石油实验地质

2017, 39(6): .

Abstract(317) PDF-CN(459)

Abstract:

Principle of TSM basin simulation system and its application

Xu Xuhui, Zhu Jianhui, Jiang Xingge, Chen Yongfeng, Chen Yinbing

2017, 39(6): 729-737. doi: 10.11781/sysydz201706729

Abstract(1482) PDF-CN(736)

Abstract:
Basin modeling describes the evolutions of basin structure, deposition as well as hydrocarbon generation, migration and accumulation from both time and space aspects by using computer software based on physical and chemical principles of petroleum geology, by which oil and gas resources can be estimated. TSM basin simulation is a deterministic numerical simulation software system constrained by basin prototype and guided by a basin research program of "3T-4S-4M". The histories of burial, thermal evolution, hydrocarbon generation, migration and accumulation were simulated by using a deterministic hydrocarbon response simulation module and guided by the parallel and superposed analyses of basin prototype, in order to reasonably estimate hydrocarbon resources. This theory was applied in the West Sichuan Depression and revealed that basin prototype changed from continental margin depression to foredeep basin ever since the late Triassic. And the source rock generation, distribution and evolution characteristics as well as the hydrocarbon generation, migration and expulsion of the Upper Triassic Xujiahe Formation were also illustrated. Simulation results showed that the subsidence of depression during Jurassic was an important reason for the difference of hydrocarbon generation and discharge in various formations. The final structure in the middle-late Jurassic epoch controlled natural gas migration and accumulation, and formed two favorable resource gathering areas, Xiaoquan-Fenggu and Anxian-Duck River-Dayi, reflecting the controlling on hydrocarbon generation and accumulation by prototype basin superposition. This application showed that TSM basin simulation reveals dynamically the oil and gas evolution, which means "prototype controlled sources, superposition controlled accumulation", and predicts undiscovered oil and gas by fitting with the known. TSM software is an important technology and tool in the field of oil and gas exploration.

Dynamic models and equations of hydrocarbon migration and accumulation in graben basins:A case study of the Maichen Sag, Beibuwan Basin

Liu Hongyu, Chen Wei, Wu Feng

2017, 39(6): 738-746. doi: 10.11781/sysydz201706738

Abstract(910) PDF-CN(405)

Abstract:
The quantitative research of hydrocarbon migration and accumulation dynamics has become a trend and important direction of petroleum geological research with the gradual development of oil and gas exploration and increasingly complex exploration conditions. This paper concentrates on the commercial quantity of hydrocarbon to establish a new method, which can calculate the dynamics and resistance of hydrocarbon migration and accumulation quantitatively, by selecting several dynamic and resistance parameters in macro level. Considering the episodic accumulation features in graben basins and the different processes of hydrocarbon generation, migration and accumulation, the paper utilizes this method to analyze the relationship between accumulation dynamics and resistance during the critical episodic accumulation stage and to establish four dynamic models including the overpressure drive dynamic model, the continuous migration dynamic model, the lateral seal dynamic model and the buoyancy driven dynamic model accompanied with their equations. An example from the Maichen Sag of Beibuwan Basin has been given in this paper to illustrate the features of accumulation dynamics and resistance distribution by compiling their isogram maps through calculating these parameters and to judge the direction and distance of hydrocarbon migration and accumulation quantitatively. And then, the best prospective traps have been given at last.

Formation mechanism, sedimentary model and typical example of a deep-water gravity flow in continental slope-basin systems

Luo Shuaibing, Zhang Li, Lei Zhenyu, Wang Xiaobing, Yang Yuchen

2017, 39(6): 747-754. doi: 10.11781/sysydz201706747

Abstract(1094) PDF-CN(450)

Abstract:
The development of deep-water gravity flow sedimentary models in oil-and-gas exploration has evolved from the discovery of a variety of large-scale oil-and-gas fields in deep-water gravity flow deposits, which in turn drives further development of deep-water gravity flow sedimentology. However, since the system is complicated and is not yet well understood, deep-water gravity flow models are not only different in terms of use and classification schemes, but also have different views on formation mechanisms. This situation has seriously hindered the development of the theory of the deep-water gravity flow and its identification. This paper tried to clarify the formation mechanism of deep-water gravity flow based on previous studies about the types and flow patterns of gravity flow, and combined with examples from the South China Sea and the southwestern sea area of the Taiwan Strait Basin. Research showed that, in the formation of deep-water gravity flow, there are many kinds of interaction and controlling mechanisms, including water depth, source supply, slope folding shape and angle, triggering mechanism and regression mechanism, which together determine the morphology, classification and sedimentary characteristics of the deep-water gravity flow sedimentary system.

Constraints of hydrocarbon migration in Longmaxi shale in Sichuan Basin on shale gas accumulation

Wang Jia, Tan Xianfeng, Tian Jingchun, Luo Chao, Ran Tian, Chen Qing, Li Xia, Zeng Chunlin

2017, 39(6): 755-762. doi: 10.11781/sysydz201706755

Abstract(956) PDF-CN(472)

Abstract:
A shale gas reservoir is typically a continuous hydrocarbon reservoir, and its formation and enrichment cannot be separated from the shale. The generation, migration and accumulation of natural gas are the key factors for the effective accumulation of shale gas in shale. The Longmaxi shale in Sichuan Basin has excellent geochemical parameters and reservoir characteristics as indicated by organic geochemical analysis, X-ray diffraction and scanning electron microscopy and on drilling and outcrop data. We studied the tectonic evolution of well PY1 in Sichuan Basin and the thermal evolution history of organic matter in the Longmaxi shale. Compared to the Barnett shale, the Longmaxi shale was buried deeper, and was preserved in an open state due to tectonic activity, which was unfavorable for free gas accumulation. Kerogen in the Longmaxi shale belongs to types I and Ⅱ. The early formed hydrocarbons discharged out of the shale in the form of oil, and only the late formed, overmature gas and secondary gas (from oil cracking) remained in the shale system, restricting the effective accumulation of shale gas to some extent.

Physical simulation and discussion of the formation mode of the Silurian oil reservoirs in the Shuntuoguole region, Tarim Basin

Yun Jinbiao, Song Haiming, Feng Xingqiang, He Nini, Chen Yuanzhuang

2017, 39(6): 763-769. doi: 10.11781/sysydz201706763

Abstract(1268) PDF-CN(346)

Abstract:
Physical simulations were carried out with the S9 reservoir in the Shuntuoguole area of the Tarim Basin to study the hydrocarbon accumulation pattern in the lower section of Silurian Kalpintag Formation. Hydrocarbon mainly originated from the Cambrian-Ordovician source rocks. Faults provided pathways for hydrocarbon migration, and were most active during the late Silurian and Permian, which matched with two accumulation stages. A physical model was made according to the geologic structure of target section in S9 reservoir. Hydrocarbon was injected from the bottom of the model by continuous and steady or intermittent way, and then migrated upwards through faults. We mainly used the intermittent injection, and carried out simulations at pressure differences of 5,10,15 MPa. The faults with high, low and flexible permeability were applied in the simulation. The controls of fault property, pressure difference and injection way on hydrocarbon migration and accumulation were discussed, so as to study the necessary geologic conditions during hydrocarbon accumulation stages. The results showed that the lower section of the Silurian Kalpintag Formation was enriched with hydrocarbon during the Silurian-Devonian and Permian-Triassic, indicating for a possibility of early and large-scale reservoir.

Pore types and controls of Silurian reservoirs in Sanshun area, Tarim Basin

Zhang Fushun, Zhang Wang

2017, 39(6): 770-775. doi: 10.11781/sysydz201706770

Abstract(1183) PDF-CN(309)

Abstract:
High-quality reservoirs in the Silurian Kepingtage Formation play an important role in oil and gas exploration in the Sanshun area of Tarim Basin. The reservoir rock characteristics, pore type and pore evolution stage of the Kepingtage Formation were studied in detail using core analysis, thin section observation, cathode luminescence, ESEM, EDS, and inclusion temperature. The controls of high quality reservoirs were identified and combined with sedimentary and diagenetic analyses. The research suggested that lithic sandstones with low compositional and textural maturities were deposited in the low-energy muddy nearshore of the lower Kepingtage Formation, and then strongly impacted by compaction. Hence they were dominated by residual intergranular pores. Reservoir properties were controlled by sedimentary facies and compaction. Porosity in the sandy shore sand in the upper Kepingtage Formation was well connected laterally and longitudinally. Dissolution improved reservoir properties, and the last phase of secondary dissolution contributed greatly to reservoir quality.

Upper Carboniferous unconformity and reservoir development model of the western Maigaiti area, Tarim Basin

Jiang Haijian, Luo Yun, Li Qun, Zhou Yushuang

2017, 39(6): 776-782. doi: 10.11781/sysydz201706776

Abstract(1096) PDF-CN(308)

Abstract:
In the western Maigaiti area in the Tarim Basin, the Carboniferous oil and gas reservoirs discovered in the Bashituo and Yasongdi areas showed a good prospect for hydrocarbon exploration. However, their development models are not clear. Unconformity characteristics were analyzed through seismic and drilling/logging stratigraphic comparison, and reservoir development features were studied combing core and seismic data. The western Maigaiti area uplifted and was eroded during the Bachu Movement in the Late Carboniferous, forming two unconformities including T₅⁵ (between the Kalashayi and Xiaohaizi formations) and T₄⁵ (between the Xiaohaizi and Nanzha formations). The T₅⁵ unconformity is a tectonic unconformity, and mainly formed karst geomorphologies such as uplift, slope and valley. It developed two karst systems, the vadose zone and shallow undercurrent belt, and the deep undercurrent belt. Favorable reservoirs mainly locate on karst slopes. The T₄⁵ unconformity is a stratum unconformity controlled by paleotopography and eustatic movement. Dolomitic reservoirs and fresh water leaching reservoirs developed in intraplatform shoal with high landform in the highstand system tract in the Xiaohaizi Formation.

Lateral deformation difference of strike-slip faults on the northern slope of Tazhong uplift and its control on petroleum geology

Fu Chenyang, Tang Liangjie, Cao Zicheng, Han Xiaoying, Wei Huadong

2017, 39(6): 783-789. doi: 10.11781/sysydz201706783

Abstract(1051) PDF-CN(345)

Abstract:
The lateral deformation difference of strike-slip faults on the northern slope of Tazhong uplift and its control on petroleum were studied based on 3D seismic interpretation and attribute statistical analysis. The structural styles of the strike-slip faults included single steep strike-slip faults, overlaid positive and negative flowers, and en echelon normal faults. The Shuntuo No. 1 strike-slip fault was divided into five parts along its strike, changing from cover-decollement to basement involvement patterns from east to west. The Shunnan-2 strike-slip fault was divided into four parts along its strike. According to deformation strength, the Shuntuo No. 1 strike-slip fault was divided into five strong parts and four weak parts, while the Shunnan-2 strike-slip fault was divided into two strong parts and two weak parts. The deformation difference of strike-slip faults played an important role in reservoir development and hydrocarbon accumulation.

Paleo-karstification of the Ordovician carbonate reservoirs and the relationship with fractures in the Halahatang area of Tarim Basin

Wu Guoqiang, Zhang Lijuan, Yang Zhenzhou, Yuan Wenfang, Qi Chunyan, Ye Yu

2017, 39(6): 790-796. doi: 10.11781/sysydz201706790

Abstract(1325) PDF-CN(286)

Abstract:
The Ordovician reservoirs in the Halahatang area of Tarim Basin are carbonate reservoirs and the storage space is karstic vugs and fractures. Types and characteristics of paleo-karstification in the Ordovician carbonate reservoirs were comprehensively analyzed by outcrop study, core observation, thin section analysis, SEM-CL spectrum and SEM-EDS analysis. Coarse-clast collapsed chaotic breccia facies, fine-clast transported chaotic breccia facies, highly disturbed strata facies and undisturbed strata facies were identified in the Xikeer outcrop by outcrop analog. Chaotic breccia related to paleo-caves was found in different formations of the Ordovician under core observation. The Ordovician reservoir experienced three types of paleo-karstification, including penecontemporaneous karstification, weathering karstification and buried karstification. Different karstic vugs demonstrated different SEM-CL spectrums. Widely developed fractures in the reservoir have a significant influence on burial karstification. On one hand, factures promoted karstification by connecting stylolite networks; on the other hand, fractures induced karstification by carrying deep hydrothermal fluids into the reservoir.

Genetic model and characteristics of the Cambrian Shorebulake reservoir in Bachu area, Tarim Basin

Li Bin, Peng Jun, Yang Suju, Xia Qingsong, Xu Qingqi, Hao Yueqi

2017, 39(6): 797-804. doi: 10.11781/sysydz201706797

Abstract(1260) PDF-CN(333)

Abstract:
Knowledge of the Cambrian Shorebulake reservoirs in the Bachu area of Tarim Basin is limited at present. Core and microscopic observations as well as geochemical analyses showed that grain dolomites and microcrystalline dolomites are common in the Shorebulake Formation. Reservoir physical properties were obviously influenced by rock structure, and the porosity and permeability of fine-grained and powdery dolomites are the best. The reservoir space in the Shorebulake Formation was mainly composed of intergranular pores, dissolution holes and fractures, with low discharge pressure and fine to medium pore-throats, showing a good reservoir capacity. The diagenetic transformation of the reservoir was dominated by buried dolomitization, and partially affected by hydrothermal activity. The Himalayan movement added fractures to the study area, which enhanced communication of residual pores and helped acid fluid transform reservoirs, increasing reservoir volume to a certain extent and resulting in the present favorable reservoirs. The superimposed area of multi-phase tectonic fractures is considered as a favorable place for the Shorebulake reservoir in the Bachu uplift.

Micro-flow characteristics and controls of Chang 4+5 reservoirs in the western Nanliang oil field, Ordos Basin

Ren Jiangli, Zhu Yushuang, Liu Linyu, Wang Wei, Wang Zhenchuan, Chen Dayou

2017, 39(6): 805-811. doi: 10.11781/sysydz201706805

Abstract(1131) PDF-CN(265)

Abstract:
A model of real sandstones was applied to study the micro-flow characteristics and oil displacement efficiency of the Chang 4+5 reservoirs in the western Nanliang oil field to improve the efficiency of water flooding. The micro-structure was studied with casting thin sections, scanning electron microscopy and mercury injection in order to estimate the influences of reservoir characteristics and micro-flow experiment factors on water flooding efficiency. The results showed that the Chang 4+5 reservoirs were dominated by homogeneous seepage, while finger-type seepage and net-type seepage also existed locally. The homogeneous seepage resulted in the highest final oil saturation and final displacement efficiency. For the internal factors affecting displacement efficiency, heterogeneity played a key role, and reservoir wettability was also important. Permeability was positively related to oil displacement efficiency, while porosity had a weak influence on oil displacement efficiency. Two external factors, water injection pressure and volume multiple, could enhance displacement efficiency, and the influence of pressure was more significant.

Effective reservoir identification and “sweet spot” optimization of Chang 7 tight oil reservoir in Xin'anbian oil field, Ordos Basin

He Chongkang, Cheng Liangbing, Chen Xufeng, Sun Dianxiang, Li Chao, Zhao Guoxi

2017, 39(6): 812-818. doi: 10.11781/sysydz201706812

Abstract(1809) PDF-CN(373)

Abstract:
We proposed criteria whereby tight oil wells can obtain industrial oil flow under the current technical conditions based on the well test results and dynamic production data for Chang 7 tight oil reservoirs in the Xin'anbian oil field of the Ordos Basin. The criteria were established using core observation, petrophysical logging results, reservoir analysis, and well-logging response. We found that the effective fine sandstone formation has porosity greater than 5.5%, and permeability greater than 0.03×10^-3 μm². Mercury injection experiments under constant rate showed that the channel radius is greater than 0.25 μm, the movable fluid saturation is greater than 30%, and the interval acoustic transit time in well logging is larger than 215 μs/m. In the "sweet spot" zone, oil saturation ishigher, and the measured gas value in well cutting logging is 3 times higher than that of the baseline, and the resistivity is greater than 30 Ω·m. The maximum thickness tolerance for a single oil layer in well drilling should be greater than 4 m, and the thickness of multi-layer oil is more than 6 m. In optimization, favorable zones were firstly selected from the sedimentary facies belt, and then the lower limit criteria of reservoir physical properties and layer thickness to make "sweet spot" zone selection. During development, oil saturation and adjacent well performance were considered for reducing the risk of low yield or low efficiency areas. Through the screening analysis of the technical indicators above, the proven oil reserve is up to 100 million tons in the Xin'anbian oil field.

Late tectonic deformation characteristics and stress mechanism in Lunpola Basin, Tibet Plateau

Liu Zhongrong, Li Xiangquan

2017, 39(6): 819-824. doi: 10.11781/sysydz201706819

Abstract(1131) PDF-CN(195)

Abstract:
The 2D seismic data of the Lunpola Basin showed that the late tectonic deformation of the basin could be classified into four types:tensional-torsional lateral adjustment, thrust-depression, compressive folding and compressive-torsional uplifting. Ten tectonic deformation partitions were identified:thrust, compressive folding and compressive-torsional uplifting belts in the south and north, respectively, compressive-torsional uplifting and thrust-depression belts in the west, tensional-torsional lateral adjustment belt in the center, and thrust-depression, compressive folding belts in the east. Tensional and compressive structural styles coexist in the Lunpola Basin, and were controlled by the regional sinistral strike-slip compressive stress, which are the most unique characteristics of late tectonic deformation of the basin.

Petroleum geology and resource potential of major basins in South America

Tian Naxin, Jiang Xiangqiang, Shi Lei, Zeng Yuxin

2017, 39(6): 825-833. doi: 10.11781/sysydz201706825

Abstract(1539) PDF-CN(417)

Abstract:
Hydrocarbon enrichment and accumulation in different types of basins in South America were studied from the perspectives of regional geology, basin, petroleum system to play, and their resource potentials were estimated. Basins in different parts of South America have different tectonic evolution features due to the expanding and closing of the Atlantic and Pacific oceans. Four basin types developed:craton, rift, passive continental margin and foreland basins. Oil and gas mainly accumulated in the Andean foreland basins and the passive continental margin basins on the Atlantic coast, accounting for 80.4% and 14.7% of the discovered hydrocarbon, respectively. Stratigraphically, most oil and gas accumulated in the Mesozoic and Cenozoic sandstone and carbonate reservoirs, especially in sandstones. On the basis of comprehensive geological evaluation, the undiscovered resources of 34 plays in 9 major basins were calculated, and subsequently the first two prospective plays were identified.

Distribution and origin of rearranged hopanes in Yanchang Formation, Wuqi-Gaoqiao area, Ordos Basin

Dong Junyan, Chen Shijia, Zou Xianli, Yao Jingli, Li Yong, Su Kaiming

2017, 39(6): 834-841. doi: 10.11781/sysydz201706834

Abstract(1166) PDF-CN(163)

Abstract:
A high abundance of rearranged hopanes has been detected from source rocks of the Triassic Chang 7,8,9 formations in the Wuqi-Gaoqiao area of the central Ordos Basin.We classified 3 types of source rocks and separately analyzed their genesis compared with the characteristics of biomarkers from different formations.The gas chromatography-mass spectrometry (GC-MS) analyses indicated that there were three series of rearranged hopanes in the source rocks,which are 17α(H)-diahopanes,early-eluting rearranged hopanes and 18α(H)-neohopanes.Moreover,early-eluting rearranged hopanes are commonly associated with high abundant 17α(H)-diahopanes and 18α(H)-neohopanes,meanwhile,rearranged drimanes and rearranged steranes are detected in source rocks which also retain high amounts of those three types of rearranged hopanes.This indicates that the genesis and alteration of rearranged compounds are probably affected by similar processes.Many geochemistry parameters showed that, the formation of rearranged hopanes could be closely related with higher plant source materials.Sub-oxic,freshwater and clay-rich depositional environment are beneficial for forming a significant proportion of rearranged hopanes. Higher thermal evolution favors rearranged hopanes;however,the content differences of hopanes affected by different pyrolysis rates at high maturity must be considered.

Characteristics and implications of carbon and oxygen isotopes in dolomites of the Ordovician Zhuozishan Formation in northern Tianhuan Depression, Ordos Basin

Xue Shiyu, Fu Siyi, Hou Mingcai, Gao Xing, Su Zhongtang, Hu Shangcai, Zhu Lijuan

2017, 39(6): 842-848. doi: 10.11781/sysydz201706842

Abstract(1281) PDF-CN(310)

Abstract:
The origin and geological significance of dolomites in the Ordovician Zhuozishan Formation in the northern Tianhuan Depression of the western Ordos Basin were interpreted based on spatial distribution and the characteristics of carbon and oxygen isotopes of different types of dolomites. There are three main types of dolomites in the study area, including powder-microcrystalline, residual sand-fine crystalline and fine-medium crystalline ones. The δ¹³C values of powder-microcrystalline, residual sand-fine crystalline and fine-medium crystalline dolomites are 0.78‰, 0.53‰, and 0.47‰, while the δ¹⁸O values are -5.0‰, -6.5‰ and -6.3‰, respectively. These values belong to normal marine carbonates, indicating that the dolomite fluid might come from ancient seawater. Carbon and oxygen isotope evolution and diagenetic effects showed that the powder-microcrystalline dolomites were formed during the quasi-synchronic stage, and the residual sand-fine crystalline and fine-medium crystalline dolomites were formed during the shallow burial stage.

Trace element characteristics and sedimentary environment of lacustrine carbonate rocks in the Huanghua Depression, Bohai Bay Basin

Wang Yongwei, Li Rongxi, Gao Shengli, Gao Pengpeng, Li Zemin, Gao Chao, Fu Mingyi

2017, 39(6): 849-857. doi: 10.11781/sysydz201706849

Abstract(1347) PDF-CN(239)

Abstract:
Carbonate rocks dominate in the lower part of the first member of Shahejie Formation in the Huanghua Depression, Bohai Bay Basin. The geochemical characteristics of trace elements in Kongdian-Yangsanmu, Qijiawu and Qinan show that the content and distribution of trace elements varied in different pays, but those of Sr, Ba, V, Mn, Th, U were similar, and the contents of Ni, Pb, Zn and others tended to decrease from Qijiawu to Yangsanmu, indicating environmental changes during the diagenesis process. The B content varied (7.5-92.8)×10^-6 with an average of 42.8×10^-6 in Qijiawu, and varied (7.2-97.4)×10^-6 with an average of 45.21×10^-6 in Kongdian-Yangsanmu, indicating an alternating process of saline to fresh water environments. The Ti content varied (946-3 496)×10^-6 and averaged 2 319×10^-6 in the lower part of the first member of Shahejie Formation from Kongdian to Yangsanmu, showing nearby provenance characteristics. The V/(V+Ni) ratio indicated strong reducingenvironment in the study area, and the low Th/U ratio showed a higher salinity of lake water or the influence of seawater intrusion.

Exploration approach and techniques for the Neogene lithologic reservoirs in the southwestern Huizhou Sag, Pearl River Mouth Basin

Du Jiayuan, Ding Lin, Zhang Xiangtao, Chen Weitao, Li Xiaoping

2017, 39(6): 858-864. doi: 10.11781/sysydz201706858

Abstract(1300) PDF-CN(723)

Abstract:
The exploration of lithologic reservoirs is one of the difficult fields in the Pearl River Mouth Basin. The key problems are how to accurately identify exploration zones and effectively implement lithologic traps. Throughout successive rounds of researches about geology and geophysics of the lithologic reservoirs in this field, an exploration approach double controlled by "source" and "facies" was formed, which effectively guided the exploratory zones' selection of lithologic reservoir. It has been proved by drilling that the Huizhou 26 subsag in the southwestern Huizhou district is rich in hydrocarbon. Next to the Huizhou 26 subsag, the Huizhou 21 structure and the Huixi low uplift, which are relatively higher, are favorable for oil and gas enrichment when connected with source rocks through fractures. During the Neogene sedimentary period in this area, shelf sand ridge and sand sheet isolated from delta system were the major sedimentary features in the Huizhou 21 structure, while the Huixi low uplift was featured by channel and mouth bar sand within delta front. These two kinds of sands pinched out laterally easily, which were both favorable for the formation of lithologic traps. Some key technologies, including high-resolution sequence stratigraphy analysis under rare wells, seismic attribute slice analysis under sedimentary model and recons-titution of isochronic genetic sand bodies, contributed a lot to the depiction of the pinchout boundaries of these target sands, which substantially implemented the lithologic traps in this area. With this exploration approach and these key technologies, the Neogene lithologic reservoir exploration achieved good results in the Huizhou 21 structure and the Huixi low uplift in the southwest Huizhou Sag.

Determination of halogenated hydrocarbons in outlet fluid for shale oil and gas reservoir fracturing by purge-and-trap and GC-MS

Guo Wei, Huang Chunhua, Zhao Xionghu, Zhang Xiaotao, Shen Bin, Wang Shuangqing, Sun Weilin

2017, 39(6): 865-872. doi: 10.11781/sysydz201706865

Abstract(1183) PDF-CN(319)

Abstract:
In shale oil and gas exploration, chemical tracer technology is effectively applied to the evaluation of fracturing technology. The precondition for the application of this technology is the establishment of corresponding analysis method. The authors selected 21 kinds of halogenated hydrocarbons as tracer, with stable chemistry character and low stratigraphic background values. And a high sensitivity detection method for the tracer by purge-and-trap and gas chromatography mass spectrometry (GC-MS) was developed. The conditions of purge-and-trap and GC-MS were optimized and the optimum conditions were obtained. The results showed that the detection limits were 0.027-0.162 μg/L. The average recoveries were 74.16%-121.9% with a precision lower than 12.79% (RSD, n=7). The established method is simple and fast, hence is applicable for the determination of tracer in fracturing outlet fluid samples after reservoir reconstruction.

2017, 39(6): 873-873.

Abstract(488) PDF-CN(102)

Abstract:

2017 Vol. 39, No. 6

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