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1.
Malcolm B. Hart Richard G. Bromley Stephen R. Packer 《Proceedings of the Geologists' Association. Geologists' Association》2012,123(3):471-478
The complex boundary between the Arnager Greensand Formation and the Arnager Limestone Formation on the island of Bornholm (Denmark) has been studied for almost a century. Despite this effort, the hiatus represented by the boundary remains poorly constrained. Using a considerable number of processed samples and thin sections the uppermost Arnager Greensand Formation is confirmed as Thalmanninella reicheli Zone age (early Middle Cenomanian) and the overlying Arnager Limestone Formation is probably early Coniacian in age. No evidence of macrofossil and microfossil assemblages indicative of the late Cenomanian or the Turonian have been recorded and there is no palaeontological or sedimentological evidence of the global late Cenomanian (Bonarelli or OAE 2) anoxic event. The significant mid-Cenomanian to early Coniacian hiatus reflects a period of sediment starvation along the line of the Sorgenfrei-Tornquist Zone in the vicinity of Bornholm. 相似文献
2.
Emad S. AlHomadhi 《Arabian Journal of Geosciences》2014,7(7):2871-2879
In sandstone, there is a trend between porosity (?) and permeability (k). It is a linear relationship having the form log (k)?=?a?+?(b ?). The slope, intercept, and degree of scatter of the log(k)???? trends vary from formation to another. These variations are attributed to differences in initial grain size and sorting, diagenetic history, cementation, clay content, pore geometry, and compaction history. In the literature, permeability and porosity modeling by using lab experiments was carried out by using unconsolidated sandstone, sand packs, or synthetic particles. Such models cannot be applied to predict flow properties of consolidated natural sandstone. Furthermore in these models, sand grain size, shape, and sorting factors were considered as the main factors that affect porosity and permeability. Hardly, any attention was paid to the confining pressure and the fraction of cementing material that bind the grain to form a coherent rock. If these two crucial aspects are not taken into consideration during the model development, the model cannot be applied to natural consolidated sandstone. The main objective of the present paper is to develop a new model for porosity versus permeability taking into account important factors such as sand grain size and sorting, compaction pressure, and concentration of cementing material that bind the sand grains. The effect for clay swelling or migration was however discarded, as the sand grains were washed prior to consolidation. The sand used in producing the sandstone cores was medium- to fine-sized well-sorted sand grains. The grain’s sphericity was measured to be in the range of (0.8–0.9) with little angularity. The fabricated cores have an average compressive strength of 5,700 psi, which is comparable with Bera sandstone strength. Also, the produced cores were stable in the fluid media as they were subjected to 300 °C to allow cementing material to be crystallized. The aspect of the present work was to analyze the dependence of both the permeability as well as the porosity on the variables of the present study that consist of grain size, cementation fraction, and the confining pressure. Using the experimental data, a linear relationship, in terms of each variable, was developed here that can eventually help researchers to fabricate cores with desired properties. The second step was to generate more general models to be used as references for scholars for further work in this research field. Nonlinear regression analysis was carried out on all the three variables of the present study to obtain two nonlinear correlations: one describes the behavior of permeability and the other describes porosity. In the third step, an advanced correlation that describes permeability versus porosity in a quantitative manner was developed by using nonlinear regression analysis. Permeability was studied accordingly as a function of all the three variables of the present study as well as porosity. This step represents the main objective of this paper. 相似文献
3.
为了研究孔隙度、渗透率、泥质等参数与砂岩型铀矿成矿的关系,本文对松辽盆地中央坳陷大庆长垣南部某区块四方台组底部砂岩进行分析。含铀矿砂岩具有高放射性,这使得测井曲线的密度值异常降低,自然伽马值异常升高。通过研究总结出利用升高的自然伽马曲线校正密度曲线的方法,以及利用其他不受放射性影响曲线重构自然伽马曲线的方法。与岩心的对比分析结果证明,校正后的密度曲线与重构后的自然伽马曲线较准确,密度曲线校正与自然伽马曲线重构解决了含铀砂岩利用测井曲线求取孔隙度、渗透率参数不准的问题。在准确求取测井参数的基础上,得到能展现砂体内部非均质性特点的物性空间展布并成图分析,进而得出本地区有利于铀成矿的物性条件：产生铀矿的砂体并不是孔渗性质最好的地方,也不是孔渗性质最差的地方,而是处于由高孔渗向低孔渗过渡的地方。 相似文献
4.
苏北盆地盐城组咸水层CO2 地质封存泄漏风险的全局敏感性分析 总被引：1，自引：0，他引：1
基于对苏北盆地盐城组下段沉积旋回地层概化,建立了一个含有断层的二维剖面模型,采用TOUGH2/ECO2N 程序对
注入到深部咸水层中CO2 的运移分布特征及沿断层的泄漏过程进行了数值模拟。结果表明,尽管盐城组下段地层具有3层旋
回结构且砂岩层属高孔高渗储层,但由于泥层厚度较小且渗透率相对较高,多层封盖效果不佳。在存在导通断层时,CO2
泄露风险较大。应用Morris 法以断层中气相CO2 总量作为输出变量,对模型参数进行了全局敏感性分析。研究显示,当仅
改变断层参数时,与毛细压力相关的参数对气相CO2 沿断层泄漏影响程度最高;当考虑系统参数整体变化时则以砂岩含水
层和泥岩的渗透率敏感性最高,其次为与毛细压力相关的参数（进气压力、残余液体饱和度及孔隙分布指数）。两种情形下
孔隙度与盐度的敏感性均很小。 相似文献
5.
6.
不同粒径级砂土渗透特性试验研究 总被引：5，自引：0，他引：5
渗透性是砂土的重要工程性质之一,影响砂土渗透性的因素有很多,比如土体密实程度、土颗粒自身特性、流体性质等,其中孔隙率与颗粒粒径是两个重要影响因素。而以往基于混合粒径的天然砂土的研究很难分别对这两个因素进行独立的研究。基于此,首先开展了单一粒径级砂土的常水头渗透试验,分别研究了同一粒径级砂土渗透系数随孔隙率的变化和同一孔隙率下不同粒径级砂土渗透系数随均值粒径的变化规律。试验结果显示,渗透系数随着孔隙率的增加而线性增加、随均值粒径二次方的增加而线性增加,其中均值粒径的影响较大,其变化能导致渗透系数量级上的差异。在此基础上,开展了多粒径混合砂土的渗透试验,讨论了曲率系数、不均匀系数等级配参数对渗透性的影响,从而将单一粒径级的研究成果推广到天然砂土,最终拟合出渗透系数与相关影响因素的经验公式,以便工程实践参考使用。 相似文献
7.
The temporal permeability, porosity, and reactive surface area evolution during dissolution of nonfractured/clay-free Fontainebleau sandstone cores was measured using a flow through percolation reactor. Four core dissolution experiments, each of ∼1000 h duration, were performed on sandstone cores having initial porosities ranging from 5.1 to 16.6%. All experiments were performed at 80°C and at far from equilibrium conditions using a 0.1 M NaOH input solution with a calculated in situ pH of 11.4. Permeability evolution was determined using Darcy’s law together with in situ measured differential pressures. Reactive surface area and porosity evolution were quantified from the mass of Si leaving the core during the experiments. The 5.1 and 8.9% initial porosity sandstone cores experienced porosity increases of 1.2 and 1.4 percent, respectively, during the experiments. These cores experienced a corresponding permeability increase from 0.27 to 0.74 mD and 0.57 to 0.87 mD, respectively. In contrast, the 10.6 and 16.6% initial porosity sandstone cores had permeabilities that were essentially constant during the dissolution experiments despite porosity increases of 6.3 and 2.5%, respectively. Only the 5.1% initial porosity core experienced a permeability evolution roughly consistent with a cubic law dependence on porosity. Reactive surface areas increased during the experiments for all cores; those for the 5.1, 10.6, and 16.6% initial porosity cores increased by 21±6% for each percent porosity increase. The reactive surface area of the 8.9% initial porosity core, however, increased by 148% for each percent porosity increase. These results suggest that dissolution of the 8.9% initial porosity core opened a substantial number of isolated pores, exposing new quartz grain surfaces to dissolution. 相似文献
8.
Permeabilities of sand and shale differ by five to seven orders of magnitude. In the depositional pattern characteristic of the Gulf Coast, lenticular sand bodies occur randomly dispersed within a shale matrix, even though they can be grouped into stratigraphic sequences, contributing to net permeability of the sand-shale system and thus facilitating upward flow of pore water. In addition, a substantial lateral flow develops as fluid flow is directed toward sand bodies, thus concentrating fluid from a wide source area into sand bodies of limited lateral and vertical extent. Calculations reported here determine the effect of randomly distributed sands on both vertical and lateral permeabilities of composite sandshale systems. Effective permeabilities depend only on mean sand percent and local variance about the mean, because the effects of sand body shapes and their orientation and dip are not incorporated in the analysis. Results indicate that at a mean sand percentage of 20–50% a large lateral migration of fluid flow develops as sand bodies attract flow from a region two to seven times the radius of the sand body itself. For a mean sand percentage in excess of 50–60%, large vertical migration results and thus hydrocarbon trapping should not be expected for sand percentages in excess of 50–60%. Results of these calculations are in accord with observations that most larger oil accumulations on the Gulf Coast are found in regions having sandiness between about 20 and 50%. 相似文献
9.
Study of the cross-stratification and other sedimentary structures in the Lower Greensand of the Weald, England, and Bas-Boulonnais, France, indicates that the sediments were deposited by the lateral migration of sand waves in a neritic sea. Comparison of the Lower Greensand sea with the modern North Sea was attempted. If those sediments were deposited as a result of tidal current similar to the present-day North Sea then the Lower Greensand shoreline could be deduced as running northwest-southeast, indication that the western part of the London Platform was submerged. 相似文献
10.
Tertiary reservoir represented by Jeribe, Anah, Azkand, and Azkand/Ibrahim formations has been studied from reservoir characterization point of view in Khabbaz Oil Field/Northern Iraq. Examined thin sections prepared from core rock samples which are selected from the wells Kz-8 and Kz-9 revealed the existence of different microfacies in which are varies types of porosity such as interparticle, intraparticle, moldic, vuggy, and fractures have been noticed. In addition to these different types of diagenetic features are represented mainly by cementation, dolomitization, recrystallization, and dissolution. The available log data for the wells Kz-11, Kz-14, and Kz-16 have been used in characterizing the reservoir properties of the studied formations. The detected lithologies from porosity logs showed domination of limestone, dolomitic limestone, and dolomites in addition to few thin beds of anhydrites in Jeribe Formation and thin beds of sand dominated lithologies in Azkand Formation. Clay content has been calculated from gamma ray log along the studied sections and appeared to be mostly of dispersed clay type as shown from density-neutron porosity crossplot of Thomas-Stieber. Correction from the effect of clay content has been done for all the measured sonic, density, and neutron porosities. The available porosity and permeability values which are measured from core tests in the well Kz-9 for the formations of Jeribe, Anah, and Azkand have been adapted to formalize the best equation for calculating permeability in the other studied wells which have no core test measurements but only log data (Kz-11, Kz-14, and Kz-16 wells). Depending on porosity, permeability, and shale content, the studied sections have been subdivided into seven reservoir units in the wells Kz-11 and Kz-16, and for eight reservoir units in the well Kz-14. 相似文献
11.
储层孔隙分形可以有效表征储层孔渗性能,综合反映储层孔隙结构特征及评价储层开发效果。为确定开发区块动用次序,对于东营凹陷西部区块沙四上纯下次亚段的致密滩坝砂储层,首先,利用薄片、物性及压汞等相关测试数据,计算致密滩坝砂孔喉分形维数（D）;其次,探讨分形维数与储层物性、孔隙结构参数相关性;然后,优选测井数据,建立孔喉分形维数的测井预测模型,并对东营凹陷西部区块滩坝砂分形维数平面分布进行了预测;最后,根据分形维数和油井产能相关性分析,建立了基于分形维数的储层评价标准,对研究区的致密滩坝砂储层进行了分类与评价。结果表明:当2相似文献
12.
人工冻融土物理力学性能研究 总被引：28，自引：2，他引：26
研究了原状土与人工冻融土的密度、干密度、含水量、饱和度、孔隙比、塑限、液限、塑性指数、液性指数、渗透系数等物理指标, 以及抗剪强度、无侧限抗压强度、压缩模量等力学指标的差异性. 土冻融后, 密度、干密度及塑性指数略有降低, 孔隙比、液性指数略有增大, 而其它物理指标基本一致. 粘土冻融后, 渗透性大大增加, 为原状土的～10倍, 而砂土仅略有增大. 粘土冻融后无侧限抗压强度是原状土的1/～1/2, 灵敏度降低, 其结果对冻结法向市政岩土工程的应用推广具有重要意义. 相似文献
13.
管涌对堤防工程的危害极为严重,人类对管涌的认识也逐渐加深。目前,对管涌破坏开始的条件及其破坏后通道贯通的后果了解较多,然而,因其破坏及发展机制的复杂性,对于管涌发生后涌砂及流量的研究并不深入。通过自行设计的室内模型,改变上覆黏土的厚度对3组土性相同的无黏性土试样进行试验。对测压管水头、通道范围、涌砂量和流量等进行对比分析,研究孔隙率、渗透系数以及流量的变化规律,发现涌砂随时间变化满足非线性关系--Boltzmann模型。最后,利用渗透系数与孔隙率以及孔隙率与累计涌砂量的关系,推导并验证了流量随时间变化的理论公式。这对于认识管涌和有效控制管涌发展以及减灾避难有着非常重要的意义。 相似文献
14.
粘土矿物的类型和含量对储层的物性有着较大的影响。伊通盆地岔路河断陷储层属于中低孔、低渗储层。据粘土矿物X射线衍射分析,结合电镜扫描等资料分析研究,得出了储层的孔隙度、渗透率随粘土矿物的含量、成分、产状的变化关系。研究表明,粘土矿物的绝对含量与孔隙度和渗透率呈现负相关性,且其对渗透率的影响明显要比对孔隙度的影响大。随着伊利石含量的增加,砂岩的渗透率有减小的趋势;而随着高岭石含量的增加,砂岩的渗透率有增大的趋势,孔隙度随粘土矿物相对含量的变化不显著。 相似文献
15.
渝东南地区黑色页岩中粘土矿物特征兼论其对储层物性的影响——以彭水县鹿角剖面为例 总被引：2，自引：0，他引：2
为探索渝东南地区下志留统龙马溪组黑色页岩中粘土矿物特征及其与储层物性的关系,在综合前人对含油气盆地粘土矿物分析的基础上,以重庆市彭水县鹿角剖面为例,深入分析了鹿角剖面黑色页岩粘土矿物组合与分布特征、粘土矿物的形成机理及其控制因素以及粘土矿物对孔隙度和渗透率的影响。结果表明,一方面根据古盐度的计算,龙马溪组上部古水介质含盐度较低,下部较高,具有上淡下咸的特点;另一方面该套黑色页岩属于晚成岩阶段B期。储层中粘土矿物的类型、数量及其分布特征等对储层孔渗条件具有一定的控制作用。伊利石(含伊/蒙有序混层矿物)含量与孔隙度有弱正相关关系,与渗透率呈负相关关系,原因可能是成岩伊利石不断生长,一方面由于其体积减小使得显微孔隙体积有所增加,但另一方面,由于自生伊利石晶体细小,使得页岩粒间孔隙遭到不同程度的破坏,致使平均孔隙半径变小,渗透率变差。绿泥石含量与孔隙度呈现微弱的正相关关系,而与渗透率呈现较好的正相关关系。这是由于成岩绿泥石主要来源于长石溶解或蚀变形成的高岭石的转化,因此,绿泥石与孔隙度和渗透率的关系可能反映其与页岩中长石矿物的含量有关。 相似文献
16.
Daniel N. Obiora David Gbenga Godwin Ogobiri 《Journal of the Geological Society of India》2016,87(5):591-600
The reservoir properties of three wells in Royal Field, Niger Delta basin was characterized using fundamental formula. The distributions and thicknesses of sand bodies were determined within each of the wells in the field using geophysical modeling software. The quantitative and qualitative analyses were done for the three exploration wells with the depth ranges of 4000-9700m for Royal well 1, 1000-8805m for Royal well 2, and 4000-8000m for Royal well 3. Each well has identified sand units. Royal well 1 and Royal well 2 have 5 sand units (A, B, C, D, E) each, with respective thicknesses 422m, 110m, 92m, 142m and 350m for well 1, and 82m, 65m, 214m, 362m, and 192m for well 2. Royal well 3 has 4 sand units (A, B, C, D), with respective thicknesses 135m, 80m, 269m and 229m. Petrophysical evaluations were made from well logs. The average porosity values obtained for Royal wells 1, 2, and 3 are 0.24, 0.18 and 0.22 respectively while the corresponding average permeability values are 2789mD, 1292mD, 1643mD. Porosity values obtained from porosity logs and density log (RHOB) using porosity formula are found to be within the range of 0.07- 0.45, while their permeabilities range from 164 to 8453 milli Darcy. The water saturation obtained for each reservoir unit in combination with the resistivity index were used to prove the presence of hydrocarbon in these sands. Royal well 2 having its sand A, 80% hydrocarbon saturated and 82m thickness is the most prolific. The results clearly indicate that the application of this technique is very effective for the interpretation of reservoir properties. 相似文献
17.
Abstract: Stratigraphic controls on the formation and distribution of gas hydrates were examined for sediments from a BH-1 well drilled in the landward slope of the Nankai Trough, approximately 60 km off Omaezaki, Japan. Three lithologic units were recognized in the 250 m-thick sequence of sediments: Unit 1 (0–70 mbsf) consists of calcareous silt and clay with thin volcanic ash layers, Unit 2 (70–150 mbsf) consists of calcareous silt and clay with volcanic ash and thin sand layers, and Unit 3 (150–250 mbsf) consists of weakly consolidated calcareous silt and clay with thick and frequent sand layers. Soupy structures and gas bubbles in the sediments indicate the presence of two hydrate zones between 40 and 130 mbsf and below 195 mbsf. Nannofossil biostratigraphy and magnetostratigraphy indicate that the sequence recovered at the BH-1 well is mostly continuous and represents sediments deposited from 0 to 1.5 Ma. Calculation of the sedimentation rate reveals a condensed section between 65 and 90 mbsf. The inferred distribution of gas hydrates in the BH-1 well appears to be strongly controlled by the stratigraphy and lithology of the sediments. Thick, gently inclined sand layers in Unit 3 provide a conduit for the migration of gases from deeper regions, and are considered responsible for the formation of the hydrate zone below 195 mbsf. At shallower levels, thin, gently inclined sand layers are also considered to allow for the migration of gases, leading to the formation of the upper hydrate zone between 40 and 130 mbsf. The overlying sub-horizontal silt and clay of the condensed section, truncating the underlying gently inclined sand and silt/clay layers, may provide an effective trap for gases supplied through the sand layers, further contributing to hydrate formation in the upper hydrate zone. 相似文献
18.
陕北延长组成岩圈闭油藏的形成及其重要意义 总被引：10，自引：2，他引：10
陕甘宁盆地南部陕北地区的上三叠统延长组,是一套湖盆三角洲体系的碎屑岩沉积。延长组油气资源丰富,但砂体储油物性极差。近期研究发现了一些富含浊沸石胶结物的砂体中,由于浊沸石胶结物的溶蚀而形成的渗透性砂岩,以及浊沸石胶结物再沉淀而成的成岩致密带和压溶嵌合作用形成的致密带。砂体溶蚀带与上倾方向的致密带配套,构成了大型成岩圈闭油藏,并已在此类油藏中探明了可观的石油储量和生成了多量石油。 相似文献
19.
为了准确认识和预测伊通盆地鹿乡断陷储层敏感性的分布,从实验分析入手,测量不同样品的敏感性、物性和粘土矿物等参数,结合铸体薄片、压汞、扫描电镜等实验方法,从宏观和微观2个角度分析了储层敏感性与孔隙度、渗透率与各类粘土矿物相对含量之间的关系,分析了储层敏感性与储层的孔喉类型和粘土矿物产状之间的关系,建立了不同微相控制下的孔隙度、渗透率、粘土矿物含量、石英和长石含量的解释模型.最后,选取孔隙度、渗透率、石英含量、长石含量、伊利石含量、高岭石含量、绿泥石含量、伊/蒙混层含量8个参数,采用Elman神经网络方法分别建立了速敏、水敏、酸敏和碱敏的预测模型.结果表明:采用神经网络方法预测的储层敏感性指数与实验结果吻合;五星构造带具有强的速敏、酸敏、碱敏和盐敏,鹿乡断陷中部和西北部具有强的水敏性. 相似文献
20.
Sedimentary Micro-facies and Macro Heterogeneity of Reservoir Beds in the Third Member of the Qingshankou Formation,Qian'an Area,Songliao Basin 
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下载免费PDF全文 Reinhard F.SACHSENHOFER 《《地质学报》英文版》2007,(6)
An analysis of drill cores and well logs shows that the main micro-facies of the third member sand bodies of the Qingshankou Formation in Qian'an are subaqueous distributary channel facies, sheet sand facies and subaqueous fan facies(olistostrome).Maps showing the distribution of these micro-facies together with inter-channel bay and prodelta mocro-facies are presented for different time-slices(lower,middle and upper parts of the Qingshankou Formation).These maps reveal the instability and change of sediment transport in the Baokang sedimentary system during the depositional period.Sediment transport was from the west in the early stage,from the south in the middle stage and from the northwest in the late stage.Values of thickness,porosity and permeability of the sand bodies in the third member of the Qingshankou Formation show that they have low to medium porosity and low permeability,and are characterized by serious reservoir heterogeneity.The joints between micro-facies and subaqueous fan micro-facies are characterized by the highest heterogeneity, the sheet sand and distal sand bar subfacies come next,and the heterogeneity of the subaqueous distributary channel sand bodies is relatively weak. 相似文献