Research Papers: Petroleum Engineering

Study on Performance Evaluation of Dispersed Particle Gel for Improved Oil Recovery

[+] Author and Article Information
Qing You

Institute of Oil & Gas,
Peking University,
No. 5 Yiheyuan Road,
Beijing 100871, China
e-mail: youqing@pku.edu.cn

Caili Dai

State Key Laboratory of Heavy Oil Processing,
China University of Petroleum,
No. 66 Changjiang West Road,
Qingdao 266580, China
e-mail: dcl306@163.com

Yongchun Tang

e-mail: tang@peeri.org

Ping Guan

e-mail: pguanl@pku.edu.cn
Institute of Oil & Gas,
Peking University,
No. 5 Yiheyuan Road,
Beijing 100871, China

Guang Zhao

e-mail: zhaoguang.sdau@163.com

Fulin Zhao

e-mail: zhaofl@upc.edu.cn
State Key Laboratory of Heavy Oil Processing,
China University of Petroleum,
No. 66 Changjiang West Road,
Qingdao 266580, China

Contributed by the Petroleum Division of ASME for publication in the Journal of Energy Resources Technology. Manuscript received August 21, 2012; final manuscript received March 13, 2013; published online June 24, 2013. Assoc. Editor: Tayfun Babadagli.

J. Energy Resour. Technol 135(4), 042903 (Jun 24, 2013) (7 pages) Paper No: JERT-12-1190; doi: 10.1115/1.4024119 History: Received August 21, 2012; Revised March 13, 2013

This work investigates the performance of dispersed particle gel (DPG) by core flow tests including injectivity, selective plugging, thermal stability, and improved oil recovery (IOR). Results showed that the resistance factor is small when DPG was injected, but obviously became larger while turning into brine water flooding. Both the oil and water relative permeability were reduced and greater reduction appeared in water relative permeability. DPG could block water flow without affecting oil flow, and oil–water segregated flow mechanism was proposed to explain this selective plugging. The injection pressure increases, caused by strong plugging due to the DPG aggregation aging in high temperature, which was consistent with the observation of atomic force microscope (AFM) photos. The DPG could effectively block high permeability zone and produce oil from low permeability zone, which could provide a practical way to enhance hydrocarbon recovery while reducing water production for extremely heterogeneous reservoirs.

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Fig. 1

The morphology of DPG

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Fig. 2

The particle size of DPG

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Fig. 3

The multipoint pressure experimental apparatus

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Fig. 4

The experimental apparatus

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Fig. 5

The oil displacement experimental apparatus

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Fig. 6

The resistance factor change at different sections of sand pack core

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Fig. 7

The relationship of the interaction energy and the distance

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Fig. 8

The schematic of oil–water segregated flow mechanism

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Fig. 9

The injection pressure variation before and after aging at 90  °C

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Fig. 10

The section analysis of DPG after aging

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Fig. 11

Oil displacement result of double sand pack cores (permeability contrast is 2)

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Fig. 12

Oil displacement result of double sand pack cores (permeability contrast is 4)

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Fig. 13

Schematic of DPG to improve oil recovery



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