next development program. References | Related Articles | Metrics

The Distribution of Petroleum Reservoirs and the Hydrocarbon Accumulation in West Part of Northern Margin of Qaidam Basin LUO Qun 2010, 31 (1):  10-13.  Abstract ( 154 )   PDF (449KB) ( 435 )   Save Different features of petroleum distribution, migration and accumulation in different structural belts and sag areas occur in the west part of northern margin of Qaidam basin, due to the differences in geologic condition and environment. The main geologic factors for these differences include the fault and unconformity that control the lateral and vertical migration of oil and gas, the source rock-reservoircap rock assemblage that controls the oil-gas distribution horizons and the burial depth that determines the phase of oil or gas. In addition, the fault could result in the formation of most traps, thus affecting the preservation of oil-gas reservoirs. It is these that are determine the petroleum distribution characteristics in the west part of northern margin of Qaidam basin, namely, being belts from north to south, with oil in the south and gas in the east in lateral direction; in the vertical the petroleum is mainly accumulated in anticline traps of footwall of shallow slip fault and upper wall of deep basement fault. These geologic factors still control the types of petroleum reservoirs and the oil-gas migration and accumulation patterns in different areas and tectonic units. References | Related Articles | Metrics

A Study on Accumulation Period of Organic Hydrocarbon Gas and Inorganic CO2 Gas in the Dehui Fault Depression YANG Guang, ZHAO Zhan-yin, SHAO Ming-li 2010, 31 (1):  14-16.  Abstract ( 196 )   PDF (333KB) ( 509 )   Save There are abundant organic hydrocarbon gas and inorganic CO2 gas resources in Dehui fault depression of southern Songliao basin. Based on the actual homogenization temperature measurement results of fluid inclusion in organic hydrocarbon gas and inorganic CO2 gas reservoirs and in consideration of analysis of the history of tectonic evolution at the same time, there exist two periods of hydrocarbon gas accumulation at the end of Quantou formation (103×106 a)and Nenjiang formation (83×106 ~76×106 a). The formation time of CO2 gas reservoir is controversial (98×106 a or 10×106 a). The accumulation patterns of hydrocarbon gas and inorganic CO2 gas are significantly different. The former is slow and continuous, the latter is instantaneous and accompanied with the occurrence of mantlederived tectonic movement, and is closely related to the tectonic events. It is concluded that the inorganic CO2 gas reservoir is accumulated later than the Yingcheng hydrocarbon gas reservoir. References | Related Articles | Metrics

The Time Effect of Hydrocarbon Generation of Source Rocks and the Natural Gas Enrichment in Southern Songliao Basin LI Jun, YAO Li-zheng, LIN Shi-guo, WANG Zong-li, YANG Qing 2010, 31 (1):  17-19.  Abstract ( 134 )   PDF (344KB) ( 515 )   Save The deep depressions in southern Songliao basin underwent multistage tectonic movements, of which the unbalance caused the great differences of source rock evolution in each deep depression, resulting in controlling the deep natural gas enrichment in this region. According to the contribution size of the deep source rock hydrocarbon generation to the hydrocarbon accumulation, the time effect of hydrocarbon generation could be divided into four types such as the continuous subsidence high efficiency type, the Late Mingshui period uplift middle efficiency type, the Late Nengjiang period uplift low efficiency type and the Late Yingcheng period uplift inefficiency type, which can be accordingly classified as the deep fault depression gas enrichment area in its middle part, the surrounding high gas-bearing area, the remained gas area in the east part and the poor gas area in the west part. It is considered that the deep fault depression gas enrichment area in the middle fault depression zone is the most realistic large scale domain for natural gas exploration in Songliao basin. References | Related Articles | Metrics

Restoration of Eroded Thickness of Jurassic Top in Baijiahai Arch in Junggar Basin TAN Si-zhe, WANG Zhen-qi, MA Zhi-liang, HUANG Yun, WU Jian, CHEN Yong, CHEN Yang 2010, 31 (1):  20-21.  Abstract ( 130 )   PDF (229KB) ( 472 )   Save Restoration of the exact thickness of eroded strata is important to rebuild the primary sedimentary and structural evolution history, the geothermal history, the history of hydrocarbon generation, expulsion, migration and accumulation, and to evaluate the potential of oil and gas resources accurately. At present, many methods have been employed in the research of the strata denudation in sedimentary basin, but each method has its own limit in application. Based on the tructural evolution research in Baijiahai arch of Junggar basin, according to the practical geological conditions and data, the method of sedimentary ratio is applied to calculate the eroded thickness of top of Cretaceous in the arch. The restoration shows that the erosion exists pervasively in Shishugou group (J2-3sh) with a relatively small intensity. The biggest thickness of erosion is near Well Block Cai-16, with the value of 280 meters. References | Related Articles | Metrics

The Stages and Significance of Ordovician Fluid Inclusions in Tazhong No.1 Slope Break ZHANG Nai, WANG Zhao-ming, YANG Hai-jun, XING Yong-liang, ZHAO Rui-hua 2010, 31 (1):  22-25.  Abstract ( 162 )   PDF (594KB) ( 431 )   Save Based on the penetrating relationship between calcite veins and hydrocarbon-bearing healed cracks, the characteristics of hydrocarbon inclusions and the characteristics of associated brine inclusion temperatures, the hydrocarbon inclusions of Ordovician in Tazhong No.1 slope break are classified into four stages. The first stage is the Late Caledonia that forms black hydrocarbon inclusion, in which hydrocarbon is generated in Cambrian and migrated upward along the Ordovician; the second stage is the Late Hercynian that the Ordovician source rocks begin hydrocarbon expulsion and forming light-brown hydrocarbon inclusion; and then because of the volcanic hydrothermalism in Late Permian, the deep and highly matured hydrocarbons charge into the Ordovician reservoir and form extensive hydrocarbon inclusions of the third stage of inclusion, which is the second and significant hydrocarbon accumulation of Ordovician reservoir in this area. The fourth stage is the Himalayan movement that the structural highs TZ26-TZ62 in Tazhong slope break, a great amount of hydrocarbons is charged into it, which is the third hydrocarbon accumulation of it. After that, the existed hydrocarbon accumulations are modified, natural gas is charged into parts of well blocks and areas. It is concluded that the first and second stages are regarded as the footprint of hydrocarbon migration, the third and fourth stages as the history of hydrocarbon accumulation, which can be regarded as the marks for searching for high-yielding oil and gas in Tazhong No.1 slope break. References | Related Articles | Metrics

Application of Quasi-Acoustic Seismic Inversion to Prediction of Glutenit Reservoir in Inshore Submarine Fan—An example from Dongying sag WANG Min-xue, YANG Feng-li, WU Man, CHENG Hai-sheng, BAO Han-yong 2010, 31 (1):  26-28.  Abstract ( 132 )   PDF (449KB) ( 478 )   Save The selected well logs that are sensitive to the effective glutenite body are analyzed using the seismic data of 3-D prestack time migration in regional range of 600 km2 and drilling-logging data of Eogene Shasixia member (Es4) in Dongying sag of Jiyang depression basin. The 3-D seismic data volume is processed and reconstructed by means of quasi-acoustic inversion method reconstructed from well logs for the purpose of improvement of identifying ability on various effective glutenite reservoirs. The results show that the distributing interval of the effective glutenite seismic parameters is over 12 000, while exact glutenit bosy ranges form 10 000 to 12 000. Based on these results, the prediction of the effective glutenite reservoir of Es4 in inshore submarine fan in this study area can be made. References | Related Articles | Metrics

Central Uplift Belt Evolution and Ordovician Reef Bank Reservoir in Tarim Basin ZHANG Cong, YU Bing-song, ZHANG Di 2010, 31 (1):  29-32.  Abstract ( 173 )   PDF (363KB) ( 431 )   Save The Ordovician reef bank developed in Tarim basin is the quite favorable carbonate reservoir for petroleum exploration. Thereef bank in this basin is found mainly in platform margin zone and inner-platform arch ramp zone. The reef bank in Bachu area developsin group along NE-SW, parallel to the tectonic boundary between Bachu uplift and Keping uplift; in Tazhong area it is mainly distributedin platform margin zone in Tazhong No.1 fault belt, with the feature of shifting with the platform margin migration. On the whole, theOrdovician reef bank in Tarim basin is distributed around the ancient uplifts, dominated by platform margin zone. With the tectonismrising and descending, this zone gradually migrates towards west, so does the reef bank zone, too. It is obvious that the ancient upliftevolution is of obvious controlling effect on the development of Ordovician reef bank reservoirs. References | Related Articles | Metrics

Turbidite Distribution of Yanchang 6-7 in Longdong Area in Ordos Basin MA De-bo, LI Ming, CUI Wen-juan, WU Dong-xu, JIN Yin-nan, SUN Jia-qing 2010, 31 (1):  33-36.  Abstract ( 119 )   PDF (574KB) ( 605 )   Save Chang 6-Chang 7 members of Yanchang formation in Longdong area in Ordos basin are divided into a large scale base-level cycle and five medium scale base-level cycles by well-seismic integrated method. It is shown that in view of time the turbidites of the members are distributed in the middle-late period of the decline hemicycle and early period of rising hemicycle of medium scale baselevel cycles, and in view of space they are distributed in the basin slopes in front of braided river delta and the lowland of ancient topography in the basin plain with the distribution range migrating to the central basin gradually as the large scale base-level declines. The distributions of turbidites in the study area are controlled by four factors: The tectonic settings of the basin and peripheral areas control turbidite development from the macro level; the regional tectonic activities provide trigger mechanisms for turbidite development; the changes of base level cycle control the formation and distribution of turbidite; the ancient topography of prograding delta area determines the flow direction of turbidity currents in delta front and the depositional position. The turbidite deposit in Longdong area is of prime conditions for petroleum accumulation, being as an significant succeeding domain for incremental reserves and production in Changqing oil field in the future. References | Related Articles | Metrics

Formation Mechanism of Middle-Deep Reservoir Space in Shizigou Area in Qaidam Basin SUN Ping-an, CAO Jian, FENG Jin-lai, HU Kai, LIU Yun-tian, WANG Guo-yan, YANG Shu-yi 2010, 31 (1):  37-39.  Abstract ( 134 )   PDF (478KB) ( 548 )   Save Petroleum in Shizigou area in southwestern Qaidam basin is mainly found in the middle-deep reservoirs of Tertiary, where the types of reservoir space generally include remained primary intergranular pore, secondary solution pore and fracture. These types may form five combinations of reservoir spaces. The favorable reservoir spaces cover secondary solution pore and fracture. The remained primary intergranular pores are normally undeveloped due to sedimentary environment, compaction, cemented fill and diagenesis, while the secondary solution pore/vug and fracture are relatively developed because of dissolution and tectonic/structural fracture effects. Besides hydrocarbon fluid, the meteoric water may play an important role to the formation of effective reservoir spaces. References | Related Articles | Metrics

Evaluation of Source Rocks of Buqu Formation of Middle Jurassic in Zharen Area in Qiangtang Basin DU Bai-wei, CHEN Ming, LI Zhong-xiong, CHEN Wen-bin 2010, 31 (1):  40-43.  Abstract ( 155 )   PDF (523KB) ( 435 )   Save Most information about the source rocks in Qiangtang basin are originally taken from analytical data of the outcrops. This paper presents correlation and analysis of the characteristics of the source rocks in Qiangzi-2 well and on the surface in Zharen area in southern Qiangtang depression. And some differences of source rocks between them are revealed in lithology, organic matter's abundance, type and maturity, etc. The result shows that the content of organic carbon of Qiangzi-2 well is higher than that on the surface condition, and the type of organic matter is dominated by Type II1 kerogen, very little with Type II2 kerogen, and also the evolution degree of organic matter is obviously low. It is concluded that the source rocks in Qiangtang basin is of very good potential of hydrocarbon generation. This is significant to the proper evaluation of the source rocks in Qiangtang basin. References | Related Articles | Metrics

Wave Equation Forward Modeling of Carbonate Cave Reservoir in Tazhong Area, Tarim Basin SUN Dong, ZHANG Hu-quan, PAN Wen-qing, WANG Hong-bin, HAN Jian-fa, TENG Tuan-yu, JING Bing, WANG Zhen-qing 2010, 31 (1):  44-46.  Abstract ( 141 )   PDF (534KB) ( 542 )   Save This paper solves the wave equations by means of finite-difference method and studies the carbonate cave reservoir in Tazhong area, the corresponding position relations between the cave and the string bead-like reflectance, the tuning phenomenon between the top and bottom of the cave and the genetic mechanism of various string bead-like forms. The results indicate that the cave locates in the central position of string bead-like reflectance; the top of cave locates in wave trough, the bottom of it located in the wave peak shifts down with its height; the demarcation line of tuning phenomenon of the top-bottom reflectance is about 120 m; the various string bead-like forms is resulted from unsuitable migration aperture and migration velocity. The recognition can be instructive for exploration and development of carbonate cave- fractured reservoirs. References | Related Articles | Metrics

Sedimentary Facies and Exploratory Potential of Quantou-Nenjiang Formations of Yushu bRiver System in Songliao Basin PAN Shu-xin, GUO Wei-hua, MA Feng-liang, DONG Li-hong, ZHANG Ping, LIU Xiao-fang, YU Lian-zhong, ZHENG Chang-long, ZHENG Hong-jun 2010, 31 (1):  47-50.  Abstract ( 175 )   PDF (569KB) ( 690 )   Save It was believed previously that in Cretaceous of Songliao basin developed 6 large provenances and 11 major river systems. However, a new river system named Yushu river system is discovered by the authors in Dongnan (southeast) uplift, with granite as the mother rock in the Caledonian and Indosinian orogenies in Zhangguangcai mountain. This system developed from Quantou formation to Nenjiang formation is dominated by fluvial and delta deposits. The comprehensive geologic studies show that Yushu river system has great exploration potentials. Its source rocks are mainly lacustrine mudstone of the Qingshankou No.1 member, Yingcheng formation and Shahejie formation, in which Fuyang oil zone is the major target for middle-shallow petroleum exploration. At present, Yushu river system has become an important domain for incremental reserves and production in Jilin oil field. References | Related Articles | Metrics

Characteristics of Temperature and Pressure Fields in Zhundong Area, Junggar Basin WANG Jing, HE Kai, ZHI Wen-dong, WANG Zhen, WANG Lei 2010, 31 (1):  51-53.  Abstract ( 179 )   PDF (444KB) ( 755 )   Save There are two important physical parameters for researching reservoir: temperature and pressure. A reservoir is just resulted from organism matter generation and evolution in the fields of temperature and pressure. If regarding the underground temperature and formation pressure as one system, the geotemperature-pressure system in petroliferous basin generally belongs to a closed systm. In Zhundong region (eastern Junggar), there exist different characteristics of temperature and pressure fields in different areas, showing negative pressure and high temperature in north, normal pressure and normal temperature in center and high pressure and low temperature in south. Such differences are formed by different geologic development and evolution history. References | Related Articles | Metrics

Variation of Reserves Production Ratio in Production Decline Stage CHEN Yuan-qian, ZOU Cun-you 2010, 31 (1):  54-57.  Abstract ( 176 )   PDF (374KB) ( 379 )   Save In process of oil field development, production decline is an important stage of it and occurs by the end. At present, the main method for prediction of the production change in decline stage is Arps' method, in which exponential decline approach is widely used. Based on hyperbolic decline curve of Arps and integrated with the rapid method for prediction of recoverable reserves and remaining recoverable reserves of oil field, this paper proposes a method for judging the variation of reserves production ratio in production decline stage of a field. It is shown that the reserves production ratio in exponential decline stage is a constant, not changing with the time of development, while that in hyperbolic decline stage is a rising straight line with the time. The case from two fields indicates that the method for judging the variation of reserves production ratio is correct in both exponential decline stage and hyperbolic decline stage. References | Related Articles | Metrics

Correlation of Formation Water Resistivity and Buried Depth in Junggar Basin LIN Zu-bin, ZENG Jun, WANG Hong-liang, QIU Chang-xia, LIN Ge3, LU Pei-yi 2010, 31 (1):  58-60.  Abstract ( 165 )   PDF (336KB) ( 499 )   Save Analysis of formation water data over the past 51 years (1955 -2006) in Junggar basin is conducted. The correlations of formation water resistivities and buried depths of 81 layers are established by layering and zoning, which provide solid conditions for determination of formation water resistivity of any depth in different areas or blocks for the purpose of proper calculation of oil and/or gas saturation in reservoirs. References | Related Articles | Metrics

Evaluation on Reservoir Sensitive and Waterflood Suitability in Di-2 Well Area of Dishuiquan Field in Junggar Basin WU Yun-qiang, DU Wen-jun, ZHAO Zeng-yi, LENG Yan, CHEN Yi-fei, LI Zhen, XIE Guang-hui 2010, 31 (1):  61-62.  Abstract ( 124 )   PDF (176KB) ( 519 )   Save This paper presents the evaluations of the injected water and formation water compatibility and the injected water on reservoir damage through Di-2 well area's reservoir sensitivity experiment, showing that this reservoir is of medium-serious water-sensitivity, with critical salinity of 9 339.32 mg/L, good compatibility, and when injected rate is up to 30 times of pore volume, the permeability loss factor is up to 41.6% in average by simulated evaluation of reservoir damage due to water flooding. References | Related Articles | Metrics

Study of Production Decline Model for Dual Porosity-Homogeneous Composite Reservoir ZHAO Hai-yang, JIA Yong-lu, WANG Dong-quan 2010, 31 (1):  63-65.  Abstract ( 118 )   PDF (330KB) ( 552 )   Save In view of reservoirs with different properties near and far wellbore, the mathematic model for dual porosity (inner zone)- homogeneous (outer zone) composite reservoir is presented and solved, obtaining log-log type plots of production rate, rate integration and its derivative, and making analyses of flow mechanisms and plot characteristics at each flowing stage. Study shows that when the inner zone's permeability is better, the derivative curve of rate integration at junction of inner and outer zones will bend up, otherwise, fall down. The crossflow effect and its endurance are affected by storativity ratio. When the pressure spreads to the reservoir boundary, the rate will sharply decline, and the integral and integral derivative curves assume a straight line with slope of -1, which is the indication of harmonic decline. The case study obtains the main parameters in production decline stage, which are accordant with the real situations. References | Related Articles | Metrics

Theoretical Research and Application of Production Forecast Model of Oil-Gas Field ZHANG Jin-qing, SUN Fu-jie 2010, 31 (1):  66-68.  Abstract ( 163 )   PDF (276KB) ( 577 )   Save The decline characteristics of Arps model and Weibull model in decline stage are analyzed, and a new general model Qt=atq-1/ (1+pbtq)1/p for production forecast of oil and gas fields is proposed. It can be simplified into Arps decline model and Weibull growth model respectively when q=1 or p→0. The model can be used to describe the entire process of production and decline rate variations. It is applicable to prediction of production, cumulative production and reserves for various kinds of oil and gas fields. References | Related Articles | Metrics

Experiment for Improving Heavy Oil Recovery by Combination Steam Stimulation Process HUANG Wei-qiang, WANG Li-hua, CHEN Zhong-qiang, ZHENG Ai-ping, PENG Tong-shu 2010, 31 (1):  69-71.  Abstract ( 165 )   PDF (231KB) ( 477 )   Save In order to improve the development effect of Xinjiang heavy oil thermal recovery, seek a more comprehensive and more effective measures for incremental production of wells, this paper presents the experimental study by combination stimulation in view of the gelological characteristies of Qigu heavy oil reservoir in District 9(7+8), in which physical modelling and numerical modelling are carried out, including the technological mechanism, the screening and evaluation of combination stimulation expansion agent in different viscosities of crude oil, the evaluation of combination stimulation core flooding experiment and the optimization studies of combination stimulation injection process and injection parameters, as a new technology for improving the efficiency of steam flooding oil and reservoir recovery. References | Related Articles | Metrics

Study on Critical Liquid-Carrying Flow Rate for Gas Well PENG Chao-yang 2010, 31 (1):  72-74.  Abstract ( 187 )   PDF (289KB) ( 1094 )   Save The proper determination of minimum critical liquids carrying flow rate for gas wells is significant for gas production engineering planning. The latest experimental research indicated that the liquid droplet is close to ellipsoidal body with depth-width ratio of 0.9. For this reason, the liquid droplet deformation should be taken into consideration in calculation of critical carrying flow rate. This paper analyzes the rationality of previous models, considers the effect of liquid droplet flow on drag coefficient on the basis of liquidcarrying flow mechanism for gas well with water production, and then develops a new critical liquid carrying flow rate model for it. References | Related Articles | Metrics

Water Producing Performance Analysis in Sebei No.1 Gas Field in Qaidam Basin SHAN Gao-jun, DU Zhi-min, AO Ke 2010, 31 (1):  75-77.  Abstract ( 181 )   PDF (214KB) ( 571 )   Save Sebei No.1 gas field is now the largest unconsolidated sandstone gas field in China, with alternative gas and water layers, multi-thin layers and edge water. In the gas field development, the gas wells often produce water, so the control of water production is the one of the technical problems. This paper, on the basis of fine description of gas reservoirs, studies the characteristics of water production and gas production curves, water gas ratio value and its increased law to all wells in one layer of the gas reservoirs, analyzes the main water sources and the cause of water production. The water production in these wells is classified into four types, namely, the low water yielding and stable type, the low water yielding and slow growth type, the moderate water yielding and fast growth type and high water yielding and sharp growth one. According to the water production situations in different types of wells, the effective measures for water control are proposed by the classification. Field application of the measures showed good results. References | Related Articles | Metrics

Scaling Property and Regularity of Production Well by ASP Flooding Process in Daqing Oil Field ZHANG Qiu-shi, CHEN Wei 2010, 31 (1):  78-80.  Abstract ( 165 )   PDF (603KB) ( 727 )   Save Alkali-surfactant-polymer (ASP) flooding is of better effect for oil displacement than water flooding by EOR of over 20%. Because of the injection of alkali, the injection-production system by ASP flooding process is normally impacted by serious scaling of the wells, which is unfavorable for normal production of a field. This paper analyzes the representative scaling sample from ASP flooding in Daqing oil field. The result shows that the main components of the scaling are calcium and magnesium carbonates, silicate, pipeline corrosion product and organic matters, etc. and the scaling follows such regularities as: the carbonate content is gradually decreased with time in the same position of production well, but that of silicate is increased; the carbonate content is decreased, the silicate content is gradually increased from wellhead to wellbottom at the same time interval. The feasible suggestions are put forward on the basis of the scaling characteristics. References | Related Articles | Metrics

Compositional Distribution in Volatile Oil Reservoir with Compositional Gradient LI Ju-hua, LI Xiang-fang, LIU Bin 2010, 31 (1):  81-84.  Abstract ( 190 )   PDF (438KB) ( 608 )   Save This paper presents the charts of compositional gradient distribution of different types of reservoir fluids based on the data from 21 groups of fluid compositions that change with depth reported in literatures at home and abroad. It is preliminarily identified that the compositional gradient of C7+ in the volatile oil system varies in range of 0.01~0.05 mol%/m. Using the isothermal model of compositional gradient to predict the oil-gas contact, the light and heavy components and the physical parameters of crude oil in volatile oil reservoir, it is shown that the maximum rate of change occurs right near the oil-gas contact, displaying the distribution and variation of the fluid component and property with depth. Using the iso-compositional and isothermal gradient model to predict the PVT attribute, the relation chart of the crude oil volume coefficient and the solution gas-oil ratio with depth of reservoir is established for estimation of the range of geological reserves. For PB reservoir as a case, by using this simulation method, it shows that the re-estimated OOIP and OGIP are 5.38% and 3.9% higher than the original estimation values, respectively. References | Related Articles | Metrics

Using Silica-Calc Complex Plugging Agent for EOR LU Jian-guo, LV Qi-jun, SHEN Xin-an, SHI Lei 2010, 31 (1):  85-86.  Abstract ( 143 )   PDF (251KB) ( 260 )   Save For thin and bottom water reservoir, the U-like distribution pattern of remained oil is likely formed in condition of water drive, allowing the injected water to flowing down to the bottom water layer, hence decreasing the oil-displacement efficiency. This paper presents such an idea for allowing the injected water to flowing up to the top of U-like watered-out area by adding suitable chemical agent into the reservoir and making it react with Ca2+ and Mg2+ in formation water, resulting in gradually forming low permeable zones. The bottom-water modeling equipment is used to simulate the feasibility of such a reaction between silica-calc complex agent (SCAP) and the calcium and magnesium ions for forming low permeable zone, for the purpose of enhancing oil recovery (EOR). References | Related Articles | Metrics

Determination of Net Pay Thickness and Permeability of Fractured-Vuggy Reservoirs Using Performance Data WANG Zi-sheng, REN Ai-jun, YAO Jun, LU Quan-jie, KANG Wan-li 2010, 31 (1):  87-89.  Abstract ( 228 )   PDF (188KB) ( 304 )   Save It is difficult to determine the parameters such as net pay thickness and permeability of fractured-vuggy carbonate reservoirs using conventional methods. This paper presents a combination method for determination of them: Based on the production and performance data, the formation factor is firstly calculated by the methods of production index and well-testing interpretation. Then the relationship between the water breakthrough time and the open/perforating thickness, net pay thickness and other related parameters is established. Following determination of the net pay thickness by trial and error method, the reservoir permeability is finally determined, which is equal to formation factor divided by net pay thickness. This combination method has been applied to the fractured-vuggy carbonate reservoirs in Tahe oil field, showing that the calculate results are reasonable and reliable, and this method is more practicable. References | Related Articles | Metrics

Development and Application of Automatic System for Water Cut Analysis in Oil Field SHANG Jian-lina, XU Chang-xina, PENG Zhen-zhongb, FANG Xue-lianc, WANG Xian-taoa 2010, 31 (1):  90-92.  Abstract ( 155 )   PDF (214KB) ( 333 )   Save This paper presents a specialized application system intelligently collecting and managing analytical data of oil field. This system provides great conveniences for real-time and rapid analysis of and oil field production performance by a combination of scan-gun, FHS-A.E layered petroleum water cut analyzer, label printer and protocol converter, integrated with the application and improvement of port synchronization access and control. The water cut analysis and gathering system is of accuracy, security, stability, timely and high effectiveness. References | Related Articles | Metrics

Quantitative Interpretation of Watered-Out Conglomerate Resevior in Karamay Oil Field XU Chang-fu, PENG Shou-chang, WANG Xiao-guang, LI Hong-qi, TAN Feng-qi 2010, 31 (1):  93-95.  Abstract ( 165 )   PDF (309KB) ( 582 )   Save The conglomerate reservoir in Karamay oil field is characterized by complicated lithology, serious heterogeneity, varied salinity of injected water, which result in difficulty of quantitative interpretation of watered-out zones in it. This paper develops the models for lithology-based oil saturation, water cut and watered-out index by multivariate regression analysis. In combination with variation of the formation resistivity, the accuracy of well log interpretation of the watered-out zones can be effectively improved, thus meeting the demand of actural application of this technique. References | Related Articles | Metrics

Application of Azimuth P-Wave to Detection of Deep Volcanic Reservoir Fractures YU Hai-sheng, JU Lin-bo, YU Jing, SHU Ping, WEN Rui-xia 2010, 31 (1):  96-99.  Abstract ( 151 )   PDF (732KB) ( 644 )   Save In view of fractural detection, a variety of methods are adopted in terms of fractural size, but different methods give some different effects. P-wave azimuth anisotropy technique is now one of developing and improving techniques for reservoir fractural detection at home and abroad. According to variation of amplitude, frequency and velocity with azimuth when P-wave propagates in anisotropy medium, this paper presents a method for detection of fracture-developed azimuth and density in deep volcanic reservoir. It is found that the prediction result by this method is related closely with microscopic feature of fracture-developed zone. Taking the volcanic reservoir in F block in Xujiaweizi fault depression as a target, its fractural detection has been made with good effect. References | Related Articles | Metrics

Selection of Relative Molecular Mass of Polymers by Polymer Flooding Process in Conglomerate Reservoir—An example from T1k1 of East District 7(1) in Karamay field NIE Xiao-bin, LOU Qin-xiang, MAI Er-dang, GU Li 2010, 31 (1):  100-101.  Abstract ( 134 )   PDF (148KB) ( 423 )   Save Based on the data of core analysis, the relationship between the permeability and median radius of porosity in the conglomerate reservoir in Karamay field is established. Integrated with the relations of relative molecular mass of several polymers with suitable pore sizes given by filter membrane experiment, the method for selection of relative molecular mass of plymers by polymer flooding process in conglomerate is proposed. It is shown from this study that the polymer flooding of T1k1 of East District 7 (1) in conglomerate reservoir in Karamay field should be performed by the relative molecular mass of 2 500×104 of polymer. This method could be as a guide for the polymer choice of other conglomerate reservoirs. References | Related Articles | Metrics

The Hydrocarbon Source, Accumulation Mechanism and Exploratory Potential of Igneous Reservoir MENG Fan-chao, LIU Jia-qi, LI Ming, ZHANG Nian-fu, CUI Yan 2010, 31 (1):  102-106.  Abstract ( 166 )   PDF (279KB) ( 739 )   Save The study progresses of igneous petroleum reservoirs at home and abroad are reviewed. The results show that the commercial igneous reservoirs are dominated by those with biogenic hydrocarbons, but inorganic petroleum reservoirs should be paid great attention to. The hydrocarbon source and the mechanism of inorganic hydrocarbon generation of igneous reservoirs are discussed. It is illustrated that primary mantle outgassing, the rebalancing of C-O-H fluid within the closed system in late-magmatic stage of less than 500℃ and the mineral-fluid Fischer-Tropsch (FT) reactions in post-magmatic stage are the main sources of inorganic hydrocarbons. The source rocks in faulted period of basins in eastern China are well developed, with mantle-derived hydrocarbons in regional volcanic mantle inclusions and volcanic spring gas. The combinations of Alkaline-peralkaline granites and basic/ultrabasic igneous rocks are of suitable for FT reactions. These indicate that igneous reservoirs have huge potentials for petroleum exploration. References | Related Articles | Metrics

Petroleum Geology and Accumulation in Aryskum Depression in Turgay Basin TIAN Zuo-ji, XU Zhi-qiang, ZHENG Jun-zhang, ZHAO Jun-feng 2010, 31 (1):  107-109.  Abstract ( 180 )   PDF (316KB) ( 998 )   Save Aryskum depression locatedin Kazakhstan is a rift basin developed on the basements of Precambrian metamorphic rocks and Paleozoic carbonate rocks. This depression is very rich in oil and gas resources which enrichment and distribution are controlled by its tectonic feature and evolution. And there are different types of oil and gas reservoirs in lateral and vertical directions in it. This depression is situated within the effective scope of oil-gas migration from central depression to top of arch, favorable for oil-gas accumulation. Thanks to the sound assemblage between the regional cap rocks and the transmission systems, the oil-gas migration and accumulation are efficient in this area. Four models for oil-gas accumulation occur in Aryskum depression, among which the Lower-Middle Jurassic lithologic reservoirs are the main targets for incremental oil-gas reserves. References | Related Articles | Metrics