Petroleum geological characteristics of Kela-2 gas field

The Kela-2 gas field is located in the center ofKelasu structural belt in Kuqa Depression. This trap is oneof a series of traps in the folded belts which are distributed ina string of pearls in the dual structure. The primary gas-bearing layers are sandstone of Lower Cretaceous K₁bswhile the secondary layers are dolomite member and gluten-ite member of Lower Tertiary E_1-2km and sandstone ofLower Cretaceous K₁b. The main component of natural gasis methane whose content is higher than 97%. It is charac-terized by dry gas whose source rock is Jurassic coal meas-ure. The Kela-2 structural trap was formed during the Xiyuperiod and then became a reservoir in the late time. The res-ervoir formed late and the thick seal rock of Lower Tertiarygipsmantle are the avail reason why the giant Kela-2 gasfield has been well kept. The abnormal high pressure of theKela-2 gas field results from the strong structural compres-sion in the northern part during the Xiyu period.     

Deep overpressure gas accumulation

The Kela-2 gas field in the Kuqa Depression of the Tarim Basin is one of the greatest fields recently discov- ered in the deep overpressure reservoir in the world. The play conditions of Kela-2 field and Ya21-l structure features in the Qiongdongnan Basin on the South China Sea shelf has been studied, and a gas accumulation under deep overpres- sure must have the following two conditions (besides other favourable conditions for gas accumulation): one is that the time of gas charge matches with overpressure occurrence time, and the other is a good quality caprock. If the charge was early and the overpressure occurrence was late, and a fine caprock of the evaporite bed existed, the accumulation of gas is favourable; conversely, it is difficult to form a gas reservoir.     

Deep overpressure gas accumulation

The Kela-2 gas field in the Kuqa Depression of the Tarim Basin is one of the greatest fields recently discovered in the deep overpressure reservoir in the world. The play conditions of Kela-2 field and Ya21-1 structure features in the Qiongdongnan Basin on the South China Sea shelf has been studied, and a gas accumulation under deep overpressure must have the following two conditions (besides other favourable conditions for gas accumulation): one is that the time of gas charge matches with overpressure occurrence time, and the other is a good quality caprock. If the charge was early and the overpressure occurrence was late, and a fine caprock of the evaporite bed existed, the accumulation of gas is favourable; conversely, it is difficult to form a gas reservoir.

     

Geochemical characteristics and formation process of natural gas in Kela 2 gas field

 On the basis of a large amount of natural gascomponents and the carbon isotope as well as some otheranalysis data in Kela 2 gas field, the geochemical character-istics, source, origin, and formation process of natural gashave been discussed. The components of gas in the field tendto be "dry", and the drying coefficient is close to 1.0. Thecarbon isotope tends to be heavier, for instance, the averageof δ¹³C₁ is -27.36‰ and that ofδ¹³C₂ is -18.5‰. Compre-hensive analysis shows that humic natural gas in the Kuqapetroleum system comes mainly from Triassic and Jurassicsource rocks, and the contribution of Jurassic source rocks tothe pool maybe is more than that of Triassic rocks. The maincause that the gas tends to be dry and bears heavier isotopecomposition lies in the fact that Kela 2 natural gas is the ac-cumulation of late production of humic source rocks, and itis affected by the abnormal high pressure as well. Consider-ing the hydrocarbon generating and structural history, wecan regard the gas pool formation processes as twice fillingand twice adjusting (destroying), that is, the filling anddestroying process in the early Himalayan movement and thefilling and adjusting in the late Himalayan movement.     

四川元坝地区须二段致密砂岩储层孔隙演化与天然气成藏

利用储层中不同碎屑颗粒、填隙物的定量统计和孔隙在压实作用下的定量演化分析以及储层中包裹体均一温度,结合储层埋藏史分析等方法,探讨了四川盆地元坝地区上三叠统须二段致密砂岩储层孔隙演化与天然气成藏的关系。早成岩阶段结束时,储层的孔隙度已经降至8.7%,致密储层业已形成,此后一系列的胶结作用导致原生孔隙进一步减少,非均质性强。而元坝地区须二段天然气大规模充注时间为中成岩A期,此时储层已经致密,总体反映出"储层先致密,天然气后成藏"的特点,天然气在储层中以"活塞式推进"方式运移,气藏富集主要受源岩的生烃强度、优质储层等因素控制。基于此,认为烃源岩生气强度高的元坝东凹陷区,同样可以作为天然气勘探有利区。     

Two accumulation modes of marine-origin natural gas in the Tarim Basin

HeUanhe gas field, Lungudong gas field and Tazhong gas field are marine marine-origin natural gas reservoirs in the craton area in the Tarim Basin. The natural gas is generated from Cambrian source rocks. The simulation experiment indicated that the cracking of the dispersedly dissoluble organic matter remaining in the source rocks is the main origin of marine natural gas. There are two modes to form gas reservoirs, one is the dry gas reservoir such as HeUanhe gas field, in which gas accumulated on the fault belt with violent tectonic movement, the other is condensate gas reservoir formed on the inheriting uplift such as Lunnan and Tazhong gas fields. The hybrid simulation experiment of cracking gas and crude oil indicated that crude oil accumulated on a large scale in those uplift belts at the early stage, and natural gas filled the ancient oil reservoir at the late stage, and the gas reservoirs were formed after the gas mixed with the crude oil.     

吉林油田火山岩特低渗气藏应力敏感性及成因研究

以吉林油田长岭火山岩气藏基质岩心、裂缝充填岩心、裂缝-基质岩心为研究对象,进行了油藏条件下的应力敏感实验,以储层原始有效覆压下的渗透率为基准渗透率评价了该火山岩气藏的应力敏感程度,并与传统评价方法进行了对比.研究结果表明:火山岩裂缝-基质岩心具有中等偏强的应力敏感性,基质岩心和裂缝充填岩心应力敏感程度较弱.这与用传统方法评价的3类岩心均具有极强应力敏感性的结果偏差较大,火山岩中天然缝和人工缝的闭合是造成应力敏感性的主导因素.由于有效覆压变化引起的渗透率损失主要在低有效覆压范围内(<20 MPa),而这种情况在整个油气藏开发期内可能并不会存在,因此认为新评价方法更加具有应用价值.     

印尼宾都尼盆地侏罗系油气成藏特征及勘探潜力

宾都尼盆地是印尼东部重要的中生界含油气盆地之一,经历了克拉通内坳陷、裂谷期、被动陆缘和挤压反转期4期构造演化,形成现今弧后前陆盆地的构造格局。盆地的主要烃源岩和储盖组合多发育于中古生界,晚二叠世与早中侏罗世煤系地层是主力烃源岩,排烃高峰期始晚中新世,以生气为主。侏罗系三角洲-滨岸砂体为优质储层,原生粒间孔发育,平均孔隙度15%,平均渗透率18mD,属于中孔-中高渗透储层;盆地中北部前渊斜坡带发育一系列背斜、断背斜圈闭,且发现了大量气田群;天然气多以“下生上储”,即从前渊坳陷气源灶沿着砂体和断层运移至侏罗系砂岩圈闭聚集成藏。综合分析认为,储层质量和有效圈闭是侏罗系油气成藏的主控因素,东部逆冲褶皱带与海湾南部斜坡带是未来勘探的两个有利区带。     

四川中江气田沙溪庙组天然气成因类型及气源对比

探讨四川盆地中江气田侏罗系沙溪庙组天然气的成因和气源,为找气提供理论依据。利用天然气组分特征、碳同位素特征、轻烃特征等地球化学资料对该区天然气成因类型进行了分析,根据轻烃的气、源配对参数和碳同位素参数对天然气的来源进行了追踪。沙溪庙组天然气以烃类气体为主,含少量的非烃类气体,为腐植型干酪根裂解成因的煤型气;对碳同位素和轻烃的研究均表明,天然气为有机成因的煤型气。气源对比结果表明,须五段烃源岩为沙溪庙组煤型气的主要来源。中江气田侏罗系沙溪庙组气藏为次生气藏。     

徐深气田断裂发育及其对天然气成藏的控制作用

为准确判断松辽盆地徐深气田断裂的发育及其与深层天然气成藏之间的关系,根据钻井、测井和分析测试资料,利用断裂生长指数、断裂活动速率、剖面伸展率及构造演化剖面,厘定徐深气田断裂主要活动时期、断裂系统等,并建立该区的天然气成藏模式。结果表明:徐深气田断裂主要活动时期由古至今依次为火石岭组、沙河子组、营一段、营三段、泉头组末—姚家组沉积时期;气田内断裂可划分为早期伸展断裂系统(Ⅰ)、早期走滑伸展断裂系统(Ⅱ)、晚期伸展断裂系统(Ⅲ)、晚期张扭断裂系统(Ⅳ)、早期走滑伸展—晚期伸展断裂系统(Ⅴ)、早期走滑伸展—晚期张扭断裂系统(Ⅵ)、走滑断裂系统(Ⅶ)(徐中、徐东)。Ⅴ、Ⅵ、Ⅶ型断裂系统是构成气源断裂的主要断裂系统类型。工业气流井均分布在距源断裂3 km范围内的火山岩区域内。     

鄂尔多斯盆地中部气田奥陶系风化壳天然气成藏分析

根据地质和地球化学资料,并结合前人研究成果,研究了鄂尔多斯盆地古生界烃源岩生气中心及生气高峰,探讨了中部气田天然气的成藏期次、成藏过程和成藏模式.鄂尔多斯盆地中部气田位于烃源岩生气中心及其附近,可以获得充足的气源;天然气成藏主要有2期,即晚三叠世末和早白垩世末;成藏过程包括4个演化阶段:储集层孕育阶段(O1-C1)、圈闭形成阶段(C2-P)、天然气运聚成藏阶段(T3-K1)和气藏调整/定型阶段(K2-Q);奥陶系风化壳天然气成藏存在上古生界天然气穿层运移至奥陶系顶风化壳聚集和下古生界天然气自生自储型2种成藏模式.     

川西中段山前带雷口坡组气藏形成条件及过程

利用探井和地球物理资料,系统分析川西中段彭州气田钻探成果和中三叠统雷口坡组天然气成藏特征。川西中段深层有优质的下寒武统烃源岩,雷口坡组微生物型储集层沿山前带呈北西向展布,晚期发育的沟源断层形成的输导体系,早于断层形成的圈闭体系,具备形成大气田的基本条件。川西中段雷口坡组气藏为次生气藏,其天然气来源于下伏古气藏及烃源岩,深层的天然气通过断层向上运移聚集。川西中段雷口坡组的成藏特点为:(1)深层古油气藏发育;(2)微生物储层发育;(3)沟源断层晚期发育;(4)地震促使断层活化;(5)天然气跨层运移成藏。除雷口坡组外,深层应该还存在残余的古气藏,可能赋存的层位为二叠系和震旦系。     

渤深6潜山天然气成因及成藏条件

孤西断裂带深层天然气来源多,成因复杂,混源现象普遍.针对这一问题,运用天然气组分、稳定碳同位素、轻烃组成、稀有气体同位素和伴生原油生物标志物等多种指标,与邻区天然气进行对比,认为该区带中渤深6潜山下古生界天然气主要为高成熟油型气,混有部分伴生气;天然气与原油同源,主要源自渤南洼陷Es4上烃源岩,也存在Es3下烃源岩的贡献.成藏条件分析表明:气源条件充足,储盖组合良好,沟通油气源的断层和不整合面发育,生烃期晚,天然气保存有利,是该区油气富集的关键.     

鄂尔多斯盆地北部山西期-下石盒子期盆地演化与天然气富集规律

通过对鄂尔多斯地区晚古生代沉积盆地中天然气聚集与地质作用的研究认为,山西期-下石盒子期之所以成为鄂尔多斯上古生界主要产气层位,其地质因素与这一时期陆内盆地的扩张演化及其相应的沉积作用有关.这种关系表现在盆地处于下降时期,河流的垂向侵蚀作用大于侧向侵蚀,有充足的物源、有较大的可容空间,盆地的充填作用大于盆地扩张作用,易于形成良好的储层;而在超长周期层序的晚期,基准面旋回由上升向下降转化,也形成良好的储集砂体.     

川中地区须家河组致密砂岩气成藏机理

以四川盆地川中地区上三叠统须家河组致密砂岩气藏为例,探讨其成藏过程及成藏机理。通过对川中地区典型构造单井的生烃史模拟发现,不同构造须家河组烃源岩的生烃过程整体上具有相似性。经包裹体均一温度、自生矿物K-Ar法测定年龄和裂缝充填矿物ESR法测定年龄确定了川中地区须家河组油气成藏的3个期次,前2期分别为侏罗纪期间成熟和高成熟的烃类流体向储层中的充注,后一期为晚白垩世以来的构造隆升调整,对早期天然气藏改造并再次成藏的过程。川中地区须家河组致密砂岩天然气成藏具有三大特点:天然气近距离运移;天然气以游离相充注为主;隆升过程中天然气的泄压膨胀对天然气成藏具有重要贡献。     

From deep basin gas to diagenetic trap—An example from the Yulin Gas Field in the Ordos Basin

In the updip portion of the Yulin Gas Field in the Ordos Basin, there are no any structural, stratigraphic and sedimentary lithologic seals. Using thin-section petrography, ultraviolet fluorescence microscopy, micro-thermometry and Raman microspectrometry, this paper finds out the diagenetic trap and studies the diagenetic history of this field. It was revealed that three phases of diagenesis and hydrocarbon charging happened in late Triassic, late Jurassic and the end of early Cretaceous respectively. In the first two phases, acid geofluid entered the reservoir and caused dissolution and cementation. Although the porosities had been increased, further compaction accompanying re-subsidence resulted in tight sandstone and conglomerates. Till the end of the early Cretaceous, bulk of gas migrated into the tight reservoir. Cementation, however, kept on in the updip portion of this field due to low gas saturation and formed the diagenetic trap. The mechanism for gas accumulation was changed from deep basin gas to diagenetic trap, which offers a sealing condition that can retain gas for much longer time.     

Control factors and porosity evolution of high-quality sandstone reservoirs of Kela-2 gas field in Kuqa Depression

By using the integrated methods includingsandbodies modelling of the outcrops, sedimentary facies ofthe cores and well logs of the drilled wells, and the reservoircorrelation of interwells, it is thought that the sandstone res-ervoirs of Kela-2 gas field are a suit of high-quality naturalgas reservoirs with great thickness, extensive and continuousdistribution, high porosity and permeability, and a few bar-rier beds. Sedimentary facies and microfacies are the mainfactors controlling the reservoir distribution and interiorheterogeneity. Based on a great deal of data of rock's thinsections, porosity, permeability, and the parameters of capil-lary pressure, the reservoir diagenesis, controls, mechanismand evolution of pores have been studied. It is consideredthat compaction in the early stage and diagenetic dolomiteand calcite cements have effect on the decline of reservoirsproperty. Now compaction is chiefly middle to weak. Thebetter reservoirs have no or a few calcite cements. In theearly of deep buried stage, there are still mainly remainderprimary intergranular pores. The authigenic kaolinite ofreservoirs is the production of the dissolution of feldsparsand lithic fragments. The dissolution results in the partlymodified and broadened secondary intergranular pores. Inthe late of deep buried stage, structure fissures and over-pressure were in favor of improving and preservation ofthese pores.     

杭锦旗探区储层致密化与天然气成藏的关系

杭锦旗地区储层主要为低孔低渗的致密砂岩储层.通过对储层特征的描述及致密化原因的分析认为,硅质胶结物、钙质胶结物和黏土矿物的生成是影响储层致密化的主要因素,最后一期胶结物——方解石是导致储层最终致密化的主要原因.根据方解石形成时的包裹体测温和氧同位素计算出的温度判断,早白垩世晚期是储层最终致密化的时间.结合生烃模拟研究及成藏期次的分析认为,研究区天然气藏分为2种类型,即常规圈闭气藏和根缘气藏,分别在中侏罗世晚期之前和早白垩世晚期之后成藏,主体上分别分布在以三眼井—泊尔江海子断裂为界的北部地区和南部地区.     

济阳坳陷太平油田网毯式油气成藏体系研究

济阳坳陷太平油田主要含油层段为新近系馆陶组下段,具有典型的网毯式成藏特点.作者运用网毯式油气成藏体系的研究方法,分析了太平油田馆下段成藏条件.馆陶组下段块状砂岩层厚度大、分布广、物性和连通性好,即所称的"毯".长期活动的义东断层连通了古近系烃源岩和"毯",是油气运移的网.由此建立了太平油田新近系地层超覆油藏模式,古地貌形态和砂岩分布特征控制了地层超覆油藏和小型披覆背斜油藏的分布.     

致密砂岩产水气井气举排液模型研究

苏里格气田是典型的致密砂岩气藏,其有效储层含水饱和度高,气、水层混杂分布,开发中后期一般因井筒积液阻碍天然气有效开发,往往需要排液才能保持一定的产量,目前气举是排液较为有效的方法,然而如何提高排液效率及优化气井排液制度已成为制约气举排液效果的难题。以高产水生产气井为研究对象,根据油套管质量、动量和能量方程,建立了气举井筒排液模型,运用显示欧拉差分方法对其进行求解。基于所建立的气井井筒排液模型,研究了不同注气量、井口油压等参数对气井排液效率的影响程度,并分析了S井气举排液过程中产液量、产气量以及排液时间等工作指标变化特征。研究成果为致密砂岩产水气井提高排液效率,以及气举排液生产制度优化提供了一定的指导。