Multiple overpressure systems and their relationship with hydrocarbon accumulation in the Qikou Depression of the Bohai Bay Basin,China

Pressure measurements using drill stem tests and estimates from log data calculation indicate that three vertically stacked regional pressure compartments exist in the Qikou Depression of Bohai Bay Basin, N. China. The compartments comprise hydrostatic, upper weak, and lower overpressure systems. Laterally, overpressure (pressure coefficient > 1.2) occurs in the deeper areas and weakens gradually from the centre to the margin of the depression. The accumulation of oil and gas exhibits the interesting characteristics of oil‐bearing layers above gas‐bearing layers in the Qikou Depression. The pattern can be accounted for by the evolution of overpressure system, the maturity process of the source rock and the main fault activity. In the late Dongying Formation (Ed, 30 Ma), the lower overpressure system began to form shape, and the hydrocarbon sources generated a large volume of oil. However, because there was no migration pathway, the oil only accumulated in the original strata. In the late Guantao Formation (Ng, 12 Ma), the gas was generated, the upper overpressure system formed gradually, and the activity of the main fault gradually increased. Then, the overpressure pushed the early gathered oil to flow from the lower overpressure system into the upper overpressure system. Afterwards, the activity of the main fault decreased again and remains weak until now. Thus, later generated natural gas cannot keep migrating along the main fault and can only accumulate in the lower overpressure system. Copyright © 2014 John Wiley & Sons, Ltd.     

南美Oriente盆地北部海绿石砂岩油藏特征及成藏规律

南美厄瓜多尔Oriente盆地斜坡带发育的白垩系Napo组高伽马特征的UT海绿石砂岩段是成熟探区新发现的隐蔽含油层段。本文分析了海绿石砂岩储层的矿物组成、孔隙结构、成岩作用、物性特点,并结合烃源岩评价与石油空间分布探讨海绿石砂岩油藏的成藏特征。海绿石粘土矿物以颗粒形式存在,与石英共同构成海绿石砂岩的颗粒组分,海绿石砂岩的孔隙结构具有双峰特征,束缚水含量高,属于中-低孔、中-低渗储层类型,孔隙类型主要是剩余粒间孔。海绿石砂岩储层中石英次生加大属Ⅱ级,长石碎屑颗粒发生溶蚀作用,含铁碳酸盐类胶结物发育,结合泥岩低的I/S混层比和高的最高峰温值T_max,指示海绿石砂岩层段属于中成岩阶段A期的产物。与海绿石砂岩油藏紧邻的大面积分布的Ⅱ₁腐泥型成熟烃源岩就是缓翼斜坡带的生烃中心,大面积连续发育的海绿石砂岩与之构成优越的源储组合,有利于上生下储式成藏。海绿石砂岩油藏表现为近源性、成藏晚期性等特点,规模发育的海绿石砂岩储层得以成藏的主要运聚机制是体积流和扩散流运聚机制。这对盆地其它油区同类油藏的发现具有重要的借鉴意义。     

辽东湾坳陷东部地区走滑双重构造的发育特征 及其石油地质意义

在将构造发育特征与走滑双重构造理论模型进行类比分析的基础上,对辽东湾坳陷东部地区的走滑双重构造的发育特征进行了研究,并结合油气勘探实践成果,就其石油地质意义进行了探讨,研究结果表明:在受控于走滑与拉伸并存的多动力源区域地质背景下,辽东湾坳陷新生代构造演化体现了断陷与拗陷、拉张与走滑的叠加效应,NNE走向的辽中1号断裂、辽中2号断裂及辽东断裂的发育不仅控制了辽东湾坳陷东部地区的凸凹格局,其走滑侧接关系也导致了研究区走滑双重构造的发育;辽东凸起是由于辽中2号断裂、辽东断裂走滑弯曲、右行左阶侧接而形成的挤压走滑双重构造,而辽中凹陷在早期拉张断陷基础上,经历了后期走滑作用的改造,其断裂体系的发育体现了辽中1号断裂与辽中2号断裂的右旋右行侧列所产生的拉张走滑双重构造效应;在走滑双重构造的增压带,断裂侧向封堵性强,有利于形成有效的断层圈闭,是油气藏发育的有利区带。     

早白垩世泥炭地净初级生产力及其控制因素--来自二连盆地吉尔嘎郎图凹陷6号煤的证据

现代泥炭地中蕴藏着巨量的碳,泥炭地生产力的高低会影响全球碳循环及全球气候变化。前人对全新世以来泥炭地生产力做了大量研究,但对前第四纪的“深时”阶段的泥炭地生产力则极少涉及,其主要原因是缺少精确的定年方法。以二连盆地吉尔嘎郎图凹陷早白垩世6号煤为例,利用地球物理测井信号进行频谱分析并获得煤层中米兰科维奇旋回周期参数（123 ka（偏心率）:38.1 ka（斜率）:22.1 ka（岁差））,将米兰科维奇旋回作为“深时”地层时间的“度量”工具,计算出6号煤层碳的聚集速率为35.1~38.9 g C/（m2·a）,进一步推算出其所代表的泥炭地的碳聚集速率为46.2~51.2 g C/（m2·a）,净初级生产力（NPP）为231~256 g C/（m2·a）。将该计算结果与全新世同一纬度带泥炭地生产力水平比较,并结合前人研究成果综合分析影响因素,得出早白垩世泥炭地生产力水平主要受温度和大气中二氧化碳含量控制,而这两种因素又与气候相关联,则泥炭地生产力的研究可能对进一步了解古气候提供帮助。     

海拉尔盆地呼和湖凹陷致密砂岩气成藏特征

海拉尔盆地呼和湖凹陷具备形成大面积致密砂岩气藏的地质条件,其断陷期地形比较宽缓,后期改造弱,主要发育低幅度的断背斜或宽缓的向斜,在局部具备稳定的构造条件。南二段煤系源岩广泛发育,丰度均达到中等--好烃源岩级别,为致密砂岩气藏的形成提供了充足的物质基础。洼槽区南二段储层属低孔--特低渗型储集层。南二段致密储层与煤、泥岩呈频繁互层状分布,形成致密砂岩气有利的的生储盖组合。构造高部位在一定程度上控制油气丰度,稳定的负向构造区有利于寻找储层富集区。呼和湖凹陷致密砂岩气主要表现为两种成藏组合,自生自储型和内生外储型,油气呈南北向条带状分布。     

滨里海盆地Z油田油藏类型与成藏因素研究

Z油田主要含油层系包括白垩系-中侏罗统低幅度背斜构造油藏、中三叠统盐檐断鼻油藏和上三叠统岩性圈闭油藏3种油藏类型。通过对紧密围绕盐有关的构造和有效盐窗这两个影响Z油田油气成藏的关键因素的研究认为成藏模式为"盐下生成、盐窗沟通、盐边盐间断层输导、高点聚集、后期保存"。Z油田油源充足,盐窗大而有效,多种有效的输导体系,圈闭类型多而好,埋深适中,储盖层发育且配置良好,侧向遮挡条件具备且后期保存条件良好,可作为今后勘探首选目标区。     

温度、饵料种类对中华哲水蚤(Calanus sinicus)油脂积累与生长发育的影响

中华哲水蚤(Calanus sinicus)C5期幼体的油脂积累是种群在黄海冷水团中得以顺利度夏的关键过程。本研究对温度(10°C和19°C恒温,10—19°CⅠ和10—19°CⅡ变温)与饵料种类(硅藻饵料,自然饵料)双因子培养实验进行研究,探讨温度和饵料种类对中华哲水蚤油脂积累与生长发育的影响作用。结果表明,不同的温度和饵料种类对C5期幼体的油脂积累均有影响。C5期幼体在变温组的油脂积累是10°C组的31%—102%,是19°C组的1.8—6.1倍,低温有利于C5期幼体降低个体代谢消耗以增加油脂的积累。在恒温培养下,C5期幼体在硅藻饵料组的油脂积累是自然饵料组的2.8倍,硅藻饵料比自然饵料更有利于油脂的积累。雌体的体长和油囊体积均随着温度的升高而减小。与硅藻饵料相比,在自然饵料组中雌体的性腺发育速度更快,性腺成熟度更高(繁殖指数:58%—65%)。     

Controls on reservoir heterogeneity of tight sand oil reservoirs in Upper Triassic Yanchang Formation in Longdong Area,southwest Ordos Basin,China: Implications for reservoir quality prediction and oil accumulation

Compared to conventional reservoirs, pore structure and diagenetic alterations of unconventional tight sand oil reservoirs are highly heterogeneous. The Upper Triassic Yanchang Formation is a major tight-oil-bearing formation in the Ordos Basin, providing an opportunity to study the factors that control reservoir heterogeneity and the heterogeneity of oil accumulation in tight oil sandstones.The Chang 8 tight oil sandstone in the study area is comprised of fine-to medium-grained, moderately to well-sorted lithic arkose and feldspathic litharenite. The reservoir quality is extremely heterogeneous due to large heterogeneities in the depositional facies, pore structures and diagenetic alterations. Small throat size is believed to be responsible for the ultra-low permeability in tight oil reservoirs. Most reservoirs with good reservoir quality, larger pore-throat size, lower pore-throat radius ratio and well pore connectivity were deposited in high-energy environments, such as distributary channels and mouth bars. For a given depositional facies, reservoir quality varies with the bedding structures. Massive- or parallel-bedded sandstones are more favorable for the development of porosity and permeability sweet zones for oil charging and accumulation than cross-bedded sandstones.Authigenic chlorite rim cementation and dissolution of unstable detrital grains are two major diagenetic processes that preserve porosity and permeability sweet zones in oil-bearing intervals. Nevertheless, chlorite rims cannot effectively preserve porosity-permeability when the chlorite content is greater than a threshold value of 7%, and compaction played a minor role in porosity destruction in the situation. Intensive cementation of pore-lining chlorites significantly reduces reservoir permeability by obstructing the pore-throats and reducing their connectivity. Stratigraphically, sandstones within 1 m from adjacent sandstone-mudstone contacts are usually tightly cemented (carbonate cement > 10%) with low porosity and permeability (lower than 10% and 0.1 mD, respectively). The carbonate cement most likely originates from external sources, probably derived from the surrounding mudstone. Most late carbonate cements filled the previously dissolved intra-feldspar pores and the residual intergranular pores, and finally formed the tight reservoirs.The petrophysical properties significantly control the fluid flow capability and the oil charging/accumulation capability of the Chang 8 tight sandstones. Oil layers usually have oil saturation greater than 40%. A pore-throat radius of less than 0.4 μm is not effective for producible oil to flow, and the cut off of porosity and permeability for the net pay are 7% and 0.1 mD, respectively.     

东非鲁伍马盆地深水区构造-沉积演化过程及油气地质特征

利用深水区的二维、三维地震资料开展构造-沉积演化研究,鲁伍马盆地二叠纪—早侏罗世为冈瓦纳陆内—陆间裂谷活动期,发育河流—湖泊沉积;中侏罗世—早白垩世为马达加斯加漂移期,位于剪切型大陆边缘,发育海陆过渡相沉积;晚白垩世—渐新世为被动大陆边缘期,深水沉积广泛发育,重力流沉积延伸至戴维隆起带;中新世—第四纪为东非裂谷海域分支活动期,陆坡和凯瑞巴斯地堑发育深水重力流沉积。盆地垂向上形成"断—坳—断"结构,二叠纪—早侏罗世及中新世—现今发育两期明显的裂谷活动。马达加斯加漂移期的海相泥岩为深水区的主力烃源岩,古近纪的陆坡深水浊积砂体为主要储层。东非裂谷海域分支的断层活动沟通了下伏烃源岩,晚期断层不发育的西部陆坡成为主要的油气聚集区。     

孟加拉湾若开海域晚新生代构造变形及其对油气的控制作用

利用钻井、二维和三维地震资料,剖析了孟加拉湾若开海域晚新生代的构造变形特征,探讨了构造变形对油气的控制作用。区域深度地质剖面揭示,研究区南部仅发育底部滑脱层(深度10 km),而北部则发育底部滑脱层(深度12 km)和中部滑脱层(深度4 km);受滑脱层的控制,研究区南部仅发育一套构造层,而北部则发育变形不协调的上、下两套构造层;南部背斜的南北向延伸距离、波长及背斜间隔距离均明显大于北部。通过北部局部构造精细解析表明,研究区北部变形相对较复杂,上构造层主要发育近南北向的背斜和次级张扭性右旋走滑断层,二者形成时间分别为晚第四纪和晚第四纪末。若开海域晚新生代的构造变形对圈闭形成、油气运聚和保存条件具有重要的控制作用。指出研究区南部平缓褶皱带构造—岩性复合圈闭具备形成大油气田的条件,是下一步油气勘探的重要目标。