Control of micro-wettability of pore-throat on shale oil occurrence:A case study of laminated shale of Permian Lucaogou Formation in Jimusar Sag,Junggar Basin,NW China

The control of micro-wettability of pore-throat on shale oil occurrence in different types of reservoir spaces remains unclear.Take the shale oil reservoir of the Permian Lucaogou Formation in the Jimusar Sag,Junggar Basin as an example,the reservoir space in laminated shale and the control of micro-wettability of pore-throat on shale oil occurrence were studied by using scanning electron microscope(SEM),multi-stage pyrolysis,quantitative fluorescence,nuclear magnetic resonance(NMR)and other techniques.The results show that there are mainly two types of laminated shale in the Lucaogou Formation,namely laminated shale rich in volcanic materials+terrigenous felsic,and laminated shale rich in volcanic materials+carbonate.The former type contains feldspar dissolution pores and intergranular pores,mainly with felsic mineral components around the pore-throats,which are water-wet and control the free shale oil.The latter type contains carbonate intercrystalline pores and organic pores,mainly with oil-wet mineral components around the pore-throats,which control the adsorbed shale oil.The oil-wet mineral components around the pore-throats are conducive to oil accumulation,but reduce the proportion of free oil.In the Lucaogou Formation,free oil,with high maturity and light quality,mainly occurs in the laminated shale rich in volcanic materials+terrigenous felsic.

Pore-Throat Combination Types and Gas-Water Relative Permeability Responses of Tight Gas Sandstone Reservoirs in the Zizhou Area of East Ordos Basin, China

With the aim of better understanding the tight gas reservoirs in the Zizhou area of east Ordos Basin,a total of 222 samples were collected from 50 wells for a series of experiments.In this study,three pore-throat combination types in sandstones were revealed and confirmed to play a controlling role in the distribution of throat size and the characteristics of gas-water relative permeability.The type-I sandstones are dominated by intercrystalline micropores connected by cluster throats,of which the distribution curves of throat size are narrow and have a strong single peak(peak ratio>30%).The pores in the type-II sandstones dominantly consist of secondary dissolution pores and intercrystalline micropores,and throats mainly occur as slice-shaped throats along cleavages between rigid grain margins and cluster throats in clay cement.The distribution curves of throat size for the type-II sandstones show a bimodal distribution with a substantial low-value region between the peaks(peak ratio<15%).Primary intergranular pores and secondary intergranular pores are mainly found in type-III samples,which are connected by various throats.The throat size distribution curves of type-III sandstones show a nearly normal distribution with low kurtosis(peak ratio<10%),and the micro-scale throat radii(>0.5μm)constitute a large proportion.From type-I to type-III sandstones,the irreducible water saturation(Swo)decreased;furthermore,the slope of the curves of Krw/Krg in two-phase saturation zone decreased and the two-phase saturation zone increased,indicating that the gas relative flow ability increased.Variations of the permeability exist in sandstones with different porethroat combination types,which indicate the type-III sandstones are better reservoirs,followed by type-II sandstones and type-I sandstones.As an important factor affecting the reservoir quality,the pore-throat combination type in sandstones is the cumulative expression of lithology and diagenetic modifications with strong heterogeneity.

Pore Size Distribution of a Tight Sandstone Reservoir and its Effect on Micro Pore-throat Structure: A Case Study of the Chang 7 Member of the Xin’anbian Block, Ordos Basin, China

Pore distribution and micro pore-throat structure characteristics are significant for tight oil reservoir evaluation, but their relationship remains unclear. This paper selects the tight sandstone reservoir of the Chang 7 member of the Xin’anbian Block in the Ordos Basin as the research object and analyzes the pore size distribution and micro pore-throat structure using field emission scanning electron microscopy(FE-SEM), high-pressure mercury injection(HPMI), highpressure mercury injection, and nuclear magnetic resonance(NMR) analyses. The study finds that:(1) Based on the pore size distribution, the tight sandstone reservoir is characterized by three main patterns with different peak amplitudes. The former peak corresponds to the nanopore scale, and the latter peak corresponds to the micropore scale. Then, the tight sandstone reservoir is categorized into three types: type 1 reservoir contains more nanopores with a nanopore-to-micropore volume ratio of 82:18;type 2 reservoir has a nanopore-to-micropore volume ratio of 47:53;and type 3 reservoir contains more micropores with a nanopore-to-micropore volume ratio of 35:65.(2) Affected by the pore size distribution, the throat radius distributions of different reservoir types are notably offset. The type 1 reservoir throat radius distribution curve is weakly unimodal, with a relatively dispersed distribution and peak ranging from 0.01 μm to 0.025 μm. The type 2 reservoir’s throat radius distribution curve is single-peaked with a wide distribution range and peak from 0.1 μm to 0.25 μm. The type 3 reservoir’s throat radius distribution curve is single-peaked with a relatively narrow distribution and peak from 0.1 μm to 0.25 μm. With increasing micropore volume, pore-throat structure characteristics gradually improve.(3) The correlation between micropore permeability and porosity exceeds that of nanopores, indicating that the development of micropores notably influences the seepage capacity. In the type 1 reservoir, only the mean radius and effective porosity have suitable correlations with the nanopore and micropore porosities. The pore-throat structure parameters of the type 2 and 3 reservoirs have reasonable correlations with the nanopore and micropore porosities, indicating that the development of these types of reservoirs is affected by the pore size distribution. This study is of great significance for evaluating lacustrine tight sandstone reservoirs in China. The research results can provide guidance for evaluating tight sandstone reservoirs in other regions based on pore size distribution.

Classification of microscopic pore-throats and the grading evaluation on shale oil reservoirs

On the basis of the characterization of microscopic pore-throats in shale oil reservoirs by high-pressure mercury intrusion technique, a grading evaluation standard of shale oil reservoirs and a lower limit for reservoir formation were established. Simultaneously, a new method for the classification of shale oil flow units based on logging data was established. A new classification scheme for shale oil reservoirs was proposed according to the inflection points and fractal features of mercury injection curves: microscopic pore-throats(less than 25 nm), small pore-throats(25-100 nm), medium pore-throats(100-1 000 nm) and big pore-throats(greater than 1 000 nm). Correspondingly, the shale reservoirs are divided into four classes, I, II, III and IV according to the number of microscopic pores they contain, and the average pore-throat radii corresponding to the dividing points are 150 nm, 70 nm and 10 nm respectively. By using the correlation between permeability and pore-throat radius, the permeability thresholds for the reservoir classification are determined at 1.00× 10^(-3) μm^2, 0.40×10^(-3) μm^2 and 0.05×10^(-3) μm^2 respectively. By using the exponential relationship between porosity and permeability of the same hydrodynamic flow unit, a new method was set up to evaluate the reservoir flow belt index and to identify shale oil flow units with logging data. The application in the Dongying sag shows that the standard proposed is suitable for grading evaluation of shale oil reservoirs.

Experimental investigation on migration and retention mechanisms of elastic gel particles(EGPs)in pore-throats using multidimensional visualized models

Knowledge of migration and retention mechanisms of elastic gel particles(EGPs)in pore-throats is essential for the effective application of EGPs as a smart sweep improvement and profile control agent for enhanced oil recovery(EOR).The matching coefficient(defined as the ratio of particle size to pore-throat size)is used to investigate its influence on migration,retention and profile control performance of EGPs.A 1-D continuous pore-throat visualization model(PTVM),a 2-D heterogeneous PTVM and a 3-D heterogeneous core model were constructed and used to investigate pore-scale migration,retention and controlling mechanism of migration and retention characteristics on EGPs profile control.The results of the 1-D continuous PTVM indicated that while the matching coefficient was in the optimal range(i.e.,0.20-0.32),the EGPs could not only smoothly migrate to the deeper pore-throats,but also form stable retention in the pores to resist the erosion of injected water,which was conducive to the effective indepth profile control.The results of the 2-D heterogeneous PTVM verified that the sweep efficiency in low-permeability regions could be significantly improved by in-depth migration and stable retention of EGPs in the pore-throats with an optimal matching coefficient(0.29),which was much better than that in cases with a smaller matching coefficient(0.17)or an excessive matching coefficient(0.39).Moreover,the NMR displacement experiments of 3-D heterogeneous cores were carried out to simulate the EGPs profile control in actual reservoir porous media.Saturation images and T2 spectrum curves of crude oil showed that EOR in the low-permeability layer was highest(56.1%)using EGPs profile control with an optimal matching coefficient,attributing to the in-depth migration and stable retention of EGPs.

Pore-throat structure characteristics and its impact on the porosity and permeability relationship of Carboniferous carbonate reservoirs in eastern edge of Pre-Caspian Basin

Carboniferous carbonate reservoirs at the eastern edge of the Pre-Caspian Basin have undergone complex sedimentation,diagenesis and tectonism processes,and developed various reservoir space types of pores,cavities and fractures with complicated combination patterns which create intricate pore-throats structure.The complex pore-throat structure leads to the complex porosity-permeability relationship,bringing great challenges for classification and evaluation of reservoirs and efficient development.Based on the comprehensive analysis on cores,thin sections,SEM,mercury intrusion,routine core analysis and various tests,this paper systematically investigated the features and main controlling factors of pore-throats structure and its impact on the porosity-permeability relationship of the four reservoir types which were pore-cavity-fracture,pore-cavity,pore-fracture and pore,and three progresses are made.(1)A set of classification and descriptive approach for pore-throat structure of Carboniferous carbonate reservoirs applied to the eastern edge of the Pre-Caspian Basin was established.Four types of pore-throat structures were developed which were wide multimodal mode,wide bimodal mode,centralized unimodal mode and asymmetry bimodal mode,respectively.The discriminant index of pore-throat structure was proposed,realizing the quantitative characterization of pore-throat structure types.(2)The microscopic heterogeneity of pore reservoir was the strongest and four types of pore-throat structures were all developed.The pore-fracture and pore-cavity-fracture reservoirs took the second place,and the microscopic heterogeneity of pore-cavity reservoir was the weakest.It was revealed that the main controlling factor of pore-throat structure was the combination patterns of reservoir space types formed by sedimentation,diagenesis and tectonism.(3)It was revealed that the development of various pore-throat structure types was the important factor affecting poroperm relationship of reservoirs.The calculation accuracy of permeability of reservoirs can be improved remarkably by subdividing the pore-throat structure types.This study deepens the understanding of pore-throat structure of complicated carbonate reservoirs,and is conducive to classification and evaluation,establishment of precise porosity-permeability relationship and highly efficient development of carbonate reservoirs.

Experimental study of the effects of a multistage pore-throat structure on the seepage characteristics of sandstones in the Beibuwan Basin:Insights into the flooding mode

To investigate the relationship between grain sizes, seepage capacity, and oil-displacement efficiency in the Liushagang Formation of the Beibuwan Basin, this study identifies the multistage pore-throat structure as a crucial factor through a comparison of oil displacement in microscopic pore-throat experiments. The two-phase flow evaluation method based on the Li-Horne model is utilized to effectively characterize and quantify the seepage characteristics of different reservoirs, closely relating them to the distribution of microscopic pores and throats. It is observed that conglomerate sandstones at different stages exhibit significant heterogeneity and noticeable differences in seepage capacity, highlighting the crucial role played by certain large pore throats in determining seepage capacity and oil displacement efficiency. Furthermore, it was found that the displacement effects of conglomeratic sandstones with strong heterogeneity were inferior to those of conventional homogeneous sandstone, as evidenced by multiple displacement experiments conducted on core samples with varying granularities and flooding systems. Subsequently, core-based experiments on associated gas flooding after water flooding were conducted to address the challenge of achieving satisfactory results in a single displacement mode for reservoirs with significant heterogeneity. The results indicate that the oil recovery rates for associated gas flooding after water flooding increased by 7.3%-16.4% compared with water flooding alone at a gas-oil ratio of approximately 7000 m^(3)/m^(3). Therefore, considering the advantages of gas flooding in terms of seepage capacity, oil exchange ratio, and the potential for two-phase production, gas flooding is recommended as an energy supplement mode for homogeneous reservoirs in the presence of sufficient gas source and appropriate tectonic angle. On the other hand, associated gas flooding after water flooding is suggested to achieve a more favorable development effect compared to a single mode of energy supplementation for strongly heterogeneous sandstone reservoirs.

非均相体系在微通道中的封堵性能研究

基于大庆油田天然岩心孔隙尺度分布特征建立了微通道模型,考虑非均相体系中的分散相和连续相的变形及流动特征,以相场法建立流动模型并用有限元方法求解,模拟了分散相颗粒在微通道内的生成,并实现了颗粒分选,研究了微观孔喉结构中匹配系数和孔喉比对颗粒封堵性能的影响。结果表明,颗粒在微观孔喉结构中发生弹性封堵时,孔喉入口处压力随颗粒运移通过而呈现周期性变化;颗粒与孔喉最佳匹配系数为[1.0,1.4),此区间内颗粒能够在孔喉入口处暂时封堵,变形运移通过孔喉后恢复原形;当孔隙直径相同时,匹配系数和孔喉比越大,颗粒通过压力越大;颗粒粒径越大,颗粒通过压力临界值越小。

鄂尔多斯盆地神木气田太原组低品质气藏储层微观特征及形成机理

鄂尔多斯盆地神木气田与周边气田开发效果差异较大,表现出低品质气藏特征,给气田勘探部署及持续稳产带来一定困扰。为了揭示低品质气藏成因,基于不同尺度微观实验手段,对神木气田太原组储层开展了微观特征及形成机理研究。结果表明,神木气田太原组储层具有“富石英、贫长石、岩屑含量较高”的特征,发育小孔—细喉型孔喉组合,孔喉连通性较差,储渗能力较弱,为低孔—超低渗致密砂岩储层;太原组低品质储层的形成受杂基、喷发岩岩屑含量及成岩作用的共同影响。储层在形成过程中,受晚石炭世—早二叠世鄂尔多斯盆地北部内蒙古古隆起火山活动的影响明显,砂岩内喷发岩岩屑和杂基含量普遍较高,喷发岩岩屑为次生孔隙的发育提供了主要物质基础,杂基在堵塞孔隙的同时也产生了一定数量杂基溶孔,对储层的影响具有双重性。成岩过程中的溶蚀作用对于太原组储层的形成至关重要,增孔效应占现今孔隙度的64.3%。晚白垩世末期,燕山运动末幕导致鄂尔多斯盆地构造反转,气水重新调整,盆地东部天然气沿断裂部分逸散,最终形成了现今神木气田太原组的低品质气藏。神木气田下一步勘探重点应在摸清成岩作用宏观展布规律及有利岩性圈闭的基础上,寻找高含量喷发岩岩屑和低含量杂基的发育区。

致密砂岩储层孔隙结构特征对可动流体赋存的影响:以鄂尔多斯盆地庆城地区长7段为例

分析孔隙结构和可动流体分布特征是储层研究的关键要素,也是当前研究的重点与热点,对致密砂岩油气勘探及提高油气采收率具有重要意义。以鄂尔多斯盆地庆城地区长7段致密砂岩储层为例,通过物性测试、铸体薄片、扫描电镜、高压压汞和核磁共振实验,结合分形理论,分析了致密砂岩储层孔隙结构、非均质性和可动流体分布特征,讨论了孔喉结构和非均质性对可动流体赋存的影响。结果表明:研究区长7段储层储集空间主要由微纳米级孔隙贡献,孔隙连通性较差,孔喉半径主要分布在0.050~0.500μm;孔喉结构非均质性较强,分形维数分布在2.65~2.90;流体可动性较差,可动流体饱和度分布在16.68%~51.74%,可动流体多分布在中孔和小孔内。研究区长7段储层可分为3类:从Ⅰ类到Ⅲ类储层,剩余粒间孔和粒间溶蚀孔发育变少,孔隙连通性变差,孔喉尺寸变小,较大孔喉变少,非均质性变强,流体可动性变差,中孔和大孔内可动流体含量趋于降低,可动流体倾向于在小孔内赋存。研究成果为致密砂岩油气勘探及油气采收率提高提供了理论依据。

致密砂岩孔喉结构分析与渗透率预测方法——以川中地区侏罗系沙溪庙组为例

致密砂岩储层孔喉结构精细表征和渗透性预测是优质储层评价和开发的关键。以川中地区侏罗系沙溪庙组为例,利用高压压汞实验和分形理论,对孔喉结构进行静态表征,探讨孔喉结构、分形维数、储层物性之间的关系,进而分析孔喉结构对渗透率的贡献,建立渗透率预测模型。沙溪庙组样品可分为4种类型:Ⅰ类样品排驱压力低、物性好、孔隙连通性好、平均分形维数为2.11,孔隙以半径大于0.1μm的大孔和中孔为主,半径大于1μm的孔喉贡献了90%以上的渗透率;Ⅱ类样品排驱压力在0.4~1.0 MPa之间,平均孔渗分别为9.72%、0.375×10^(-3)μm^(2),分形维数为2.20,半径大于0.1μm的中孔含量上升,并贡献了大部分渗透率;Ⅲ、Ⅳ类样品排驱压力与分形维数明显高于Ⅰ、Ⅱ类样品,孔隙度低且缺乏大孔导致渗透率较低。半径大于0.1μm的大孔和中孔贡献了沙溪庙组98%以上的渗透率。分形维数是指示孔喉结构的良好标志,分形维数与孔喉半径、最大进汞饱和度、渗透率均呈现明显的负相关关系,而与排驱压力、孔喉相对分选系数呈正相关关系。分形维数与孔喉组成有着强相关性,基于分形维数、孔隙度、最大孔喉半径建立了“孔隙型”储层渗透率定量预测模型。

玛湖凹陷风城组储集层孔喉结构及流体赋存特征

为了揭示和对比玛湖凹陷北部风城组砂岩和泥页岩2类岩性储集层微观结构及不同尺寸孔隙内流体赋存特征,基于高压压汞、核磁共振、大视域拼接电镜扫描等实验,定量表征2类岩性储集层的孔喉尺寸和流体赋存特征,并对比原始样品和加压饱和原油样品的核磁共振以及抽提前后的高压压汞实验结果,揭示不同尺寸孔喉系统内束缚态流体和可动流体的分布。研究表明:2类岩性储集层孔隙和喉道尺寸差异均不明显,主要发育直径为0.01~10.00μm的孔隙和半径小于10.00 nm的喉道,以中孔-细喉为主,其中,泥页岩孔隙直径略大于砂岩,喉道半径略小于砂岩。泥页岩多发育晶间孔、蜂窝状溶孔等导管状孔,砂岩导管状孔和球形孔各占一半,且随着孔径增大,粒间孔、粒间溶孔等球形孔占比增大。流体赋存及可动性受矿物组分、孔径等多种因素影响,有机质、白云石以及黄铁矿的偏油润湿性以及黏土矿物晶间孔的强毛细管束缚致使页岩油可动性降低,可动流体主要分布在直径大于300 nm的中—大孔隙内。综合储集层物性和可动流体分布特征,研究区页岩油有利区块为东部的玛51X井区,该井区泥页岩和砂岩均可作为有利的开发对象。

柳赞油田多层砂岩优势渗流通道特征及喉道体积

陆相油藏储集层非均质性强,长期注水开发容易形成优势渗流通道,导致油井快速水淹,驱油效率降低,开发效果变差。以柳赞油田古近系渐新统沙河街组为例,综合分析测井岩电响应、储集层非均质性、注采特征、储集层孔隙特征等,描述柳赞油田多层砂岩优势渗流通道特征,确定了该区优势渗流通道形成条件,通过建立优势渗流通道喉道体积的计算方法,明确了油藏下一步调驱剂用量,达到了有效封堵优势渗流通道的目的,研究成果可为油田下一步稳油控水提供技术支撑。

陇东合水地区长6油藏成岩作用对孔喉结构的影响探析

在充分了解合水地区长6油藏储层主要勘探成果和勘探难点的基础上,本着对信息进行综合判断、解释和分析的原则,运用沉积岩石学、储层沉积学、实验储层沉积学等方法与原理,对合水地区长6油藏储层孔喉结构类型特征进行了研究。研究结果表明,研究区长6储层主要发育粒间孔、长石溶孔、岩屑溶孔三种孔隙类型;主要发育的喉道类型以片状、弯片状喉道类型为主;主要发育的孔隙组合类型为中孔微喉型和小孔微喉型。还进一步研究了该区长6油藏储层成岩作用对孔喉结构的影响,研究发现该区发育的成岩作用中溶解作用对储层岩石的储集性能起着建设性作用,而压实作用、压溶作用、胶结作用则起着破坏性作用。该研究对研究区孔喉微观结构的认识及油藏的高效开发均具有重要的指导意义。

多孔介质两相流动分形质-热弥散系数模型

利用分形理论描述了多孔介质微观孔喉结构,研究了两相流体在孔道空间内的占比情况,考虑了流体经过孔喉结构处流动状态发生改变产生二次流引起的局部水头损失,结合两相流体的沿途储热能力的差异,推导出孔道中同时存在两种相态流体的速度弥散效应和热弥散系数表达式.研究结果表明:饱和度小于0.1或大于0.9时,非湿润相流体速度弥散和热弥散系数变化受饱和度的影响较小,只与微观孔喉结构有关.当孔喉比为1时,局部水头损失为0,不存在速度弥散效应和热弥散效应;孔喉比大小在1~200时,速度弥散效应和热弥散效应随饱和度、孔喉比和流体物性参数的改变而改变;孔喉比大于200时,速度弥散效应变化不明显,对热弥散系数的影响不再显著,与饱和多孔介质孔喉比为150时速度弥散效应不再显著的结论不一致.壁面温度一定,当孔喉比大于2时,孔喉间隙近壁处的二次流停滞导致加热时间增加,孔喉结构间隙之间的流体温度与孔道壁面的温度近似相等,速度弥散和热弥散效应不受温度影响.

致密砂岩储层微观孔喉结构及其分形特征

孔喉微观结构定量评价一直是致密砂岩储层研究的热点和难点。以分形维数为突破口,在鄂尔多斯盆地子长地区不同井中采集了上三叠统延长组长6段12个岩心样品,通过扫描电镜、铸体薄片、高压压汞等实验方法以及分形理论对致密砂岩样品的孔喉结构及其分形特征进行了研究。结果表明,研究区致密砂岩储层的孔隙类型主要由剩余粒间孔、溶孔和晶间孔组成。总分形维数与孔隙度和渗透率存在良好的负相关性,表明研究区致密砂岩储层孔喉结构的复杂程度和非均质性对物性具有一定的影响。中孔的分形维数与孔喉结构参数的相关性更好,表明中孔的非均质性和表面粗糙度主要影响储集空间和渗流性质。致密砂岩储层的品质与分形维数呈明显的负相关关系,越有利于油气富集的储层,其分形维数越小。

基于恒速压汞技术研究安塞油田S区储层孔隙结构特征

为准确评价安塞油田S区储层孔隙结构特征,利用恒速压汞实验,研究了孔隙和喉道的分布特征以及孔喉半径比特征参数与孔渗间的关系。结果表明:不同渗透率的岩心样品孔隙半径分布范围基本相同,主要分布在120~340μm之间,平均孔隙半径在240μm左右;喉道半径主要分布在23μm以内;孔喉半径比与渗透率呈正相关关系,是影响S区储层渗流能力的主要因素。

基于双峰高斯函数的海上低渗储层孔隙结构定量表征——以琼东南盆地BD21气田陵水组三段为例

海上低渗气藏占比增加,孔隙结构的差异影响气井产能,制约海上低渗气藏规模开发。根据高压压汞和核磁共振实验,采用测井曲线与储层分类参数、双峰高斯函数拟合曲线等方法,利用球状孔隙模型将核磁共振T2谱转化为伪毛细管压力曲线定量表征孔径大小及分布,分析核磁共振T2谱反映的大孔孔隙度、大中孔孔隙度与物性、压汞参数之间关系,分析反映储层渗流能力的孔隙结构评价参数,建立孔隙结构和物性参数预测模型。结果表明:陵水组三段低渗储层孔隙结构分布呈双峰型和单峰型,其中小孔曲线与大孔曲线存在重叠区域,双峰型曲线的重叠区域较小,单峰型曲线的重叠区域较大,孔隙可按双峰高斯函数拟合的小孔曲线、大孔曲线和重叠区域的分布范围划分为大孔、中孔和小孔;大中孔孔隙度、大孔孔隙度可有效评价储层物性和孔隙结构,储层大中孔越发育,物性越好,可动流体饱和度相对较高。以大孔和大中孔综合评价参数为主要指标的低渗储层分类标准,将研究区低渗储层划分为三种类型,其中Ⅰ类、Ⅱ类储层大中孔较为发育,储层物性较好,大孔、大中孔综合评价参数值分别大于7、10,可动流体饱和度相对较高,普遍在65.75%以上;Ⅲ类储层物性相对较差,大孔和大中孔综合评价参数值较小,孔隙结构复杂,可动流体饱和度相对较低。该结果为海上低渗气田经济有效开发提供指导。

基于孔喉分布碳酸盐岩储层类型划分

针对储集空间多样、非均质性强的碳酸盐岩储层,由于内部孔隙结构复杂,常规的岩石物理分类方法难以准确地划分储层类别,特别是对孔喉半径呈现双峰、三峰等多峰分布的复杂多孔隙系统。本文以中东某油田M组碳酸盐岩储层为研究对象,明确了岩石内部孔隙结构决定孔喉半径分布特征,进而影响岩石的类型划分。因此从孔喉大小分布入手,考虑多峰样品中每个峰对应孔隙组分对岩石储集空间及渗流作用的贡献,以累积渗透率曲线为依据,提出了结合孔喉大小及其占比的组合孔喉半径参数(Rmax^(*))来表征岩石的孔隙结构,并对选取的114块双峰及43块三峰岩样进行分类。结合物性、压汞、薄片、测井等资料,对每类储层特征展开了深入研究。结果表明,相比于利用单一孔喉半径(Winland R35)的分类结果,Rmax^(*)可以更好地表征储层孔隙结构,提高储层的分类效果。

储层矿物类型对致密油藏CO_(2)驱替效果的影响

为明确致密砂岩储层中石英、伊利石和绿泥石对CO_(2)驱油效率及孔隙动用特征的影响,分别选取以石英、伊利石、绿泥石为主要矿物类型的3种岩心,开展核磁共振扫描分析下的CO_(2)驱替实验,定量评价每种类型岩心在不同CO_(2)注入压力下小孔隙、大孔隙的原油采出程度,并分析了产出水中离子质量浓度变化。结果表明:目标储层以石英型和黏土矿物型为主,其中黏土矿物以伊利石和绿泥石为主;石英型岩心的CO_(2)驱替过程中,当CO_(2)注入压力小于等于最小混相压力时,大孔隙的原油动用程度大于小孔隙,当CO_(2)注入压力大于最小混相压力时,小孔隙的原油动用程度增加,而大孔隙的原油动用程度下降;伊利石型岩心大、小孔隙的原油采出程度最大,驱油效果最好,绿泥石型岩心大孔隙的原油采出程度很高,小孔隙的原油采出程度非常低,整体驱油效果最差;随着CO_(2)注入压力的增加,石英型岩心产出水中金属离子质量浓度大幅增加,伊利石型、绿泥石型岩心溶蚀后的钙、镁等离子产生沉淀,且绿泥石型岩心沉淀量最大,最易堵塞小孔隙。研究成果为致密砂岩油藏CO_(2)驱提供了参考和依据。