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2007 Vol. 29, No. 4

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GEOCHEMICAL CHARACTERISTICS OF THE CAMBRIAN OIL AND GAS IN WELL TASHEN 1, THE TARIM BASIN
Zhai Xiaoxian, Gu Yi, Qian Yixiong, Jia Cunshan, Wang Jie, Lin Jun
2007, 29(4): 329-333. doi: 10.11781/sysydz200704329
Abstract(802) PDF-CN(539)
Abstract:
The Well Tashen 1 in Tarim Basin is the deepest subaerial well both in China and in Asia.The brown liquid hydrocarbon had been first discovered in the Upper Cambrian dolomite pore and cave with the formation temperature being 160℃,the formation pressure being 80 MPa and the buried depth being 8 400 m.The systematic geochemical analysis on the gas and liquid hydrocarbon from the Lower Ordovician to the Upper Cambrian in Well Tashen 1 shows that the content of hydrocarbon gas is 97 percent,the dryness factor of the gas is 0.97 and the average carbon isotope of CH4 is -37.9‰.The Ro of the correspondent source rock is from 1.65% to 1.91%,which is characteristic of typical oily dry gas with high thermal maturity.Various biomarkers and distribution of isotope of petroleum family composition in the saturated fraction from extracts of two samples in Well Tashen 1 indicate that the distribution of n-alkanes is complete(from nC13 to nC38 with the C23 being dominant),the OEP is 1.029,the C21-/C21+ is from 0.49 to 1.46 and the ratio of Pr to Ph(Pr/Ph) is from 0.762 to 0.991 with a predominance of phytane,suggesting a marine sapropelic source rock under the reduction to strong reduction environment.On the other hand,the parameters representing thermal maturity of biomarkers,such as Pr/nC17,Pr/nC18 and MPI,show the great difference between the Ordovician oil in Tahe oilfield and the liquid hydrocarbon in Well Tashen 1.The latter mostly like to the oils in Well Tadong 2 and Well T904 that is believed to come from the Middle and Lower Cambrian source rock.In addition,the liquid hydrocarbon in Well Tashen 1 is characteristic of sterane C27 > C28 << C29 and the isotope of petroleum family composition in the saturated fraction is -29.13‰ to -25.84‰.It can be inferred that the liquid hydrocarbons in the Upper Cambrian dolomite mostly come from the Middle and Lower Cambrian source rock and the high formation pressure is an important reason of the hydrocarbon being preserved in the deep buried formation.
TYPES AND DISTRIBUTION CHARACTERISTICS OF SHALLOW RESERVOIRS IN THE NORTH JIANGSU BASIN
Zhou Liqing, Wu Yuyuan
2007, 29(4): 334-339. doi: 10.11781/sysydz200704334
Abstract(888) PDF-CN(247)
Abstract:
There are three types of shallow reservoirs controlled by different key factors for hydrocarbon accumulation in the North Jiangsu Basin,respectively controlled by low maturity and high efficiency oil source rock in the lower-middle part of the Fu2 Member,fault of vertical migration pathway,and large scale sandstone for lateral migration.Distribution of shallow reservoirs is featured with hyperdispersion in the North Jiangsu Basin.Shallow reservoirs are developed in the Jinhu Sag and Gaoyou Sag in western basin,with various types and large scales.This distribution feature is correlated to the Tanlu Fault Belt controlling the structure and deposit evolution of basin as well as the key factors for hydrocarbon accumulation.The evidence is that the periphery of Tanlu fault depressions is well-developed of low maturity and high efficiency oil source rock in the lower-middle part of the Fu2 Member,sandstone in the bottom part of the Fu2 Member and the upper part of the Fu1 Member,forming abundant shallow reservoirs.Periphery Tanlu fault depressions are inherited from early deep rift with high geothermal gradient,with earlier matured oil.Faults are polyformative and of high density in the area near the Tanlu Fault Belt,which helps to form secondary shallow reservoirs of fault-passway type.Consequently,there are a lot of shallow reservoirs in the Jinhu Sag,the Gaoyou Sag and the Qintong Sag around the Tanlu Fault Belt.Shallow reservoirs distributed over the growth fault zone and the strike-slip flower fault system in inner-outer slope.There is a great exploration potential in the North Jiangsu Basin,if we aim at the three types of shallow reservoirs,and focus on their forming and distribution rules in these areas.
THE OIL-GAS CHARACTERISTICS OF THE FORELAND BASIN IN THE SOUTHEASTERN MARGIN OF THE DABIE MOUNTAINS
He Mingxi, Du Jianbo, Wang Rongxin, Zhou Jianwen, Cao jiankang, Ma Rongfang
2007, 29(4): 340-344. doi: 10.11781/sysydz200704340
Abstract(788) PDF-CN(249)
Abstract:
The foreland basin in the southeastern margin of the Dabie mountains experienced an evolution of marine sedimentation-marine-continental sedimentation-continental sedimentation and characterized by superimposed-composited pattern.From the deposit sequence of the foreland basin and combined with characteristics of source rocks and oil-gas system,it can be seen that the continental deposit system of the foreland during early Mesozoic overlies the marine deposit of the passive continental margin during late Paleozoic,and formed upper continental facies and lower marine facies hydrocarbon-bearing rock systems and oil-gas forming systems.Among the conditions,the key for oil-gas accumulation is development and preservation of the marine source rocks underlying the foreland basin.It proves that,the marine source rocks are high quality in the deposit on the passive continental margin during late Paleozoic period,moderate or higher geothermal evolution,which can produce oil and gas;the good container rock is marine-continental molasses;the high quality cover rock is gypsum rock in the marine-continental-evaporation facies,the correlation of generation-reservoir-cover rock is good,and which proved the foreland basin possess the basic conditions for oil-gas occurrence.
HYDROCARBON ACCUMULATION AND OIL-SOURCE CORRELATION IN THE FRONT OF JIANGNAN-XUEFENG MOUNTAIN——SERIES 3 OF THE SOUTHERN STRUCTURE STUDIES
Ding Daogui, Liu Guangxiang, Chen Yuhua, Pan Wenlei, Zhai Changbo, Rao Dan
2007, 29(4): 345-354. doi: 10.11781/sysydz200704345
Abstract(660) PDF-CN(366)
Abstract:
The Jiangnan-Xuefeng uplifted belt is a nappe formed by basement decoupling from southeast to northwest and from south to north at the end of Middle Triassic Indosinian movement.It caused the Middle Palaeozoic marine sedimentary basins to be deformed with the intensity decreasing progressively.A series of palaeo-asphalt oil pool of fracture-anticline type,such as Tongjiang Bankeng,Fenghuang Shuidatian,Alaying,Cili Nanshanping,Majiang,etc.,formed in the overthrust-fault curve folding belt(B zone) in the front of Jiangnan-Xuefeng mountain,in the Lower Palaeozoic.In overthrust fault,i.e.faulted unfurl folding belt(C zone),the oil pools of faulted unfurl anticline type and surface oil formed in the Upper Paleozoic strata in Chibi Beimencha,Cili Miaoshi,etc.Oil-source correlation shows that these palaeo-asphalt oil pools accept the oil from the Lower Camberian,Lower Silurian and Lower Permian slope facies source rock in the Early Palaeozoic cratonic marginal subsidence in Indosinian-Early Yanshan period.They migrate to platform and accumulate in the "X" type fracture belt and compressional anticline in the front of nappe.
HYDROCARBON PLAY AND CONTROLLING FACTORS IN FOLD-THRUST BELT OF THE SOUTHERN JUNGGAR FORELAND BASIN
Da Jiang, Song Yan, Liu Shaobo, Hong Feng, Zhao Mengjun, Fu Guoyou
2007, 29(4): 355-360. doi: 10.11781/sysydz200704355
Abstract(935) PDF-CN(392)
Abstract:
It is discussed in this paper hydrocarbon plays and controlling factors in the fold-thrust belt of the Southern Junggar Foreland Basin.According to the study,there are excellent hydrocarbon source rocks,reservoirs and caprocks in the belt.Furthermore,the abnormal overpressure is in good sealing condition for hydrocarbon accumulation.According to the key factors and the matching of hydrocarbon plays,hydrocarbon plays in this region are divided into two types,namely the lower play with Permian-Jurassic source rock and Triassic-Jurassic reservoir,and the upper play with Jurassic-Tertiary source rock and Cretaceous-Tertiary reservoir.Furthermore,three hydrocarbon sub-plays are suggested,namely the lower Permian-Jurassic play,the middle Jurassic play and the upper Tertiary play.Main controlling factors for hydrocarbon plays in this region are hydrocarbon source rock,fracture,caprock and overpressure.The upper play with Jurassic-Tertiary source rock and Cretaceous-Tertiary reservoir is favorable for exploration.
EXPLORATION STRATA AND BREAKTHROUGH ORIENTATION OF MARINE FACIES NATURAL GAS IN THE MIDDLE YANGTZE REGION
Zhang Shiwan, Yang Zhenwu, Liang Xiwen, Chen Xuehui
2007, 29(4): 361-366. doi: 10.11781/sysydz200704361
Abstract(838) PDF-CN(359)
Abstract:
Marine facies strata in the middle Yangtze region have experienced 4 big cycles including Caledonian,Hercynian-early Indosinian,late Indosinian-early Yanshanian,and late Yanshanian-Himalayan during geological evolutions,giving birth to 3 types of basin: shallow-sea facies,foreland depression and rift-subsidence.Sedimentary packing and deformation of stages of basin have formed foundation for petroleum accumulation.Influenced by eustacy,controlled by sedimentary palaeogeologic environment and surface corrosion,different types of reserve such as Dengying Formation of Upper Sinian,Shilongdong Formation of Lower Cambrian,Huanglong Formation of Middle Carboniferous and Maokou Formation of Middle Permian are formed.The middle Yangtze region is set in platform edge reef bank background during late Permian and early Triassic,generating reef and bank in platform.On the other hand,sandstone reserves generated widely during Silurian foreland basin evolution should be the focus for Paleozoic exploration in South China.Different types of reserve prove large fields for exploration in the region.Study of reserve sedimentary facies,precise seismic prediction,as well as geophysical respond and distribution rules of different types of reserve is the key for exploration breakthrough.Large gas fields should be paid attention to.The upper,middle,lower strata and multifields should be taken into consideration.Breakthrough can be made in favorable areas.
HYDROCARBON ACCUMULATION ZONES OF ORDOVICIAN CARBONATE RESERVOIR IN TAZHONG AREA OF THE TARIM BASIN
Chen Qianglu, He Zhiliang, Li Sitian
2007, 29(4): 367-372. doi: 10.11781/sysydz200704367
Abstract(742) PDF-CN(360)
Abstract:
Tazhong area of the Tarim Basin is restricted-open platform facies carbonate rock sediments from early to middle Ordovician.During the early stage of late Ordovician,the region develops to peninsula-like isolated platform and reef-band facies sediments along platform margin are deposited.Due to uplifts from middle Caledonian to early Hercynian,Tazhong area has experienced stages of supergene karst effects.Based on analysis of stages of tectonic evolution,it is pointed out that,Ordovician carbonate rock reservoirs in this region are controlled by palaeo-geography,sedimentary facies and diagenetic deformation stages.There are 4 types of reservoirs correspondingly: supergene karst,reef-band along platform margin,dolomite and hydrothermal deformation.Hence 4 types of accumulation zone are divided.
ACCUMULATION CHARACTERISTICS AND PETROLEUM DISTRIBUTION IN JIUFOTANG FORMATION, THE LUXI SAG, THE KAILU BASIN
Wang Qijun, Zan Guojun, Fang Binzhong, Sun Chao, Zhang Xilin
2007, 29(4): 373-376. doi: 10.11781/sysydz200704373
Abstract(974) PDF-CN(330)
Abstract:
The Luxi Sag in the Kailu Basin is a Meso-Cenozoic faulted basin with high quality source rock in which kerogen belongs to type Ⅰ-Ⅱ and the source rock has entered low maturity-maturity stages for oil generation.Source rock quality of the lower member of Jiufotang Formation is better than that of the upper member.Oil generation and discharge took place during Yanshanian epoch and Late Cretaceous.The main centers for oil generation locate in Wushijiazimiao as well as Xiaojingzi.Oil accumulation mainly occurred during Fuxin stage.Sandbody distribution of delta,nearshore subaqueous fan is controlled by fault activities.These sandbodies develop primary porosity and are characterized by high-medium porosity and low permeability when buried over 1 600 m deep.The mudstone of Shahai and Fuxin Formations works as regional cap.The mudstone of Jiufotang Formation is local cap.The Majiapu uplift,Baoriwendu fault belt and Mabei slope are close to source center,and are the areas for oil migration trend.The oil formation in lithologic-structural trap and lithologic trap is controlled by the organic combination of sandbodies and faults.The authors predict that the favorable regions for oil exploration locate in the northern Majiapu uplift and the middle Baoriwendu fault belt.
KEY FACTORS TO CONTROL FORMATION CONDITIONS OF STRATIGRAPHIC POOLS IN CHEPAIZI AREA, THE WEST OF THE JUNGGAR BASIN
Jing Hui, Jiang Hong, Xiang Kui
2007, 29(4): 377-383. doi: 10.11781/sysydz200704377
Abstract(673) PDF-CN(488)
Abstract:
Based on analysis of strata,structure,facies and petroleum in Chepaizi area in the west of the Junggar Basin,accumulation types in this region have been counted.Studies of source condition,reservoir characteristics,conducting characteristics and trap preservation,together with drilling success and failure effectivity,have indicated that,traps in Chepaizi area are mainly lithologic ones.Source condition is good.Faults and unconformities work as complex conducting system.Favorable reservoir facies and physical properties control petroleum accumulation.Trap condition and its preservation are the keys for final accumulation.Reservoir physical property and reservation are the main factors controlling lithologic pool formation in this area.
DIAGENESIS AND RESERVOIR EVALUATION ON THE UPPER PALAEOZONIC RESERVOIR SANDSTONES IN DANIUDI GAS FIELD, THE ORDOS BASIN
Luo Yueming, Liu Weixin, Tan Xuequn, Yang Qi
2007, 29(4): 384-390. doi: 10.11781/sysydz200704384
Abstract(939) PDF-CN(305)
Abstract:
The diagenesis stages of the reservoir sandstones in the Upper Palaeozonic strata in Daniudi Gasfield,northern Ordos Basin,were studied.The results show that the vitrinite reflectance(Ro) of the Taiyuan Formation and the First Member of Shanxi Formation is between 1.4% and 1.5%,the inclusion homogenation temperature is 140℃ and the percentage of montmorillonite is usualy less than 30% in illite-montmorillonite mixed-layer mineral,indicating the stage B of metarmosis.The Lower Shihezi Formation(including P1x1,P1x2 and P1x3 Members) is in the stage A of metarmosis with the Ro being 1.3%-1.4%,the inclusion homogenation temperature being 126℃ and the percentage of montmorillonite being 32%-36% in illite-montmorillonite mixed-layer mineral.The inclusion homogenation temperature of the Second Member of Shanxi Formation is complicated,but still can be considered as in the stage A of metarmosis.The main diagenesis processes that control the reservoir properties include compaction,cementation(silicide,carbonates,clay minerals),dissolution and fracturing.The types of pores are primary intergrain pore(residual),intercrystalline micro-pore and intergrain or intragrain solution pore(including moldic pore).The reservoir generally belongs to the type of low-porosity and low-permeability.The microfractures in formation greatly improve the reservoir properties and contribute to higher gas yield in P1x3 and P1x2 than in P1x1 and other reservoirs.
STUDY ON THE LOWER LIMIT OF HYDROCARBON EXPULSION OF MARINE CARBONATE ROCKS
Qin Jianzhong, Liu Baoquan, Zheng Lunju, Zhang Qu
2007, 29(4): 391-396. doi: 10.11781/sysydz200704391
Abstract(665) PDF-CN(298)
Abstract:
The pyrolysis and hydrous pyrolysis simulating experiments of samples with differentTOC which confected by burned calcite,smectite,limestone and mudstone added into the same organic mat-ters respectively,show that the content of absorpted hydrocarbon by the marine carbonate rock is usually about 0.35 mg/g and the range is 0.2-0.85 mg/g,the content of absorpted hydrocarbon by the shale is usually about 1.25 mg/g and the range is 0.46-2.62 mg/g.The lower limit of total organic carbon(TOC) is about 0.08% for hydrocarbon expulsion of high-to-over mature marine carbonate rock and about 0.3% for mature marine carbonate rock rich in hydrocarbon.The lower limit of total organic car-bon(TOC) for hydrocarbon expulsion is related with the quantity of absorpted hydrocarbon by source rocks,the type of kerogen and the maturity of organic matters.
RESEARCH ON INDICATORS OF OIL-SOURCE CORRELATION IN THE SUBEI BASIN
Chen Anding
2007, 29(4): 397-401. doi: 10.11781/sysydz200704397
Abstract(675) PDF-CN(334)
Abstract:
There are three sets of oil source rock in the Subei Basin.They are the Second Member of Taizhou Formation in the Upper Cretaceous,the Second Member and the Fourth Member of Funing Formation in the Paleocene.Their kerogen properties and geological environments are similar.They are difficult to be distinguished by using common indexes.For this reason,a multi-parameter plate and such indicators as normal alkane,primary sterane,triaromatic steroid series and dimethyl carbazole series have been suggested and triumphantly used for source-rock identification in the Subei Basin.It is recommendable that the dimethyl carbazole series being used for oil-gas migration researches show the amazing stability in discrimination of the oils with the same sources.This provides a detail fingerprint information on the further division of oil origins.
APPROACH TO SOLID MIGRABITUMEN MECHANISM OF CARBONIFEROUS GAS RESERVOIR IN THE EAST OF SICHUAN BASIN
Li Yanxia, Zhong Ningning
2007, 29(4): 402-404. doi: 10.11781/sysydz200704402
Abstract(620) PDF-CN(308)
Abstract:
The formation mechanism of a great deal solid migrabitumens of Carboniferous gas reservoir in the east of Sichuan Basin is discussed.There are high content methane and solid bitumen in the gas reservoir.Solid bitumens mainly distribute system of dissolution pore(intergrain pore,insidegrain pore and intercrystalline pore),fracture(fissure) and dissolution cavity in carbonate reservoir.Compared with other composition in gas reservoir and source rock,such as δ13Csaturated,δ13Caromatic,δ13CNOS,δ13Casphaltenes and δ13Ckerogen,the value of δ13Cbitumen is the heaviest and mainly range from -28.83‰ to -23.99‰.But δ13C value of methane is the lightest and about -37.7‰ to -29.2‰.The difference is result of carbon isotope thermal dynamical frationaction.With increasing depth and rising temperation,there is a tendency for crude oils in reservoirs to become specifically low lighter molecular hydrocarbon and high molecular weight constituent.The ultimate stable end products are low molecular methane and insoluble carbon-rich residue of very high molecular weight.Finally crude oils in reservoirs crack into gas and solid bitumen.The formation mechanism of solid migrabitumen is a result of high molecular with aromatic cycles condensation insoluble carbon-rich residue.
RESEARCH OF THE OIL-GAS SOURCE AND FORMATION OF THE POOLS IN THE SHALLOW BED OF THE SHENGBEI SAG, THE TUHA BASIN
Li Yanjun, Chen Yicai, Zhang Yanyun, Guo Xiuying, Yangjun
2007, 29(4): 405-410. doi: 10.11781/sysydz200704405
Abstract(724) PDF-CN(281)
Abstract:
By the comprehension correlation of the crude oil carbon isotope,light hydrocarbon,oil-rock biomarker,the paper indicates that the oil-gas in the shallow bed are mainly provided by the Shuixigou Group coal seam of Middle-Lower Jurassic series,and some areas are mixed with the hydrocarbons generated from lake facie shale of the Middle Jurassic Qiketai Formation in the Shengbei Sag,Tuha Basin.In the meantime,it shows that the fault passed through the regional cover(J2q-J3q) is a key to migration and collection of the oil-gas in the shallow bed.Furthermore,the author thinks that the time and way of the oil-gas migration and collection are different in the different areas,which is the characteristic of capturing oil-gas in stags to form pool,example for,Hongnan structure belt,which is later for the shallow oil-gas to migrate,and mainly redistributed that the oil-gas has collected in middle Jurassic,and is secondary oil-gas pool.But,as for Shengbei structure belt,which is earlier for the shallow oil-gas to migrate,and is mainly the low-mature hydrocarbons of the Shuixigou Group coal seam to be captured.
HYDROCARBON SOURCE ROCK EVOLUTION IN TAIZHOU FORMATION, THE GAOYOU SAG, THE NORTH JIANGSU BASIN
Wang Yongjian, Wang Yanbin, Zheng Yabin, Liu Guofeng
2007, 29(4): 411-414. doi: 10.11781/sysydz200704411
Abstract(1054) PDF-CN(328)
Abstract:
Researches on burial,temperature,maturity and oil generation histories of hydrocarbon source rocks of Taizhou Formation in the Gaoyou Sag,the North Jiangsu Basin with basin modeling methods have indicated that,hydrocarbon source rocks of Tai2 Member have entered mature stage and Ro has reached 0.6% during the early Sanduo period.As stratigraphic burial depth increases,stratum temperature,source rock maturity and hydrocarbon generation ability also increase gradually.In the end of Sanduo period,stratigraphic burial depth,temperature and hydrocarbon source rock maturity have reached the maximum,3 000 m,110℃,0.8%,respectively.At the same time,oil generation also reaches the maximum,and oil generation content of Well Jiao1 in the east reaches 350 mg/g.So,Sanduo period is the main stage during which Tai2 Member source rock generates and discharges hydrocarbon.In addition,tectonic and fault activities are strong during Sanduo period and most traps are formed.Therefore,Sanduo period is also the favorable and main period for oil-and-gas migration and accumulation.
COMPREHENSIVE EVALUATION OF HETEROGENEITY CONGLOMERATE RESERVOIRS——TAKING CONGLOMERATE RESERVOIRS IN QIZHONG AND QIDONG AREA OF KARAMAY OIL FIELD AS AN EXAMPLE
Song Ziqi, Yang Lilei, Cheng Ying, Wang Nan, Ding Jian
2007, 29(4): 415-419. doi: 10.11781/sysydz200704415
Abstract(1596) PDF-CN(662)
Abstract:
Conglomerate reservoirs in Qizhong and Qidong area of Karamay Oil Field are different from sandstone ones due to extra-high heterogeneity and complex mode pore structure.Influenced by piedmont pluvial phase,diagenetic compact and epigenetic diagenetic change,the reservoir is characterized by obviously different rock and mineral components,unequal grain sizes,great changes of facies horizontally and vertically as well as changes of permeability in or between layers.It is established in this paper comprehensive evaluation parameter,criterion and weighting coefficient by quantitative evaluation index system of stored energy parameter,reserves parameter,reserves distribution,scales,connectivity,drilling meeting ratio,permeability and heterogeneity.Comprehensive evaluation and classification description of heterogeneity conglomerate reservoirs are also made with gray system.Hence it is analyzed and illustrated from different aspects the quiescent quality of heterogeneity conglomerate reservoirs in this area.Conglomerate reservoirs with special microcosmic construction are studied macroscopically.Potential wells,layers and types for heterogeneity conglomerate reservoir development are pointed out,providing guild for oil field exploration.
SOURCE ROCK THERMAL AND MATURITY HISTORY MODELING IN THE BAIYUN SAG OF THE PEARL RIVER MOUTH BASIN
Guo Xiaowen, He Sheng
2007, 29(4): 420-425. doi: 10.11781/sysydz200704420
Abstract(1072) PDF-CN(303)
Abstract:
It is significant to study the source rock maturity history of the Baiyun Sag for the deep water exploration in the Baiyun Sag of the Pearl River Mouth Basin.Based on geohistory and thermal history of the Baiyun Sag,using EASY% Ro model reconstruction of the source rock maturity history in the western sag,the middle sag and the eastern sag of the Baiyun Sag.Comparing to the character of the Wenchang and Enping Formation source rocks maturity evolution in the western sag,the middle sag and the eastern sag.The studies indicate: 1)The studies of the Well B1 indicate that the character of the heat flow evolution is divided into two phase which is continuate rise in the forepart and gradually decline in the latter part in the Baiyun Sag.The heat flow reaches the maximum(76.7 mW/m2) at 44.4 Ma,the heat flow is about 60 mW/m2 at present.2)The Wenchang Formation source rock in the western sag,the middle sag and the eastern sag begins to generate hydrocarbon(Ro=0.5%)about at 43,44,35 Ma,reaches the hydrocarbon generation peak(Ro=1.0%) about at 30,35,17 Ma,reaches the high maturity(Ro=1.3%) about at 25,33,13 Ma.The Enping Formation source rock begins to generate hydrocarbon about at 20,30,22 Ma,reaches the hydrocarbon generation peak about at 10,22,8 Ma,reaches the high maturity about at 8,17,0 Ma.3)The thermal evolution of the Wenchang and Enping Formation source rocks in the middle sag of the Baiyun Sag is the highest,the time of the hydrocarbon generation is earliest and the main hydrocarbon generation phase is the shortest;the thermal evolution of the Wenchang and Enping Formation source rocks in the western sag is the lowest,the time of the hydrocarbon generation is latest and the main hydrocarbon generation phase is the longest.
SIMULATION EXPERIMENT OF BIOGENIC GAS FROM SOURCE ROCK AND BIODEGRADATION OF CRUDE OIL IN THE JIYANG DEPRESSION, THE BOHAI BAY BASIN
Luo Xia, Liu Hua, Wang Yulin, Li Wentao, Deng Yu
2007, 29(4): 426-431. doi: 10.11781/sysydz200704426
Abstract(669) PDF-CN(304)
Abstract:
Detection of the bacteria in the source rocks from different types of formation,lithology and depth in the Jiyang Depression was carried out in this paper.The result shows that the methane-forming bacteria exist in mudstone and sandstone in Es3,Es1 and Ed formations with depth being from 1 297 to 2 522 meters,indicating that the existence of methane-forming bacteria depends on the survival environment of the bacteria and is independent of rock's formation and lithology.The characteristics of the biogenic gases from source rocks and biodegradation of crude oil are similar in simulation experiment.The products of simulation experiment are mathane and carbon dioxide.Temperatures at the biogenic gas generating peak are 45℃ and 65℃.The yields of biogenic gases generated by a ton of TOC and a ton of crude oil are 20-160 m3 and 10-15 m3 respectively.Carbon isotope compositions of methane which range between -80.2‰ and -41.5‰ become lighter with simulation temperature going up,while carbon isotope compositions of carbon dioxide become heavier.Hydrogen isotope compositions of biogenic gas in simulation which mainly range between -300‰ and -350‰ are lighter than those in actual formation like the Luliang Basin in Yunnan Province which mainly range between -240‰ and -270‰.
CLASSIFICATION AND APPLICATION OF ORGANIC MACERALS IN THE LOWER PALEOZOIC HYDROCARBON SOURCE ROCK
Hu Mingxia, Cao Yin
2007, 29(4): 432-435. doi: 10.11781/sysydz200704432
Abstract(818) PDF-CN(316)
Abstract:
In this paper,the organic macerals from the Lower Paleozoic hydrocarbon source rock in the Tarim Basin were observed and studied by using the polished thick sections of whole-rock and kerogen as well as the polished thin sections of rock and kerogen.Characteristics of the organic macerals were described.These organic macerals were classified as three types according to the genesis and optical pro-perties of them.They are primary morphologic organics,non-morphologic organics and secondary organics.Based on the above,the weighting coefficient every organic maceral in the Lower Paleozoic hydrocarbon source rock was determined.Finally,this classification method was applied to the evaluation of the Middle-Upper Ordovician hydrocarbon source rock in the Well Kongquehe 1,the Tarim Basin.One of the six samples is determined as type I,two of them are type Ⅱ1 and the other two samples are type Ⅱ2.
RESEARCH ON BINARY GAS SORPTION ON COAL WITH DIFFERENT COAL RANKS
Zhang Qingling
2007, 29(4): 436-440. doi: 10.11781/sysydz200704436
Abstract(643) PDF-CN(310)
Abstract:
The sorption characteristics of the single-component gas(CH4,N2,CO2) and the binary gas with different proportion(80% CH4+20% CO2,50% CH4+50% CO2,20% CH4+80% CO2,80% CH4+20% N2,50% CH4+50% N2,20% CH4+80% N2) on long-flame coal,coking coal and anthracite were studied by means of isotherm adsorption experiment in laboratory.Based on gas content data and gas reservoir pressure data measured through coalbed gas test,some abnormal phenomena taking place in actual production,such as the gas saturation being at the extra-saturated state of 110%,were analyzed in details.The results indicate that in order to obtain the relatively accurate sorption parameters and adsorption isotherm curves,the mixed gas used in isotherm adsorption experiment in laboratory should be matched to the actual coalbed gases in different areas.

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