双坨子气田下白垩统泉三段储层地质建模研究
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摘要
双坨子气田结合目前的生产情况可以看出,气藏部分气井压力下降速度较快,气产量递减幅度大,产水量增大,直接影响了气藏的稳产。三维地质建模研究是油藏开发阶段的一个核心内容,是油气藏数值模拟的必要参数和油气藏开发调整方案的直接依据。建立能够正确反映油气藏地质特征的地质模型是决定油气藏数值模拟、动态预测的关键,对进一步认识油气藏地质特征及调整开发方案从而达到提高油田采收率的目的具有重要意义。本论文利用岩心、地质、测井等资料对双坨子气田泉三段开展了沉积相分析、测井储层参数精细解释研究和储层特征研究,最后利用上述研究成果建立了双坨子气田泉三段三维地质模型。
基于收集到的录井、岩芯和测井资料,识别划分了泉三段单井沉积微相,并编制了泉三段Ⅲ砂层组的沉积相平面展布图,进而总结出泉三段的沉积相模式。泉三段发育曲流河沉积体系。曲流河包括河床、边滩、天然堤、决口扇以及泛滥平原等微相,泉三段沉积微相中边滩最为发育。
岩芯测试物性资料统计分析表明:泉三段砂岩的孔隙度的最小值为4.4%,最大值为27.7%,平均值为19.15%;泉三段砂岩的渗透率的最小值为0.05 10~(-3)μm~2,最大值为953 10~(-3)μm~2,均值为95.57 10~(-3)μm~2。基于“岩芯刻度测井”,采用非线性BP人工神经网络,建立了双坨子气田泉三段单井测井储层参数精细解释模型。研究区5口取芯井神经网络预测孔隙度平均绝对误差为0.73%,渗透率平均相对误差为45.89%,误差较小。
通过对泉三段单井储层级别的划分及统计,得出泉三段主要发育Ⅰ类和Ⅱ类储层,储层以发育“中高孔—中渗型”为主。分析泉三段Ⅸ砂层组的砂体厚度平面图,沉积相控制着储层的发育,储层主要发育在边滩、天然堤微相中。顺着东西向剖面,储层随着河道的摆动迁移而发生变化,顺着河道的方向,储层的连通性是比较好的,呈现条带状形态。
在综合研究该区地质特征的基础上,利用Petrel软件建立了泉三段的构造模型、框架模型、砂组框架模型。采用序贯指示模拟算法建立了泉三段砂泥岩相模型。在数据分析及得到的变差函数模型基础上,在砂泥岩相控制下,进行孔隙度模拟得到双坨子气田泉三段的孔隙度模型,渗透率的模拟以孔隙度为第二变量,进行协同模拟得到双坨子气田渗透率分布模型,利用岩相对其约束,进行双坨子气田含气饱和度模拟。建模结果表明:双坨子气田泉三段的储层总体表现为“中高孔—中渗型”特征,孔隙度、渗透率的分布受到砂泥岩相的明显控制。最后根据建模成果计算得到的双坨子气田泉三段天然气地质储量为8.51亿方。
From the current productivity of Shuang Tuozi gas field, it is can been seen that the pressure dropping quickly in some gas well of gas pool, the gas productivity declining quickly and the water production are directly affected the stable production of the gas pool. The reservoir geological modeling research is the key for the development phase, the necessary parameter for the numerical simulation of reservoir, the directly basis for the development and adjustment program. Establishing the geological modeling correctly reflected geological characteristic of reservoir is the key for the reservoir numerical simulation and dynamic prediction., has important significance for the further understanding the geological characteristic of reservoir and adjusting the development program in order to reach the purpose of improving the recovery ratio. In this paper, it is using the core data, geologic information, logging data to analysis the sedimentary facies of Quan III member of Shuan Tuozi gas field, fine logging interpretation model on reservoir parameters and research on the reservoir characteristic. Finally it is using the above research results to establish the reservoir geological model of Quan III member in Shuang Tuozi gas field.
Based on the borehole log, core and log data, it is identified and classified the microfacies of the single well of Quan III member and composed the sedimentation map of III sand set of Quan III member. Then it is summarized the sedimentation model The Quan III member develops snaking stream. The snaking stream is composed of riverbed, marginal bank, crevasse splay, flood plain and so on. The marginal bank is the mostly developed in the Quan III member.
The statistics of petrophysical data tested using the core shows that the minimum value of the porosity is 4.4%, the maximum value of the porosity is 27.7% and the average value of the porosity is 19.15% and the minimum value of the permeability is 0.05 10~(-3)μm~2, the maximum value of the permeability is 953 10~(-3)μm~2, the average value of the permeability is 95.57 10~(-3)μm~2. On the basis of the principal of core scale the log, it is established the fine interpretation model of reservoir parameter of single well of Quan III member in the Shuang Tuozi gas field using the non-linear BP artificial neural network. The mean absolute error of the predicted porosity by the neural network is 0.73% and the mean relative error of the predicted permeability by the neural network is 45.89% of the 5 core-well in the studied area. The result shows that the error is minimum.
Through the classifying and calculating the reservoir degree of single well of Quan III member, it is obtained that it is mainly developed the I type and II type in the Quan III member. The study demonstrates that it is the medium-large porous- and medium penetrative reservoir in the Quan III member. Through the sand body’s thickness map of the mainly productivity IX sand set of Quan III, it is reached that sedimentary facies controls the reservoir’s development and reservoir is mainly mainly developed in the marginal bank and natural bank. Along with east-western section, the sand body changed along with the deviating and moving of the river channel. And along with the direction of river channel, the connectivity of the reservoirs is relatively good and the shape is banding.
On the basis of comprehensive study of the geologic feature in this area, it is used the Petrel Software to established the structural model, skeleton model and sand set skeleton model of the Quan III member. Using the sequential indication simulated algorithm, it is established the sand-mud lithofacies model of the Quan III member. Based on the data analyses and variation function and under the control of sand-mud lithofacies, it is reached the porosity model after simulation. Using the porosity as the second variable and with the synergistic simulation, it is established the permeability model. By the means of controlling under lithofacies, it is established the saturation model. The model is demonstrated that the characteristic of reservoir is medium-large porosity and medium permeability. And the distribution of the porosity and permeability is under the control of lithofacies. Finally, it is counted that the gas in place is 8.51 billion square of the Quan III member in the Shuang Tuozi gas field in accordance with result of model.
基于收集到的录井、岩芯和测井资料,识别划分了泉三段单井沉积微相,并编制了泉三段Ⅲ砂层组的沉积相平面展布图,进而总结出泉三段的沉积相模式。泉三段发育曲流河沉积体系。曲流河包括河床、边滩、天然堤、决口扇以及泛滥平原等微相,泉三段沉积微相中边滩最为发育。
岩芯测试物性资料统计分析表明:泉三段砂岩的孔隙度的最小值为4.4%,最大值为27.7%,平均值为19.15%;泉三段砂岩的渗透率的最小值为0.05 10~(-3)μm~2,最大值为953 10~(-3)μm~2,均值为95.57 10~(-3)μm~2。基于“岩芯刻度测井”,采用非线性BP人工神经网络,建立了双坨子气田泉三段单井测井储层参数精细解释模型。研究区5口取芯井神经网络预测孔隙度平均绝对误差为0.73%,渗透率平均相对误差为45.89%,误差较小。
通过对泉三段单井储层级别的划分及统计,得出泉三段主要发育Ⅰ类和Ⅱ类储层,储层以发育“中高孔—中渗型”为主。分析泉三段Ⅸ砂层组的砂体厚度平面图,沉积相控制着储层的发育,储层主要发育在边滩、天然堤微相中。顺着东西向剖面,储层随着河道的摆动迁移而发生变化,顺着河道的方向,储层的连通性是比较好的,呈现条带状形态。
在综合研究该区地质特征的基础上,利用Petrel软件建立了泉三段的构造模型、框架模型、砂组框架模型。采用序贯指示模拟算法建立了泉三段砂泥岩相模型。在数据分析及得到的变差函数模型基础上,在砂泥岩相控制下,进行孔隙度模拟得到双坨子气田泉三段的孔隙度模型,渗透率的模拟以孔隙度为第二变量,进行协同模拟得到双坨子气田渗透率分布模型,利用岩相对其约束,进行双坨子气田含气饱和度模拟。建模结果表明:双坨子气田泉三段的储层总体表现为“中高孔—中渗型”特征,孔隙度、渗透率的分布受到砂泥岩相的明显控制。最后根据建模成果计算得到的双坨子气田泉三段天然气地质储量为8.51亿方。
From the current productivity of Shuang Tuozi gas field, it is can been seen that the pressure dropping quickly in some gas well of gas pool, the gas productivity declining quickly and the water production are directly affected the stable production of the gas pool. The reservoir geological modeling research is the key for the development phase, the necessary parameter for the numerical simulation of reservoir, the directly basis for the development and adjustment program. Establishing the geological modeling correctly reflected geological characteristic of reservoir is the key for the reservoir numerical simulation and dynamic prediction., has important significance for the further understanding the geological characteristic of reservoir and adjusting the development program in order to reach the purpose of improving the recovery ratio. In this paper, it is using the core data, geologic information, logging data to analysis the sedimentary facies of Quan III member of Shuan Tuozi gas field, fine logging interpretation model on reservoir parameters and research on the reservoir characteristic. Finally it is using the above research results to establish the reservoir geological model of Quan III member in Shuang Tuozi gas field.
Based on the borehole log, core and log data, it is identified and classified the microfacies of the single well of Quan III member and composed the sedimentation map of III sand set of Quan III member. Then it is summarized the sedimentation model The Quan III member develops snaking stream. The snaking stream is composed of riverbed, marginal bank, crevasse splay, flood plain and so on. The marginal bank is the mostly developed in the Quan III member.
The statistics of petrophysical data tested using the core shows that the minimum value of the porosity is 4.4%, the maximum value of the porosity is 27.7% and the average value of the porosity is 19.15% and the minimum value of the permeability is 0.05 10~(-3)μm~2, the maximum value of the permeability is 953 10~(-3)μm~2, the average value of the permeability is 95.57 10~(-3)μm~2. On the basis of the principal of core scale the log, it is established the fine interpretation model of reservoir parameter of single well of Quan III member in the Shuang Tuozi gas field using the non-linear BP artificial neural network. The mean absolute error of the predicted porosity by the neural network is 0.73% and the mean relative error of the predicted permeability by the neural network is 45.89% of the 5 core-well in the studied area. The result shows that the error is minimum.
Through the classifying and calculating the reservoir degree of single well of Quan III member, it is obtained that it is mainly developed the I type and II type in the Quan III member. The study demonstrates that it is the medium-large porous- and medium penetrative reservoir in the Quan III member. Through the sand body’s thickness map of the mainly productivity IX sand set of Quan III, it is reached that sedimentary facies controls the reservoir’s development and reservoir is mainly mainly developed in the marginal bank and natural bank. Along with east-western section, the sand body changed along with the deviating and moving of the river channel. And along with the direction of river channel, the connectivity of the reservoirs is relatively good and the shape is banding.
On the basis of comprehensive study of the geologic feature in this area, it is used the Petrel Software to established the structural model, skeleton model and sand set skeleton model of the Quan III member. Using the sequential indication simulated algorithm, it is established the sand-mud lithofacies model of the Quan III member. Based on the data analyses and variation function and under the control of sand-mud lithofacies, it is reached the porosity model after simulation. Using the porosity as the second variable and with the synergistic simulation, it is established the permeability model. By the means of controlling under lithofacies, it is established the saturation model. The model is demonstrated that the characteristic of reservoir is medium-large porosity and medium permeability. And the distribution of the porosity and permeability is under the control of lithofacies. Finally, it is counted that the gas in place is 8.51 billion square of the Quan III member in the Shuang Tuozi gas field in accordance with result of model.
引文
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