In-situ stress state in the Linxing region,eastern Ordos Basin,China: Implications for unconventional gas exploration and production

The Carboniferous and Permian sedimentary rocks (mainly the Shanxi and Taiyuan formations) in the Linxing region, eastern Ordos Basin, China, host a significant volume of unconventional gas resources (coalbed methane, shale gas and tight sandstone gas). Currently, the in-situ stress state is poorly understood but knowledge of this is extremely important for a range of applications, such as gas exploration and production, fracture stimulation and wellbore stability. The maximum horizontal stress (S_Hmax), minimum horizontal stress (S_hmin) and vertical stress (S_v) magnitudes, and the S_Hmax orientation in the Linxing region were systematically analyzed for the first time in the present study, which can provide a reference for subsequent numerical simulation and hydraulic fracturing design. Based on borehole breakouts and drilling-induced tensile fractures interpreted from borehole imaging logs, the S_Hmax orientation rotates from ∼NEE-SWW-trending in the southern part to ∼ NWW-SEE-trending in the northern part of the Linxing region. Both conventional logs and extended leak-off tests were used for stress magnitude determination. The results revealed three types of in-situ stress fields (S_v > S_Hmax > S_hmin, S_Hmax > S_v > S_hmin and S_Hmax > S_v ≈ S_hmin), and a dominant strike-slip stress regime (S_Hmax > S_v ≥ S_hmin) was found for the entire well section in the target Shanxi Formation and Taiyuan Formation in the Linxing region. In addition, differential stress increased with depth in the Linxing region, which indicates that wellbore instability might be a potentially significant problem when drilling wells that are vertical or ∼ N-S-trending.     

Influence of detrital composition on the diagenetic history of tight sandstones with implications for reservoir quality: Examples from the Permian Xiashihezi Formation and Carboniferous Taiyuan Formation,Daniudi gas field,Ordos Basin,China

Tight-gas reservoirs, characterized by low porosity and low permeability, are widely considered to be the product of post-depositional, diagenetic processes associated with progressive burial. This study utilizes a combination of thin section petrography, scanning electron microscopy, microprobe and back scatter electron analysis, stable isotope geochemistry and fluid inclusion analysis to compare the diagenetic history, including porosity formation, within sandstones of the second member of Carboniferous Taiyuan Formation (C₃t₂) and the first member of Permian Xiashihezi Formation (P₁x₁) in the Ordos Basin in central China.In the P₁x₁ member, relatively high abundances of metamorphic rock fragments coupled with a braided river and lacustrine delta environment of deposition, produced more smectite for transformation to illite (50–120 °C). This reaction was driven by dissolution of unstable minerals (K-feldspar and rock fragments) during the early to middle stages of mesodiagenesis and consumed all K-feldspar. Abundant intragranular porosity (average values of 2.8%) and microporosity in kaolinite (average values of 1.5%) formed at these burial depths with chlorite and calcite developed as by-products.In the C₃t₂ member, relatively low abundances of metamorphic rock fragments coupled with an incised valley-coastal plain environment of deposition resulted in less smectite for transformation to illite. High K⁺/H⁺ ratios in the early pore waters related to a marine sedimentary environment of deposition promoted this reaction. Under these conditions, K-feldspar was partially preserved. During the middle to late stages of mesodiagenesis, K-feldspar breakdown produced secondary intragranular (average values of 1.4%) and intergranular pores (average values of 1.2%). Release of K⁺ ions promoted illitization of kaolinite with quartz overgrowths and ferrous carbonates developed as by-products.This study has demonstrated that whereas both members are typical tight-gas sandstones, they are characterized by quite different diagenetic histories controlled by the primary detrital composition, especially during mesodiagenesis. Types of secondary porosity vary between the two members and developed at different stages of progressive burial. The content of unstable detrital components, notably feldspar, was the key factor that determined the abundance of secondary porosity.     

Geochemical characteristics of tight gas and gas-source correlation in the Daniudi gas field,the Ordos Basin,China

The molecular composition, stable carbon and hydrogen isotopes and light hydrocarbons of the Upper Paleozoic tight gas in the Daniudi gas field in the Ordos Basin were investigated to study the geochemical characteristics. Tight gas in the Daniudi gas field displays a dryness coefficient (C₁/C_1–5) of 0.845–0.977 with generally positive carbon and hydrogen isotopic series, and the C₇ and C_5–7 light hydrocarbons of tight gas are dominated by methylcyclohexane and iso-alkanes, respectively. The identification of gas origin and gas-source correlation indicate that tight gas is coal-type gas, and the gases reservoired in the Lower Permian Shanxi Fm. (P₁s) and Lower Shihezi Fm. (P₁x) had a good affinity and were derived from the P₁s coal-measure source rocks, whereas the gas reservoired in the Upper Carboniferous Taiyuan Fm. (C₃t) was derived from the C₃t coal-measure source rocks. The molecular and methane carbon isotopic fractionations of natural gas support that the P₁x gas was derived from the P₁s source rocks. The differences of geochemical characteristics of the C₃t gas from different areas in the field suggest the effect of maturity difference of the source rocks rather than the diffusive migration, and the large-scale lateral migration of the C₃t gas seems unlikely. Comparative study indicates that the differences of the geochemical characteristics of the P₁s gases from the Yulin and Daniudi gas fields originated likely from the maturity difference of the in-situ source rocks, rather than the effect of large-scale lateral migration of the P₁s gases.     

东海平湖油气田中高渗凝析气藏开发效果分析

东海平湖油气田放鹤亭始新统平湖组气藏,属中高渗砂岩中低凝析油含量凝析气藏,1999年3月投入生产,采用衰竭式开采,至今已有8个年头,目前仍处于开发稳产阶段,日生产天然气量在140×10^4m^3左右。通过对平湖油气田凝析气藏开发生产状况跟踪研究发现,其采气速度高、主力气藏气井无水采气期普遍较长、气油比随着压力下降而上升、凝析油含量随着压力下降而下降、天然气采收率将优于开发方案设计值,同时也发现,防止气井出水、出砂是中高渗凝析气藏开发中应予以高度重视的问题。平湖油气田凝析气藏开发,在技术上和经济上都取得了较好的效果,可以借鉴于类似凝析气田的开发实践中。     

Impact of diagenesis on reservoir quality and heterogeneity of the Upper Triassic Chang 8 tight oil sandstones in the Zhenjing area,Ordos Basin,China

Reservoir quality and heterogeneity are critical risk factors in tight oil exploration. The integrated, analysis of the petrographic characteristics and the types and distribution of diagenetic alterations in the Chang 8 sandstones from the Zhenjing area using core, log, thin-section, SEM, petrophysical and stable isotopic data provides insight into the factors responsible for variations in porosity and permeability in tight sandstones. The results indicate that the Chang 8 sandstones mainly from subaqueous distributary channel facies are mostly moderately well to well sorted fine-grained feldspathic litharenites and lithic arkose. The sandstones have ultra-low permeabilities that are commonly less than 1 mD, a wide range of porosities from 0.3 to 18.1%, and two distinct porosity-permeability trends with a boundary of approximately 10% porosity. These petrophysical features are closely related to the types and distribution of the diagenetic alterations. Compaction is a regional porosity-reducing process that was responsible for a loss of more than half of the original porosity in nearly all of the samples. The wide range of porosity is attributed to variations in calcite cementation and chlorite coatings. The relatively high-porosity reservoirs formed due to preservation of the primary intergranular pores by chlorite coatings rather than burial dissolution; however, the chlorites also obstruct pore throats, which lead to the development of reservoirs with high porosity but low permeability. In contrast, calcite cementation is the dominant factor in the formation of low-porosity, ultra-low-permeability reservoirs by filling both the primary pores and the pore throats in the sandstones. The eogenetic calcites are commonly concentrated in tightly cemented concretions or layers adjacent to sandstone-mudstone contacts, while the mesogenetic calcites were deposited in all of the intervals and led to further heterogeneity. This study can be used as an analogue to understand the variations in the pathways of diagenetic evolution and their impacts on the reservoir quality and heterogeneity of sandstones and is useful for predicting the distribution of potential high-quality reservoirs in similar geological settings.     

鄂尔多斯盆地陕北地区延长组长7段致密油储层特征及其主控因素

鄂尔多斯盆地延长组石油资源丰富,储层致密,为了查明湖盆致密砂岩储层发育机理,综合利用岩心观察、铸体薄片鉴定、X射线衍射分析、扫描电镜观察、高压压汞测试等方法,对鄂尔多斯盆地陕北地区长7段致密油储层特征及其发育主控因素进行了分析。研究结果显示,研究区长7段长石含量高,主要发育长石砂岩和岩屑长石砂岩。致密砂岩储层孔隙类型以长石粒内溶蚀孔隙和粒间溶蚀孔隙为主,同时晶间微孔和微裂缝较为发育。研究区长7段时期主要为三角洲前缘与滨浅湖沉积环境,水动力较弱,发育砂岩中泥质含量较高。中等强度压实作用及早期的方解石胶结作用使原生孔隙消失殆尽,胶结作用进一步使孔隙减小。由于长石及黏土含量较高,其受溶蚀作用形成溶蚀孔隙,改善储层质量,同时也是研究区长7段致密砂岩储层发育的主要控制因素。     

Fractures in the low porosity and ultra-low permeability glutenite reservoirs: A case study of the late Eocene Hetaoyuan formation in the Anpeng Oilfield,Nanxiang Basin,China

The Naxiang Basin, located within the Qin-and-Dabie Mountains orogenic belt in central China, is a small intermountain faulted basin, in which the late Eocene Hetaoyuan Formation in the Anpeng Oilfield is the low porosity and ultra-low permeability glutenite reservoirs. The large-scale fractures are mainly developed in the thick-bedded conglomerates and gravel-bearing gritstones, the small-scale jointed-fractures bounded by layer are mainly developed in the medium-granular and fine sandstones between the conglomerates or gravel-bearing gritstones. There also developed three kinds of micro-fractures, namely intergranular fractures, intragranular fractures and transgranular fractures, in the tight glutenites. The fractures in the glutenite reservoirs are of chiefly high dip-angles. They assume chiefly the E-W strikes, next are the NE-SW and NW-SE strikes. On the log curve, fractures usually show such responses as a decrease of the deep and shallow lateral resistivities, an increase of the acoustic time difference, a reduction of the density, an increase of the compensation neutrons, an occurrence of middle and high gamma ray and an expansion of the calipers. Fractures make contributions to the low porosity and ultra-low permeability glutenite reservoirs by improving the permeability and then porosity. Micro-fractures are the important channels connecting intergranular and intragranular solution pores, thereby making better the connectivity within the tight glutenite reservoirs. The small- and medium-scale fractures serve as the flow channels within the layers of fine and medium-granular sandstones, while the large-scale fractures serve as the main flow channels for the whole reservoir. Under the impact of the present-day stress, the NE-SW fractures perpendicular to the minimum principal stress assume a tensile state and have good connectivity, large apertures and high permeability, and are the major direction for fluid flow, thereby providing a major basis for a further development.     

Shale gas accumulation potential of the Upper Cretaceous Qingshankou Formation in the southeast Songliao Basin,NE China

The purpose of this paper is to provide both quantitative and qualitative visual analyses of the nanometer-scale pore systems of immature and early shales, as well as to discuss the biogenic shale gas accumulation potential of the Upper Cretaceous section of the Songliao Basin. To achieve these goals, mineralogical compositions were determined using transmitted and reflected light petrography, X-ray diffractometry and scanning electron microscopy (SEM), while the nanostructure morphology and pore size distributions (PSDs) were quantified using field emission scanning electron microscopy (FE-SEM) and low-pressure nitrogen gas adsorption (LP-N₂GA). The results of these analyses indicate that nanometer-scale pores are well developed in the immature and low-maturity shale, and that these shales contain many types of reservoir pores. The mudstone layer of the Qingshankou Formation (K₂qn) contains a high permeability characteristic and good rock fracturing conditions, while it is also thick (>9 m in thickness) and rich in fine organic matter. Overall, analysis of the entire formation using source rock and reservoir evaluations indicate that the first member of the Qingshankou Formation (K₂qn₁) has a greater shale gas accumulation potential than the second and third members of the Qingshankou Formation (K₂qn_2-3).     

Quantitative impact of diagenesis on reservoir quality of the Triassic Chang 6 tight oil sandstones,Zhenjing area,Ordos Basin,China

The Upper Triassic Chang 6 sandstone, an important exploration target in the Ordos Basin, is a typical tight oil reservoir. Reservoir quality is a critical factor for tight oil exploration. Based on thin sections, scanning electron microscopy (SEM), X-ray diffraction (XRD), stable isotopes, and fluid inclusions, the diagenetic processes and their impact on the reservoir quality of the Chang 6 sandstones in the Zhenjing area were quantitatively analysed. The initial porosity of the Chang 6 sandstones is 39.2%, as calculated from point counting and grain size analysis. Mechanical and chemical compaction are the dominant processes for the destruction of pore spaces, leading to a porosity reduction of 14.2%–20.2% during progressive burial. The porosity continually decreased from 4.3% to 12.4% due to carbonate cementation, quartz overgrowth and clay mineral precipitation. Diagenetic processes were influenced by grain size, sorting and mineral compositions. Evaluation of petrographic observations indicates that different extents of compaction and calcite cementation are responsible for the formation of high-porosity and low-porosity reservoirs. Secondary porosity formed due to the burial dissolution of feldspar, rock fragments and laumontite in the Chang 6 sandstones. However, in a relatively closed geochemical system, products of dissolution cannot be transported away over a long distance. As a result, they precipitated in nearby pores and pore throats. In addition, quantitative calculations showed that the dissolution and associated precipitation of products of dissolution were nearly balanced. Consequently, the total porosity of the Chang 6 sandstones increased slightly due to burial dissolution, but the permeability decreased significantly because of the occlusion of pore throats by the dissolution-associated precipitation of authigenic minerals. Therefore, the limited increase in net-porosity from dissolution, combined with intense compaction and cementation, account for the low permeability and strong heterogeneity in the Chang 6 sandstones in the Zhenjing area.     

A区块断层成因机制及其对致密气成藏的影响

受L断裂带左旋走滑应力及Z火成岩体多期活动的综合影响,A区块断裂系统复杂。基于应力叠加程度的不同,研究区发育火山作用型和区域应力型2类断层。火山作用型断层主要伴随Z岩浆侵入热事件形成,对气藏起调整过度的作用,破坏天然气成藏;区域应力型断层主要由L断裂带左旋应力场派生出的3类断层组成,分别为NW向张性走滑断层、NE和近SN向压性走滑断层及X型共轭剪切破裂断层,通过对钻井距断层横向距离、砂岩厚度及气层厚度之间关系分析,认为该类断层对横向范围2 km之内起适度调整的作用,而远离断层控制范围,对气藏调整的作用不足。可见断层输导能力对致密气的纵向分布以及断层对储层物性的改造对致密气藏的横向展布均起到了重要的控制作用,打破了一直以来沉积作用控制致密气成藏的局限认识,因此明确断层的成因机制及控藏作用对鄂尔多斯盆地东北缘上古生界致密气的勘探开发具有关键现实意义。     

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.     

Effect of sedimentary heterogeneities on hydrocarbon accumulations in the Permian Shanxi Formation,Ordos Basin,China: Insight from an integrated stratigraphic forward and petroleum system modelling

Sedimentary heterogeneities are ubiquitous in nature and occur over a range of scales from core, reservoir to basin scales. They may thus exert significant influences on hydrocarbon generation, migration and accumulation. The sedimentary heterogeneities of the Permian Shanxi Formation in the Ordos Basin, China were modelled using Sedsim, a stratigraphic forward modelling program. The simulation results were then used to construct a 3D petroleum system model using PetroMod. The effects of sedimentary heterogeneities on hydrocarbon accumulations were evaluated by comparing the integrated Sedsim-PetroMod model with the classic 3D basin model. The Sedsim simulation shows that considerable sedimentary heterogeneities are present within the Shanxi Formation, as a result of the interplay of the initial topography, tectonic subsidence, base level change and sediment inputs. A variety of lithologies were developed both laterally and vertically within the Shanxi Formation at kilometre and metre scales, respectively, with mudstones mainly developed in the depositional centre, while sandstones developed in the southern and northern margin areas. A typical source-ward retrogradation is well developed within the Lower Shanxi Formation.A base-case classic 3D basin model was constructed to quantify the Permian petroleum system in the Ordos Basin. The geological and thermal models were calibrated using Vr and borehole temperature data. The source rocks of the Upper Paleozoic became mature (R_o > 0.5%) and high mature (R_o > 1.2%) in the late Triassic and late Jurassic, respectively, in the central and southern areas. During the Early Cretaceous, a tectonically induced geothermal event occurred in the southern Ordos Basin. This caused the source rocks to reach over maturity (R_o > 2.0%) quite rapidly in the early Late Cretaceous in the central and southern areas. All the source rock transformation ratios (TR) at present are greater than 70% in the P₁ coal and P₁ mudstone layers with TR values approaching 100% in the central and southern areas. The transformation ratios of the P₁ limestone are close to 100% over the entire interval.In the base-case model, a large amount of hydrocarbons appear to have been expelled and migrated into the Shanxi Formation, but only a minor amount was accumulated to form reservoirs. In the model, the Shanxi Formation sandstone layer was set to be homogeneous vertically and there was no regional seal rocks present at the top of the Shanxi Formation. Therefore hydrocarbons could not be trapped effectively with only minor accumulations in some local structural highs where hydrocarbons are trapped both at the top and in the up-dip direction by the adjacent mudstone facies. In contrast, the integrated Sedsim-PetroMod model takes into account of the internal lithological and sedimentary facies heterogeneities within the Shanxi Formation, forming complex contiguous sandstone-mudstone stacking patterns. Hydrocarbons were found to have accumulated in multiple intervals of lithological traps within the Shanxi Formation. The results indicate that lithological distinctions, controlled by sedimentary heterogeneities in three dimensions can provide effective sealing in both the top and up-dip directions for hydrocarbon accumulations, with gas being mainly accumulated near the depocentre where lithological traps usually formed due to frequent oscillations of the lake level.     

Influence of natural fractures on gas accumulation in the Upper Triassic tight gas sandstones in the northwestern Sichuan Basin,China

The Upper Triassic Xujiahe Formation in the northwestern Sichuan Basin, China, is a typical tight gas sandstone reservoir that contains natural fractures and has an average porosity of 1.10% and air permeability less than 0.1 md because of compaction and cementation. According to outcrops, cores and image logs, three types of natural fractures, namely, tectonic, diagenetic and overpressure-related fractures, have developed in the tight gas sandstones. The tectonic fractures include small faults, intraformational shear fractures and horizontal shear fractures, whereas the diagenetic fractures mainly include bed-parallel fractures. According to thin sections, the microfractures also include tectonic, diagenetic and overpressure-related microfractures. The diagenetic microfractures consist of transgranular, intragranular and grain-boundary fractures. Among these fractures, intraformational shear fractures, horizontal shear fractures and small faults are predominant and significant for fluid movement. Based on the Monte Carlo method, these intraformational shear fractures and horizontal shear fractures improve the reservoir porosity and permeability, thus serving as an important storage space and primary fluid-flow channels in the tight sandstones. The small faults may provide seepage channels in adjacent layers by cutting through layers. In addition, these intragranular and grain-boundary fractures increase the connectivity of the tight gas sandstones by linking tiny pores. The tectonic microfractures improve the seepage capability of the tight gas sandstones to some extent. Low-dip angle fractures are more abundant in the T₃X³ member than in the T₃X² and T₃X⁴ members. The fracture intensities of the sandstones in the T₃X³ member are greater than those in the T₃X² and T₃X⁴ members. The fracture intensities do not always decrease with increasing bed thickness for the tight sandstones. When the bed thickness of the tight sandstones is less than 1.0 m, the fracture intensities increase with increasing bed thickness in the T₃X³ member. Fluid inclusion evidence and burial history analysis indicate that the tectonic fractures developed over three periods. The first period was at the end of the Triassic to the Early Jurassic. The tectonic fractures developed during oil generation but before the matrix's porosity and permeability reduced, which suggests that these tectonic fractures could provide seepage channels for oil migration and accumulation. The second period was at the end of the Cretaceous after the matrix's porosity and permeability reduced but during peak gas generation, which indicates that gas mainly migrated and accumulated in the tectonic fractures. The third period was at the end of the Eogene to the Early Neogene. The tectonic fractures could provide seepage channels for secondary gas migration and accumulation from the Upper Triassic Xujiahe Formation into the overlying Jurassic Formation.     

南海北部气烟囱成因及其与油气及水合物运聚成藏关系

南海北部大陆边缘盆地油气勘探及天然气水合物调查与勘查评价中,地球物理资料尤其是二维/三维地震剖面上常见不同类型、不同特征且与油气藏及天然气水合物藏密切相关的地震反射模糊带等地震地质异常体,即“气烟囱”或“流体底辟”或“含气陷阱”。本文拟重点研究“气烟囱”成因及其与油气及天然气水合物运聚成藏的关系。油气勘探实践表明,气烟囱往往与油气藏尤其是天然气水合物藏伴生,且油气及水合物多处于其上覆或两侧位置附近。通过大量油气及天然气水合物勘探实践、地质地球物理资料综合分析及油气地球化学分析等,充分证实了气烟囱与其上覆或两侧附近的油气及天然气水合物藏具有密切的成因联系。研究表明,气烟囱作为连接和沟通烃源/气源供给系统与油气藏及水合物藏之间的重要桥梁和纽带,是油气（水合物）勘探中判识追踪油气藏及水合物藏成因、确定其烃源/气源供给系统活动特征的重要依据和指示。因此,深入分析研究气烟囱系统成因及类型,不仅能够追踪探索和判识确定油气及水合物成因,阐明其运聚成藏规律及控制因素,而且能够指导油气及水合物勘探部署与综合评价工作。同时,通过油气及水合物成因的地球化学分析,亦可判识确定其气烟囱成因及其对油气和水合物运聚成藏的控制影响作用。     

东海陆架盆地N气田花港组储层特征及分类评价

东海陆架盆地西湖凹陷古近系花港组储层为典型的低孔、低渗储层。基于大量岩心物性、粒度、薄片、压汞等资料,对N气田目的层储层岩性、物性和孔隙结构特征进行精细评价。结果表明：N气田花港组储层岩性以细砂岩为主,矿物成分构成稳定,以石英为主,黏土含量低,岩性较纯;随着埋藏变深,孔隙变差,粒间孔减少,溶蚀孔增加,孔喉半径减小,连通性变差;局部发育砂砾岩,且渗透率大于细砂岩一个数量级以上,可作为甜点储层开发。基于实验和试油资料统计结果,建立了一套适用于花港组储层的综合分类评价标准,包含孔隙度、渗透率、饱和度和地质特征4类储层重要参数,分类结果特征鲜明,分类依据科学可靠,为该区域低孔、低渗储层勘探开发提供依据。     

Petrographic and geochemical characteristics of the lacustrine black shales from the Upper Triassic Yanchang Formation of the Ordos Basin,China: Implications for the organic matter accumulation

The lacustrine black shales in the Chang7 Member from the Upper Triassic Yanchang Formation of the Ordos Basin in Central China are considered one of the most important hydrocarbon source rocks. However, the mechanism of organic accumulation in the black shales remains controversial. To resolve the controversy, with the former paleontological data of Yanchang Formation and sedimentation rate data of the Chang7 black shales, we investigated the typical intervals of the Chang7 black shales (TICBS) which were obtained by drilling in Yaowan at the southern margin of the Ordos Basin and performed various sedimentary, isotopic and geochemical analysis, including the sedimentary petrography, pyrite morphology, total organic carbon (TOC) and total sulfur (TS), the ratio of pyritic Fe to total Fe (DOP_T), major and trace elements, together with pyritic sulfur isotopes (δ³⁴S_py). The high sulfur content, enrichment of redox-sensitive trace metals, and the lower sedimentation rate of the TICBS in addition to the presence of marine spined acritarchs and coelacanth fossils indicate that the TICBS were deposited in a lacustrine environment possibly influenced by seawater. The petrographic observations show a thick layer of black shale with interlayers of thin layered siltstone (silty mudstone) and laminated tuff, which were related to the turbidity currents and volcanism, respectively. The U/Th, C-S, and Mo-U covariations, pyrite morphology, DOP_T, combined with the δ³⁴S_py, suggest that the deposition occurred beneath the anoxic-sulfidic bottom waters, which was intermittently influenced by the oxygen-containing turbidity. The Ni/Al and Cu/Al possibly show extremely high to high primary productivity in the water column, which might be connected with the substantial nutrients input from seawater or frequently erupted volcanic ash entering the lake. In addition, the coincidence of an increased abundance of TOC with increased P/Al, Ni/Al, Cu/Al and U/Th, as well as relatively consistent Ti/Al suggest that the accumulation of the organic matter might be irrelevant to the clastic influx, and was mainly controlled by the high primary productivity and anoxic-sulfidic conditions. Further, the covariations of TOC vs. P/Al and TOC vs. Ba/Al indicate that the high primary productivity led to the elevated accumulation and burial of organic matter, while the anoxic to sulfidic conditions were likely resulted from an intense degradation of the organic matter during the early diagenesis. In summary, the organic matter accumulation is ultimately attributed to the high primary productivity possibly resulted from seawater or volcanic ash entering the lake.     

Deep-lacustrine sandy debrites and turbidites in the lower Triassic Yanchang Formation,southeast Ordos Basin,central China: Facies distribution and reservoir quality

The deep lacustrine gravity-flow deposits are widely developed in the lower Triassic Yanchang Formation, southeast Ordos Basin, central China. Three lithofacies include massive fine-grained sandstone, banded sandstone, and massive oil shale and mudstone. The massive fine-grained sandstones have sharp upper contacts, mud clasts, boxed-shaped Gamma Ray (GR) log, but no grading and Bouma sequences. In contrast, the banded sandstones display different bedding characteristics, gradational upper contacts, and fine-upward. The massive, fine-grained sandstones recognized in this study are sandy debrites deposited by sandy debris flows, while the banded sandstones are turbidites deposited by turbidity currents not bottom currents. The sediment source for these deep gravity-flow sediments is a sand-rich delta system prograding at the basin margin. Fabric of the debrites in the sandy debris fields indicates initial formation from slope failure caused by the tectonic movement. As the sandy debris flows became diluted by water and clay, they became turbidity currents. The deep lacustrine depositional model is different from the traditional marine fan or turbidite fan models. There are no channels or wide lobate sand bodies. In the lower Triassic Yanchang Formation, layers within the sandy debrites have higher porosity (8–14%) and permeability (0.1–4 mD) than the turbidites with lower porosity (3–8%) and permeability (0.04–1 mD). Consequently, only the sandy debrites constitute potential petroleum reservoir intervals. Results of this study may serve as a model for hydrocarbon exploration and production for deep-lacustrine reservoirs from gravity-flow systems in similar lacustrine depositional environments.     

Lithofacies and origin of the Late Triassic muddy gravity-flow deposits in the Ordos Basin,central China

Fine-grained sediments from the Late Triassic Yanchang Fm. in the Ordos Basin (central China) were studied by core analysis and geophysical logging. Part of the mudstones in this formation are stratified, part of them are unstratified; the various mudstones can be subdivided into eight types on the basis of their structures and textures. They represent a variety of environments, ranging from delta fronts and subaqueous fans to deep-water environments. Part of the sediments were reworked and became eventually deposited from subaqueous gravity flows, such as mud flows, turbidity currents and hyperpycnal flows that easily developed on the clay-rich deltaic slopes. The sediments deposited by such gravity flows show abundant soft-sediment deformation structures. Understanding of such structures and recognition of fine-grained sediments as gravity-flow deposits is significant for the exploration of potential hydrocarbon occurrences. Because fine-grained deposits become increasingly important for hydrocarbon exploration, and because the sediments in the lacustrine Yanchang Formation were deposited by exactly the same processes that play a role in the accumulation of deltaic and prodeltaic fine-grained sediments, the sedimentological analysis provided here is not only important for the understanding of deep lacustrine sediments like the Yanchang Formation, but also for a better insight into the accumulation of fine-grained prodeltaic deep-marine sediments and their potential as hydrocarbon source rocks and reservoir rocks.     

天然气水合物储层有效绝对渗透率现场测试进展

天然气水合物作为一种新型的非常规能源具有较大的资源潜力。天然气水合物储层的有效绝对渗透率常被选为天然气水合物降压开采效果评价的关键指标,指标大小需要在现场进行测试加以确定。首先对国内外典型地区天然气水合物储层有效绝对渗透率的现场测试实例进行梳理,然后介绍了地层测试和核磁共振测井等现场测试方法,最后总结了目前水合物储层有效渗透率现场测试仍存在的主要问题并给出未来的研究建议,期望为天然气水合物储层现场测试技术的发展提供参考。     

Bicyclic alkanes in source rocks of the Triassic Yanchang Formation in the Ordos Basin and their inconsistency in oil-source correlation

The Triassic Yanchang Formation is the main source rocks for Mesozoic oil in Ordos Basin. The formation includes 10 oil-bearing beds (Ch 1–Ch 10), that each can be further divided into two to three intervals. Abundant C₁₂–C₁₄ and C₁₅–C₁₆ bicyclic alkanes have been detected in the formation in the Xifeng oilfield, Ordos Basin. The C₁₂–C₁₄ group is dominated by C₁₂ and C₁₃, and the C₁₅–C₁₆ group contains abundant C₁₅. The groups show three distribution patterns: A) the C₁₂–C₁₄ group is the major component in the non-source rocks of the Ch 7-1 and Ch 8-1 intervals; B) both groups are abundant and are common in source rocks of the Ch 7-3 interval; and C) the C₁₅–C₁₆ group is the major component in source rocks of the Ch 7-3 interval and also in sediments that contain type Ⅰ or partial sapropel type Ⅱ₁ organic matter (OM) in the Ch 7-2 and Ch 8-1 intervals. Although thermal maturities of the source rocks in the Ch 7 section are similar, they show significant differences with respect to the drimane isomerisation index, which indicates that the drimane rearrangement is controlled by thermal evolution of the sediments, but may also be closely related to the depositional environment. This study determined that reducing environments are more conducive to preservation of drimane than oxic environments. The drimane isomerisation index and the value of the hopane parameter Tm/Ts are positively correlated. The parameter Tm/Ts varies over a wide range within the sequence, and the large variations may be a result of terrigenous OM input by turbidity currents and/or gravity flows, mixed with the autochthonous sediments. Abundant homodrimane in both source rocks may reflect reducing environments in deep lakes and major input of higher plant OM. Organic-rich shale and oil shale in the Ch 7-3 interval of the Yanchang Formation are the primary sources of oil in reservoirs in the Xifeng area. The crude oil is rich in bicyclic alkanes that are dominated by C₁₅–C₁₆ as source rocks with pattern C for bicyclic alkanes, which indicates an origin mainly from the Ch 7-3 interval. The main peaks in all of the crude oils are associated with 8β(H)-drimane and lower abundance of rearranged drimane. However, most of the source rocks have a main peak associated with 8β(H)-homodrimane or rearranged drimane. Weak microbial action, selective degradation and water washing may be the cause of the significant difference in bicyclic sesquiterpane composition between the crude oil and the source rocks. The result suggests that oil-source correlations based on the bicyclic sesquiterpanes are questionable.