Point Bar Numerical Simulation and Results Analysis of x-Unit in the Daqing Oilfield D Block

2013 ◽  
Vol 321-324 ◽  
pp. 890-893
Author(s):  
Dong Zhang ◽  
Bai Quan Yan ◽  
Er Shuang Gao
Keyword(s):  
Numerical Simulation ◽  
History Matching ◽  
Water Displacement ◽  
Injection Wells ◽  
Point Bar ◽  
Oil Saturation ◽  
Splitting Factor ◽  
Remaining Oil ◽  
Oil Water ◽  
Oilfield Development

Point bar reservoir is the key development object in the late stage of oilfield development at present. In this paper, numerical simulation is done on the basis of the point bar architecture in the modeling of the point bar. Through dynamic data generating simulated well history and acquiring X-unit splitting factor, history matching is done on this basis. The numerical simulation results reveal that oil saturation has belt distribution characteristics on the pane due to the lateral accretion interlayer affect to the oil-water displacement; injection wells transverse spread is limited by the lateral accretion interbed control; by lateral accretion interlayer updip pinchout control, the remaining oil is mainly located in the middle and upper part of the lateral accretion [1,2]. Because of the above characteristics, taking horizontal wells to develop the top remaining oil of point bar has been very good results. And it has been confirmed by the further results of the numerical simulation.

Numerical Simulation of the Buried Hill Reservoir in Bohai Bay

2013 ◽  
Vol 448-453 ◽  
pp. 4003-4008
Author(s):  
Kai Jun Tong ◽  
Yan Chun Su ◽  
Li Zhen Ge ◽  
Jian Bo Chen ◽  
Ling Ling Nie
Keyword(s):  
Numerical Simulation ◽  
History Matching ◽  
Numerical Models ◽  
Bohai Bay ◽  
Fractured Reservoir ◽  
Fracture Characterization ◽  
Oil Distribution ◽  
Remaining Oil ◽  
Remaining Oil Distribution ◽  
Buried Hill

Buried hill reservoir fracture description and reservoir simulation technology have been a hot research, but also is one of the key issues that restrict the efficient development of such reservoirs. Based on JZ buried hill reservoir which heterogeneity is strong, some wells water channeling fast and difficult to control the situation for fracture affect, a typical block of dual medium reservoir numerical models which was comprehensive variety of information, discrete fracture characterization and geological modeling is established. The fractured reservoir numerical model is simulated through Eclipse software to seek the law of remaining oil distribution. Through the reservoir geological reserves and production history matching, the remaining oil distribution of main production horizon is forecasted. On this basis, the results of different oilfield development adjustment programs are predicted by numerical simulation.

A Study on the Lateral Accretion Body Potential Tapping of the Point Bar

2013 ◽  
Vol 838-841 ◽  
pp. 863-866
Author(s):  
Hong Zhao
Keyword(s):  
Horizontal Wells ◽  
River Sand ◽  
Point Bar ◽  
Meandering River ◽  
Oil Distribution ◽  
Abandoned Channel ◽  
Sand Body ◽  
Remaining Oil ◽  
Body Potential ◽  
Oilfield Development

The channel sand in PI3132 units of A area in Daqing oilfield is meandering river sand body. Although more than 90 percent of it is watering out, the serious heterogeneity in layers make it possible that there are plenty of remaining reserves in unwashed or low-washed segments in water flooded layers. All these two kinds of remaining oil are the main potential tapping objectives in later period of oilfield development.The writer deeply analyzed the point bar sand body of the meandering river, established the recognizing method of the abandoned channel and the lateral accretion body of point bar, understood the remaining oil distribution in the washed segments and unwashed segments of the thick oil layers. By implementing the Personalized treatments for individual wells,such as super-short radius horizontal wells drilling,waterflood depth profile controlling,cyclic injecting and producing, etc, the point bar sand body potential tapping technology for different formation cause has been established. And this has essential meaning to direct the oilfield development.

scholarly journals A New Measurement of Anisotropic Relative Permeability and Its Application in Numerical Simulation

Energies ◽  
2021 ◽  
Vol 14 (16) ◽  
pp. 4731
Author(s):  
Congcong Li ◽  
Shuoliang Wang ◽  
Qing You ◽  
Chunlei Yu
Keyword(s):  
Numerical Simulation ◽  
Relative Permeability ◽  
Residual Oil ◽  
Displacement Efficiency ◽  
Two Phase ◽  
Oil Saturation ◽  
Residual Oil Saturation ◽  
Displacement Direction ◽  
Oil Water ◽  
The Law

In this paper, we used a self-developed anisotropic cubic core holder to test anisotropic relative permeability by the unsteady-states method, and introduced the anisotropic relative permeability to the traditional numerical simulator. The oil–water two-phase governing equation considering the anisotropic relative permeability is established, and the difference discretization is carried out. We formed a new oil–water two-phase numerical simulation method. It is clear that in a heterogeneous rock with millimeter to centimeter scale laminae, relative permeability is an anisotropic tensor. When the displacement direction is parallel to the bedding, the residual oil saturation is high and the displacement efficiency is low. The greater the angle between the displacement direction and the bedding strike, the lower the residual oil saturation is, the higher the displacement efficiency is, and the relative permeability curve tends towards a rightward shift. The new simulator showed that the anisotropic relative permeability not only affects the breakthrough time and sweep range of water flooding, but also has a significant influence on the overall water cut. The new simulator is validated with the actual oilfield model. It could describe the law of oil–water seepage in an anisotropic reservoir, depict the law of remaining oil distribution of a typical fluvial reservoir, and provide technical support for reasonable injection-production directions.

scholarly journals Comprehensive correction method of airtight coring saturation based on core classification

2021 ◽  
Vol 25 (6 Part A) ◽  
pp. 4153-4160
Author(s):  
Junjie Dong ◽  
Rui Deng
Keyword(s):  
Water Saturation ◽  
Correction Method ◽  
Comprehensive Analysis ◽  
Production Well ◽  
Oil Saturation ◽  
The Core ◽  
Split Method ◽  
Remaining Oil ◽  
Oil Water ◽  
Core Classification

The indoor comprehensive analysis of core saturation of airtight coring wells is an important part of well logging interpretation. According to the saturation data, the geological reserves can be accurately calculated, and the remaining oil saturation and water-flooded zone in the later stage of the production well can be accurately evaluated. Due to the influence of many factors in the coring process and the experiment process, the sum of the core oil and water saturation is usually not equal to 100%. At present, conventional airtight coring correction method is generally to analyze the oil-water saturation, and then correct the data of the same factors that affect the results. This article combines two methods for saturation correction of XX oilfield in China. For cores with consistent missing factors, mathematical statistics are used to correct the saturation. When most of the rock pores have irreducible water and remaining oil, the phase percolation split method is used for the correction after the experimental analysis. By comparing with the logging interpretation results and the results of adjacent wells, the feasibility of the comprehensive correction method can be verified.

Oil Saturation Log Prediction Using Neural Network in New Steamflood Area

2020 ◽  
Author(s):  
A. Syahputra
Keyword(s):  
Neural Network ◽  
Water Saturation ◽  
Prediction Method ◽  
Neural Model ◽  
Training Model ◽  
Acquisition Time ◽  
Oil Saturation ◽  
Full Field ◽  
Remaining Oil ◽  
Observation Wells

Surveillance is very important in managing a steamflood project. On the current surveillance plan, Temperature and steam ID logs are acquired on observation wells at least every year while CO log (oil saturation log or SO log) every 3 years. Based on those surveillance logs, a dynamic full field reservoir model is updated quarterly. Typically, a high depletion rate happens in a new steamflood area as a function of drainage activities and steamflood injection. Due to different acquisition time, there is a possibility of misalignment or information gaps between remaining oil maps (ie: net pay, average oil saturation or hydrocarbon pore thickness map) with steam chest map, for example a case of high remaining oil on high steam saturation interval. The methodology that is used to predict oil saturation log is neural network. In this neural network method, open hole observation wells logs (static reservoir log) such as vshale, porosity, water saturation effective, and pay non pay interval), dynamic reservoir logs as temperature, steam saturation, oil saturation, and acquisition time are used as input. A study case of a new steamflood area with 16 patterns of single reservoir target used 6 active observation wells and 15 complete logs sets (temperature, steam ID, and CO log), 19 incomplete logs sets (only temperature and steam ID) since 2014 to 2019. Those data were divided as follows ~80% of completed log set data for neural network training model and ~20% of completed log set data for testing the model. As the result of neural model testing, R2 is score 0.86 with RMS 5% oil saturation. In this testing step, oil saturation log prediction is compared to actual data. Only minor data that shows different oil saturation value and overall shape of oil saturation logs are match. This neural network model is then used for oil saturation log prediction in 19 incomplete log set. The oil saturation log prediction method can fill the gap of data to better describe the depletion process in a new steamflood area. This method also helps to align steam map and remaining oil to support reservoir management in a steamflood project.

A New Method of Fall-Off Test in Water Injection Well in Tahe Oilfield

2013 ◽  
Vol 807-809 ◽  
pp. 2508-2513
Author(s):  
Qiang Wang ◽  
Wan Long Huang ◽  
Hai Min Xu
Keyword(s):  
Water Injection ◽  
Injection Well ◽  
Well Test ◽  
Well Bore ◽  
Residual Oil ◽  
Injection Wells ◽  
Oil Saturation ◽  
Tahe Oilfield ◽  
Fitting Method ◽  
Front Radius

In pressure drop well test of the clasolite water injection well of Tahe oilfield, through nonlinear automatic fitting method in the multi-complex reservoir mode for water injection wells, we got layer permeability, skin factor, well bore storage coefficient and flood front radius, and then we calculated the residual oil saturation distribution. Through the examples of the four wells of Tahe oilfield analyzed by our software, we found that the method is one of the most powerful analysis tools.

Numerical simulation of hydrate slurry flow behavior in oil-water systems based on hydrate agglomeration modelling

2018 ◽  
Vol 169 ◽  
pp. 393-404 ◽  
Author(s):  
GuangChun Song ◽  
YuXing Li ◽  
WuChang Wang ◽  
Kai Jiang ◽  
Zhengzhuo Shi ◽  
...  
Keyword(s):  
Numerical Simulation ◽  
Flow Behavior ◽  
Water Systems ◽  
Slurry Flow ◽  
Oil Water

A high precision computing method for heat transfer in the process of oil-water displacement

2021 ◽  
Vol 33 (5) ◽  
pp. 958-969
Author(s):  
Pan-pan Han ◽  
Ke Chen ◽  
Dong-xi Liu ◽  
Yun-xiang You ◽  
Jin Wang
Keyword(s):  
Heat Transfer ◽  
High Precision ◽  
Water Displacement ◽  
Oil Water ◽  
Computing Method
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