Results Of Seismic Interpretation Research Articles

First results of stratigraphic drilling in the North-Eastern Laptev Sea

The Stratigraphic Drilling Project of the Russian Arctic Shelf conducted by the PJSC Rosneft is aimed at discover the stratigraphic age and rock composition of sedimentary succession of its subsurface. In 2021, six shallow wells for the first time have been drilled with core sampling in the east of the Laptev Sea. Drilling revealed folded sedimentary succession dated back to the Late Barremian – Early Aptian. The synrift complex overlying unconformably dates to the Paleocene. The upper strata dates from Eocene to Pleistocene and contains significant hiatuses. The data discovered together with the results of seismic interpretation clarified the regional geological model and dated the stages of its tectonic evolution.

Use of spectral decomposition in identifying stratigraphic baffles below seismic resolution; A case study of UTB field, offshore Niger Delta

During a reservoir characterization study of the UTB field, Niger Delta, a 20-psi pressure difference was observed between two wells, X6 and X8, drilled into the F1 reservoir. Initial seismic interpretation results showed no flow barriers between the wells that would have caused this difference. In order to solve this problem, we attempted using conventional attribute analysis. However, this approach was ineffective as it was unable to highlight any flow barrier in the form of baffles. As a way forward, we deploy spectral decomposition, an advanced attribute analysis method, capable of imaging these subtle features. This study therefore demonstrates application of advanced spectral decomposition technique in resolving the stratigraphic baffles in the F1 reservoir. Two algorithms, including Short Time Fourier Transform (STFT) and Continuous Wavelet Transform (CWT), were adapted for identifying and delineating the hydraulic flow barriers. Analysis of frequency map revealed potential faults, thickness, lateral lithology variations, as well as hydraulic flow barriers within the reservoir. The modular formation dynamic tester (MDT) pressures, together with an understanding of the reservoir's geology, were integrated to validate and interpret the results of the spectral decomposition. The frequency maps between 10 Hz −26 Hz show the pay zone of the F1 reservoir as a continuously connected hydrocarbon pool. We interpreted them as shale baffles, forming the flow barriers that resulted in the pressure differential between the two wells. Thus, the spectral decomposition tool as applied in this study is a robust and cost-effective way to identify intra-reservoir and sub-seismic compartmentalization without drilling additional wells.

Overview of seismic stratigraphic referencing methods in conditions of limited or substandard set of initial well data

Background: Well tying is an integral part of seismic interpretation both at the stage of structural and dynamic analysis. Linking seismic and well data is a critical process that allows you to link geological objects identified from seismic data with actual data obtained from wells, because. it is based on the relationship between the lithological composition of the deposits that make up the section under study and the characteristics of the reflections. Seismic data are in most cases presented on a time scale, while well data are on a depth scale, and in order to calibrate them, it is necessary to select a velocity law and establish a time-depth relationship.
 Aim: This article aims to deepen the understanding of the importance of quality control of initial well data to improve the result of seismic stratigraphic tying and increase the efficiency of geological exploration, as well as to propose methods to improve the quality and efficiency of tying..
 Materials and methods: Methods for correcting the readings of acoustic logging are described, various algorithms for tying seismic and well data are given.
 Results: The paper considers the reasons for the distortion of the values of the initial well data, examples of data quality analysis, suggests options for how to conduct a seismic stratigraphic tie in the conditions of a limited or initially substandard set of initial data and obtain reliable depth-velocity dependences for wells.
 Conclusion: Conducting quality control and, if necessary, correcting the original well data is a critical step to improve the accuracy of the final results of seismic interpretation. It is important to note that even with limited and low quality input data, it is possible to obtain depth-time dependencies. However, the results of the work show that editing and amending the original logs significantly improve the quality and detail of the seismic stratigraphic tie.

Different roles of tectonic events in the development history of the coastal Tanzania basin: remote sensing mapping and seismic interpretation results, and their implications for petroleum prospectivity

Different roles of tectonic events in the development history of the coastal Tanzania basin: remote sensing mapping and seismic interpretation results, and their implications for petroleum prospectivity

Numerical investigation of fracture interference effects on multi-fractures propagation in fractured shale

Since fracture morphology is jointly influenced by inter-cluster interference and natural fractures, multi-cluster fracture propagation behaviors are complicated during staged volume fracturing. Although there are many studies on complex fracture propagation, the engineering-scale investigation of multi-cluster fracture interactive propagation behaviors is still needed. In this paper, a coupled fracture propagation PF model is developed and an engineering-scale natural fracture characterization method based on seismic interpretation results is introduced. The effectiveness of the model is validated by comparing fracture propagation behaviors with the fracturing experimental result, and this model is applied to study interactive behaviors of multi-cluster fractures in fractured shale. The results indicate that inter-cluster stress interference affects the induced stress field and leads to merging, diverting, and restraining fracture behaviors, activating NFs can effectively reduce the interference and is beneficial for forming complex fractures, and the NF occurrence is a decisive factor that affected fracture morphologies. To enhance the stimulation efficiency, the fracturing mode with multi-cluster and close-spacing is recommended for fractured shale stimulation.

Coalbed methane enrichment prediction and resource estimation for the areas with different tectonic complexities

Geological tectonic movement plays a controlling role in the distribution pattern of coalbed methane (CBM) resources. The traditional CBM resource estimation methods use the measured CBM as the overall CBM content and do not consider the influence of geological structure on the nonuniform distribution of CBM resources. In this paper, the geological structure of the Guojiahe coalfield in the northern Yonglong mining area, China, was used as the research background. Based on the precise three-dimensional (3D) seismic interpretation results of the coal seam geological structure and the tested CBM contents at sampling points, a fuzzy comprehensive evaluation method was used to classify the tectonic complexity of the study area, and the CBM contents of different tectonic locations in the tested coal seams and the results determined by the finite element method were analyzed. On this basis, a quantitative relationship between the tectonic complexity index and the amount of CBM resources was established, and finally, a CBM-enrichment prediction model and a CBM resource estimation method for areas with different tectonic complexities were proposed. The agreement between the amount of CBM resources obtained by the estimation method and the actual exploration result is 85.2%; therefore, the proposed method has a theoretical guidance and engineering application value for the exploration and precise development of CBM resources.

Microgravity Monitoring in Fractured-Vuggy Carbonate Reservoirs

With the development of Tahe Oilfield entering the high water cut stage, gas channeling occurs in fractured-vuggy system during nitrogen injection, resulting in some inefficient wells. To improve the development effect of gas flooding, how to define the distribution of fracture, vuggy, and remaining oil has become one of the urgent problems to be solved at present. Microgravity monitoring technology uses high-quality data, the residual gravity anomaly of the target layer is obtained by depth recursion processing, the density distribution of the target layer is obtained by layer density inversion, and the fractured-vuggy distribution is depicted by edge detection. The results show that the lower part of the fractured-vuggy system in the north is connected to the middle, while the fractured-vuggy system in the south is directly connected to the middle, which leads to different effects of injected nitrogen. The early injected nitrogen in the SX area is mainly distributed in the north. Nitrogen injection in the north needs to reach a certain amount of gas before the middle can be effective. Nitrogen is injected in the south, and the central part is effective quickly. The research results provide a basis for adjusting injection-production scheme and improving reservoir development effect. Compared with the production performance and seismic interpretation results, it verifies the accuracy of ultradeep microgravity monitoring in depicting the development of fractured-vuggy system, which provides a new technology and idea for characterizing fractured-vuggy carbonate reservoirs.

Biogenic gas – “from drilling hazard to promising future hydrocarbon resource”: Study of Mamberamo Frontier Basin, North Papua, Indonesia

Biogenic gas was previously considered as a drilling hazard before it has become captivating with competitive price and due to high demand. This study was done to diagnose rock formations which are prospective match up to revolutionary hydrocarbon system variables and to cast up volume estimation. The North Papua Basin, which classified as a foreland (hybrid) basin, is reckoned to have significant gas potentials from well data compliments Pleistocene Mamberamo sandstone with robust biogenic gas parameters, high methane composition (99-100%) and low CO2, H2S or N2 contents. Rapid sedimentation and low geothermal gradient play great role to establish effective biogenic gas system, followed by young-aged reservoir parameter. Field data comprise of soil gas sample supports geochemical investigation. Petrophysical and seismic interpretation results, as follow, are applied to assist volumetric calculation and uncertainty analysis using Monte Carlo simulation. Source rock evaluation from two wells reveals that Mamberamo Member D layer as the target is highly potential to become good source rock and storage of biogenic gas system in the area. The Monte Carlo simulation draws adequate correlation linking P50 (the most likely case) to the highest cumulative frequency in CDF curves, and testifies reasonable volumetric and resource calculation to be considered.

Cretaceous volcanism and intrusive magmatism features in the Mendeleev Rise region (Arctic Ocean) according to seismic data

The current paper is based primarily on the interpretation of 2D seismic lines for the Amerasian Basin. A synrift complex has been identified in half-grabens almost everywhere within the Alpha-Mendeleev Rise and conjugate basins according to the results of seismic data interpretation. Various magmatism features within the synrift complex have been identified on seismic profiles: plateau basalts; sills and dikes; reflections similar to SDRs (Seaward Dipping Reflectors Sequences) and volcanoes. Regional extension and synchronous widespread magmatism are probably associated with the formation of the High Artic Large Igneous Province (HALIP) in the Aptian-Albian. Considering the data on the isotope ages of igneous rocks for the Mendeleev Rise, it is assumed that the top of the synrift complex has an approximate age of 100 Ma and the bottom has an approximate age of 125 Ma. The Alpha-Mendeleev Rise was formed simultaneously with conjugate basins in the Aptian-Albian. An axial line can be drawn along the Alpha-Mendeleev Rise. To the west of the axial line, reflections similar to SDRs dip towards the Podvodnikov basin. To the east of the axial line, reflections dip towards the Toll, Mendeleev, Nautilus and Stefansson basins. The reflections converge in the central parts of the basins. The Alpha Mendeleev Rise is a double-sided volcanic passive continental margin. The Podvodnikov, Toll, Mendeleev, Nautilus, and Stefansson basins are rift basins with thinned continental crust at the base. Their development was interrupted before the start of spreading and the oceanic crust formation.

Prediction of Overpressure Zones in Marine Sediments Using Rock-Physics and Other Approaches

The paper discusses the problem of localizing zones of high pore pressure in sub-bottom sediments (first tens of meters under the seafloor). Prediction of the overpressure zones in the near-surface is required for the mitigation of risks at the early stages of the offshore hydrocarbon field exploration and development. The results of seismic data interpretation generally serve as the main source of information for this kind of problems, yet there are other methods to predict overpressure zones in the subsurface. The paper presents the results of the overpressure zone prediction using a set of methods including empirical ones, and the approach based on rock-physics modeling that features the soft-sand model of unconsolidated media effective properties. While the rock-physics modeling grants the most reliable result, it is also the most demanding method to the input data. Hence, it can be used to verify other methods of the overpressure zone prediction. We present the results of the overpressure zone prediction at the research site on the Black Sea shelf. The mitigation of the drilling risks via changing the drilling conditions is discussed in detail. As the drilling through the overpressure zones is often a necessity, the engineering solutions proposed in the paper can be applied elsewhere when facing similar problems typical for offshore exploration.

3D Geological Modelling for Asmari Reservoir In Abu Ghirab Oil Field

Building a geological model is an essential and primary step for studying the reservoir’s hydrocarbon content and future performance. A three-dimensional geological model of the Asmari reservoir in Abu- Ghirab oil field including structure, stratigraphy, and reservoir petrophysical properties, has been constructed in the present work. As to underlying Formations, striking slip faults developed at the flank and interlayer normal. Abu Ghirab oilfields are located on the eastern anticlinal band, which has steadily plunged southward. 3D seismic interpretation results are utilized to build the fault model for 43 faults of the Asmari Formation in Abu Ghirab Oilfield. A geographic facies model with six different rock facies types are developed. This new modelling system should be capable of more clearly reflecting the connectivity of the oil body and the heterogeneity of the reservoir. To represent the vertical and horizontal heterogeneity and create a framework for the Asmari reservoir in the Abu Ghirab oil field, the Petrel software has been used to create a reservoir in a 3D model. This model was constructed using data from 55 wells located across the Asmari formation. The model demonstrates accurate estimations (porosity, saturation, and net to gross). These reservoir models directly impact the facies model’s computation of each layer of the net pay thickness of the reservoir. The final goal of the present work is to determine the initial oil in place (IOIP), which is found to be 269*106 sm3.

Tracer analysis in flow channel characterization and modelling of gas and CO2 injection EOR in unconventional reservoirs

A large amount of unproduced oil remains in unconventional shale reservoirs. In this paper we present the use of water and oil tracers as a key factor in flow channel characterization and in constructing a viable numerical model to forecast oil and gas recovery by depletion drive and enhancing oil recovery (EOR) by hydrocarbon gas or CO2 injection in Niobrara and Codell formations in the Denver-Julesburg (DJ) Basin. First, a dual-porosity compositional model was built based on seismic interpretation results, well logs, and core analysis. Two hydraulic fracture scenarios, (1) uniform dimensions and (2) variable dimensions, were included in the static rock frame of the numerical model. Production performance matching demonstrated that the use of variable length and height for hydraulic fractures led to a more realistic representation of the reservoir performance. On another front, injection of water and oil tracers and flowback analysis provided the means to better quantify the fracture network distribution, flow communication between wells, and hydraulic fracture performance in each well. Finally, two ‘huff-and-puff’ (injection, shut-in, production) cycles of lean gas and CO2 injection into the reservoir were modeled to assess EOR potential of cyclic gas injection. With identical gas injection rates, lean gas produced more oil than CO2; however, CO2-EOR modeling results indicated that a substantial amount of CO2 was stored in the reservoir. The net carbon stored after CO2-EOR was approximately 13% of the injected CO2 and CO2 utilization was 39,000 scf per incremental oil barrel produced which is much larger than the average CO2 utilization of about 12,000 scf per incremental oil barrel produced in conventional reservoirs. However, the produced CO2 from unconventional reservoir EOR operation can be recycled to achieve complete storage of CO2 — rendering CO2-EOR an effective means of decarbonization. Finally, transmissibility analysis of an existing major fault zone in the study area indicated that CO2 did not leak via a major fault in the study area nor via the associated nearby natural fractures in the study area.

Tectonostratigraphic evolution of a rift basin and corresponding source-to-sink systems: Implications for the western Bohai Bay Basin, North China

The Bohai Bay Basin, a typical intracontinental rift basin, records East Asia's kinematic plate history during the Cenozoic. The rifting process was driven by the counterclockwise rotation in the direction of the Pacific Plate subduction. From the early Eocene to the Oligocene, the rifting process can be divided into three stages: extension initiation, peak extension, and post-extension. The corresponding rifting rate was calculated based on 40Ar-39Ar data. Then, the provenance area evolution of the above three rifting stages was established by combining the detrital zircon U–Pb data and heavy mineral assemblage data (ZTR, GZi, and ATi). According to the results calculated by 40Ar/39Ar analysis, the topography of the sink area in the western Bohai bay basin was characterized by moderately rising subsidence rates (100 m/Ma) during the extension initiation stage (Paleocene-Early Eocene), when surface drainage was restricted to a limited area with steep channel slopes. During this stage, referring to the core description and seismic interpretation results, the fan delta distributes most of the sediment, most of which migrates from the proximal region. Until the peak extension stage, the source-sink system develops as the rate of subsidence increases (200 m/Ma), making the sink area larger, and this period involves multiple types of pathways, including synsedimentary faults and erosional valleys. Sediments from Taihang Massif and Jiaoliao Massif infill the subsidence zone at the distal end. Then, in the post-extension stage, the source-sink systems involve a multi-provenance area (i.e., sourcing from both proximal and distal areas), a large sink area, and a gentle channel gradient due to a decrease in subsidence rate (60–80 m/Ma). Catchment relief, sediment migration distance, and average fault displacement were used, and these parameters were related to the sediment supply (Qs) for the three rifting stages. We find that during extension initiation and peak extension, the source-to-sink systems show a high amount of sand influx (Qsand/) and that the ratio Qsand/Qs total shows a proportional relationship with catchment relief and average fault displacement; this relationship is inversely proportional to the catchment-unit area. Also, according to the types of pathways, we classified the source-to-sink systems during this period into three types, steep eroded pathway (Type-I S2S), gentle slope developed with several boundary faults (Type-II S2S), steep slope with observably eroded valleys or fault-troughs (Type-III S2S). The ratio of Qsand/Qs is only related to the sediment migration distance and average fault displacement in the post-extension stage. Besides the above three types of source-to-sink systems, we found that multi-stage faults developed along the slope (Type-IV S2S) predominated during this stage.

Shape Carving Methods of Geologic Body Interpretation from Seismic Data Based on Deep Learning

The task of seismic data interpretation is a time-consuming and uncertain process. Machine learning tools can help to build a shortcut between raw seismic data and reservoir characteristics of interest. Recently, techniques involving convolutional neural networks have started to gain momentum. Convolutional neural networks are particularly efficient at pattern recognition within images, and this is why they are suitable for seismic facies classification and interpretation tasks. We experimented with three different architectures based on convolutional layers and compared them with different synthetic and field datasets in terms of quality of the seismic interpretation results and computational efficiency. The architectures used in our study were three deep fully convolutional architectures: a 3D convolutional network with a fully connected head; a 2D fully convolutional network, and U-Net. We found the U-Net architecture to be both robust and the fastest when performing classification at the prediction stage. The 3D convolutional model with a fully connected head was the slowest, while a fully convolutional model was unstable in its predictions.

The syn- and post-collision structures related to the Tarim-Qaidam collision: Results of seismic interpretation in the Tarim Basin.

The syn- and post-collision structures related to the Tarim-Qaidam collision: Results of seismic interpretation in the Tarim Basin.

The syn- and post-collision structures related to the Tarim-Qaidam collision: Results of seismic interpretation in the Tarim Basin

位于塔里木盆地南侧的阿尔金山和西昆仑山是特提斯超级造山带最北部的两条缝合带。该处的早古生代造山作用是原特提斯构造演化的重要组成部分。根据地震资料解释在塔里木盆地发现的碰撞相关构造指示,早古生代的碰撞事件发生于塔里木地块的东南侧,是塔里木地块与柴达木地块之间的碰撞造山作用。这次碰撞形成了阿尔金早古生代碰撞造山带。其同碰撞构造主要包括前陆褶皱冲断带(塘沽孜巴斯前陆褶皱冲断带)和大型基底卷入型背斜构造(轮南、塔东和塔中背斜),形成于晚奥陶世-早志留世。碰撞后构造为一系列正断层及其组合成的雁列状张扭性断层带,形成时间是中志留世-中泥盆世。根据塔里木盆地内发现的碰撞相关构造分析,结合造山带内的蛇绿岩和俯冲-碰撞相关岩浆岩、变质岩研究成果推论,作为原特提斯洋分支的古阿尔金洋,其洋壳自晚寒武开始向柴达木地块之下俯冲。至中奥陶世末-晚奥陶世初,洋壳俯冲完毕,古阿尔金洋闭合,塔里木地块-柴达木地块碰撞开始。该碰撞造山作用持续至早志留世末结束,然后进入中志留世-中泥盆世碰撞后应力伸展构造演化阶段。迄今,尚无碰撞相关构造指示塔里木克拉通西南缘曾经发生早古生代碰撞造山事件。早古生代,阿尔金山发生的是增生-碰撞型造山,西昆仑山发生的是增生型造山作用。

Study on reservoir description technology of complex fault block oilfield——Taking the South 1st member of D sag as an example

The D sag has developed faults, serious erosion and fault loss, developed glutamate, strong heterogeneity, and large formation dip, which makes stratigraphic comparison difficult and unclear understanding of oil reservoir and oil-water relationship during the development process. For this reason, this study was carried out. On the basis of the existing seismic interpretation results, carry out the fine structural interpretation of the main sub-layers in the study area; carry out the study of sedimentary characteristics, divide the sedimentary facies, and clarify the sedimentary characteristics of the main sand bodies; use the core analysis data to establish the interpretation of physical parameters in the study area model, and establish a fine three-dimensional geological model, through the study of oil-water distribution law, carry out potential research, and select favorable well-distributed blocks.

Impact of mechanical stratification on the structural style of the Lublin Basin, SE Poland: results of seismic interpretation and implications for quantification of deformation within the frontal parts of thin-skinned fold-and-thrust belts

We demonstrate how lithological and mechanical stratification of Ediacaran–Carboniferous sedimentary package governs strain partitioning in the Lublin Basin (LB) which was incorporated in the marginal portion of the Variscan fold-and-thrust belt. Based on the geometry of seismic reflectors, the pre-Permian–Mesozoic sedimentary sequence was subdivided into two structural complexes differing in structural style. The lower one reveals forelandward-vergent imbrication, while the upper one comprises fold train, second-order deformations, and multiple local detachments. Lithological composition of the upper structural complex controlled geometry, kinematics, and position of compressional deformations in stratigraphic profile. System of foreland-vergent thrusts which links lower and upper detachment developed due to efficiency of simple shear operating in heterogeneous clastic-carbonate-evaporitic strata of the Lower–Upper Devonian age. Internal homogeneity promoted the formation of conjugate sets of thrusts in Silurian shales and Upper Devonian limestones. Structural seismic interpretation combined with sequential restoration revealed localised thickening of Devonian strata and up to 5% difference in length of Devonian horizons. This mismatch is interpreted as a manifestation of distributed shortening, including layer-parallel shortening (LPS), which operated before or synchronously to the initiation of folding. The amount of distributed strain is comparable with numbers obtained in external parts of other fold-and-thrust belts. The outcomes derived from this study may act as a benchmark for studying variability in a structural style of multilayered sequences which were incorporated in the external portion of other fold-and-thrust belts.

Structural characteristics of transtensional fault system and its implication for hydrocarbon accumulation in S Block, South Asia area

Transtensional faults are well developed in the S Block of the South Asia area, which have an important impact on the hydrocarbon accumulation. However, the transtensional fault structure is very complex. Based on drilling and seismic data interpretation results, faults are divided into three typical types in the Lower Cretaceous, which can help to understand the complex fault system. The main faults are distributed in the NNW-SSE direction and parallel arrangement with dextral strike-slip shear characteristics, which determines the development of the tectonic belt. The secondary faults are often associated with the main faults, often composed of multiple branch faults. The complexity of the fault system is further aggravated by the small interlayer faults. Based on balanced crosssection technique analysis, the fault evolution has experienced five geological periods, which is closely related to the Indo-Pakistan plate tectonics and the Indus Basin evolution. In the diagonal extension stage of the Late Cretaceous, the fault activity was very strong, which had a significant impact on the tectonic pattern of "horst-graben structures and locally complex faulted blocks" in S Block. It is found that transtensional fault assemblage patterns are regular and diverse. It consists of six kinds of plane assemblage and seven kinds of profile assemblage patterns. Plane assemblage patterns include en echelon, broom, feather, comb, horsetail and diamond shape, while profile assemblage patterns consist of horst-graben faulted type, consequent faulted type, antithetic faulted type, "Y" and reverse "Y" type, "X" type and negative flower type. Different transtensional fault assemblage patterns form various kinds of hydrocarbon trap types, including faulted block, faulted nose, faulted anticline and composite traps. Fault activity and evolution promote the hydrocarbon generation, control the formation of tectonic zones and favorable traps and play an important control role in hydrocarbon migration and accumulation. Therefore, in this study the main exploration and evaluation targets are faulted reservoirs in the study area.

Geological Modeling Technology and Application Based on Seismic Interpretation Results under the Background of Artificial Intelligence

The development of seismic technology has made seismic data to be widely used in the interpretation of stratigraphic sequence frames, reservoir identification, fluid detection, and other research fields involved in reservoir description. The 3D technology reservoirs have always been the focus, as well as difficulty, of research. With the rapid development of information technology and the continuous improvement of seismic exploration level, people have put forward higher requirements for the accuracy of seismic data interpretation results. Aiming at the large number of structural and unstructured data in seismic, logging, geology, and other disciplines involved in seismic interpretation, how to effectively organize and coordinate analysis to discover the hidden reservoir structure and oil and gas distribution information has always been a geological and important topic for information processing technicians. This thesis is aimed at the current high-water-phase development of Shengtuo Oilfield reservoir and the problems existing in geological research. Based on seismic structural interpretation and attribute analysis, this paper analyzes the reservoir structural characteristics, sedimentary characteristics, and reservoir physical parameter characteristics based on geology, logging interpretation, core analysis, drilling, and seismic interpretation. Using the kriging method with external drift can cooperate with seismic variables to establish a reservoir geological model to study the Shengtuo Oilfield reservoir. We combine artificial intelligence technology with geological modeling technology of seismic interpretation results to explore the best method for predicting earthquakes. The research results in this paper show that the relative error of the model established by the kriging method in the article is relatively small for thinning wells, mainly concentrated around 1%. Examination of the thinning wells of 45 wells shows that the model established is basically good and the example has high accuracy. The research results in this paper have a guiding study of distribution and tapping potentials in the study area, formulating reasonable development and adjustment plans and improving oil recovery.