注采单元地层结垢机理及数值模拟研究

李年银; 康佳; 张昊天; 陶卫东; 任屹

doi:10.13809/j.cnki.cn32-1825/te.2019.04.004

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注采单元地层结垢机理及数值模拟研究
Study on mechanism and numerical simulation of formation scaling in injection-production unit
2019年第4期页码：19-25
纸质出版：2019
DOI： 10.13809/j.cnki.cn32-1825/te.2019.04.004
稿件说明：

移动端阅览

李年银, 康佳, 张昊天, 等. 注采单元地层结垢机理及数值模拟研究[J]. 油气藏评价与开发, 2019,(4):19-25. DOI： 10.13809/j.cnki.cn32-1825/te.2019.04.004.

LI Nianyin, KANG Jia, ZHANG Haotian, et al. Study on mechanism and numerical simulation of formation scaling in injection-production unit[J]. Petroleum Reservoir Evaluation and Development, 2019, (4): 19-25. DOI： 10.13809/j.cnki.cn32-1825/te.2019.04.004.

摘要

注水开发是确保油田持续稳产

提高原油采收率最经济、有效的措施之一。然而长期的注水开发过程中地层结垢不可避免

严重影响和制约油田开发效果。以注采单元为研究对象

基于热力学及溶度积规则等理论

考虑地层温度、压力、成垢离子浓度以及流速等因素的影响

建立了注采单元地层结垢数值模型

包括压力场模型、温度场模型、孔隙度与渗透率分布模型以及地层结垢模型

并根据油田实际生产数据

运用MATLAB数学模拟软件进行实例模拟

分析各因素对注采单元内结垢总量、结垢范围、结垢量分布以及地层结垢对视吸水指数和渗透率的影响。结果表明

注水井近井地带温度较低

溶解平衡常数较小且流速大

难以结垢;径向往外

地层温度升高

注入水的流速大幅减缓

最易成垢;继续往外

成垢离子浓度低于最小结垢浓度时

不再结垢。

Abstract

Water flooding is one of the most economical and effective measures for the sustainable and stable production of oil field and EOR（enhance oil recovery）. However

formation scaling is inevitable in the process of long-term water flooding

which seriously affects and restricts the effect of oil field development. Taking injection-production unit as the research object

based on thermodynamic theory and solubility product rule

and considering the influence of formation temperature

pressure

scaling ion concentration and flow rate

the numerical models of formation scaling in injection-production unit was established

including pressure field model

temperature field model

porosity and permeability distribution model and formation scaling model. Meanwhile

according to the actual production data of oil field

mathematical simulation software—MATLAB—was used to carry out the case to analyze the influence of each factor on the total scaling amount

scaling range

distribution of scaling quantity and formation scaling on apparent water absorption index and permeability in injection-production unit. The results showed that the temperature of the immediate vicinity of the injection wells was low

the dissolution equilibrium constant was small and the flow rate was high

so that scaling was difficult. When in radial outward direction

the formation temperature increased

and the flow rate decreased greatly

which made it the most easy condition for scaling. Continue outward

when the scaling ion concentration was lower than the minimum scaling concentration

scale would no longer form.

关键词

Keywords

references

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Petroleum Engineering Department, Khalifa University of Science and Technology, Abu Dhabi, United Arab Emirates,Petroleum Engineering Department, Khalifa University of Science and Technology, Abu Dhabi, United Arab Emirates,Petroleum Engineering Department, Khalifa University of Science and Technology, Abu Dhabi, United Arab Emirates.Geochemical modeling of engineered water injection effect on oil recovery from carbonate cores[J].Journal of Petroleum Science and Engineering,2018.

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David Hasson,Andrei Cornel.Effect of residence time on the degree of CaCO3 precipitation in the presence of an anti-scalant[J].Desalination,2017.

Geoffrey Thyne,Patrick Brady.Evaluation of formation water chemistry and scale prediction: Bakken Shale[J].Applied Geochemistry,2016.

Qihong Feng,Hongwei Chen,Xiang Wang,Sen Wang,Zenglin Wang,Yong Yang,Shaoxian Bing.Well control optimization considering formation damage caused by suspended particles in injected water[J].Journal of Natural Gas Science and Engineering,2016.

Xiaoxi Yang,Wei Li,Longjiang Guo,Xiaojie Liu,Hongqing Feng.Prediction of CaCO 3 scaling in water injection wellbore[J].Applied Thermal Engineering,2016.

Jun Xie,Zheming Zhu,Rong Hu,Jianjun Liu.A calculation method of optimal water injection pressures in natural fractured reservoirs[J].Journal of Petroleum Science and Engineering,2015.

N. Wang,D.Z. Chen,L.S. Zou.Influence of non-thermal plasma pre-treatment on the scaling characteristics of viscous oil wastewater during evaporation[J].Applied Thermal Engineering,2015.

Ali Haghtalab,Mohamad Javad Kamali,Abbas Shahrabadi.Prediction mineral scale formation in oil reservoirs during water injection[J].Fluid Phase Equilibria,2014.

Yunjiao Fu,Wolfgang van Berk,Hans-Martin Schulz.Temporal and spatial development of scale formation: One-dimensional hydrogeochemical transport modeling[J].Journal of Petroleum Science and Engineering,2013.

S.M. Peyghambarzadeh,A. Vatani,M. Jamialahmadi.Application of asymptotic model for the prediction of fouling rate of calcium sulfate under subcooled flow boiling[J].Applied Thermal Engineering,2011.

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M. Salman,H. Qabazard,M. Moshfeghian.Water scaling case studies in a Kuwaiti oil field[J].Journal of Petroleum Science and Engineering,2006(1).