Formation Damage in Heavy-Oil Formation During Steamflooding

1991 ◽  
Author(s):  
C.U. Okoye ◽  
N.L. Onuba ◽  
A. Ghalambor ◽  
A. Hayatdavoudi
Keyword(s):  
Heavy Oil ◽  
Formation Damage ◽  
Oil Formation

Foamy Oil Formation by Gas Injection and the Effect on Heavy Oil Recovery

2015 ◽  
Vol 33 (7) ◽  
pp. 846-854
Author(s):  
X. Sun ◽  
Y. Zhang ◽  
C. Zhao ◽  
W. Li ◽  
X. Li
Keyword(s):  
Oil Recovery ◽  
Heavy Oil ◽  
Gas Injection ◽  
Heavy Oil Recovery ◽  
Foamy Oil ◽  
Oil Formation

scholarly journals A Multicomponent Thermal Fluid Numerical Simulation Method considering Formation Damage

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-15
Author(s):  
Xinan Yu ◽  
Xiaoping Li ◽  
Shuoliang Wang ◽  
Yi Luo
Keyword(s):  
Numerical Simulation ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Physical Simulation ◽  
Damage Model ◽  
Simulation Method ◽  
Formation Damage ◽  
Thermal Fluids ◽  
Before And After ◽  
Control Equation

Multicomponent thermal fluid huff and puff is an innovative heavy oil development technology for heavy oil reservoirs, which has been widely used in offshore oilfields in China and has proved to be a promising method for enhancing oil recovery. Components of multicomponent thermal fluids contain many components, including carbon dioxide, nitrogen, and steam. Under high temperature and high pressure conditions, the complex physical and chemical reactions between multicomponent thermal fluids and reservoir rocks occur, which damage the pore structure and permeability of core. In this paper, the authors set up a reservoir damage experimental device, tested the formation permeability before and after the injection of multiple-component thermal fluids, and obtained the formation damage model. The multicomponent thermal fluid formation damage model is embedded in the component control equation, the finite difference method is used to discretize the control equation, and a new multielement thermal fluid numerical simulator is established. The physical simulation experiment of multicomponent thermal fluid huff and puff is carried out by using the actual sand-packed model. By comparing the experimental results with the numerical simulation results, it is proved that the new numerical simulation model considering formation damage proposed in this paper is accurate and reliable.

Heavy-Oil-Recovery Enhancement With Choline Chloride/Ethylene Glycol-Based Deep Eutectic Solvent

SPE Journal ◽  
2014 ◽  
Vol 20 (01) ◽  
pp. 79-87 ◽  
Author(s):  
S.M.. M. Shuwa ◽  
B.Y.. Y. Jibril ◽  
Y.M.. M. Al-Wahaibi ◽  
R.S.. S. Al-Hajri
Keyword(s):  
Ethylene Glycol ◽  
Oil Recovery ◽  
Heavy Oil ◽  
Energy Demand ◽  
Choline Chloride ◽  
Deep Eutectic Solvent ◽  
Wettability Alteration ◽  
Formation Damage ◽  
Heavy Oil Recovery ◽  
Brine Solution

Summary Because of increasing energy demand, unconventional resources such as heavy oil are being explored and recovered. Enhanced-oil-recovery (EOR) methods such as surfactants and polymer flooding must be optimized and new chemicals must be designed to produce more oil. This paper introduces a new deep eutectic solvent (DES) that is based on choline chloride/ethylene glycol for EOR. As preliminary investigations revealed, different concentrations of DES solutions in brine (0 to 100 vol%) were characterized by measuring density, viscosity, conductivity, surface tension, and refractive index at different temperatures (25 to 55°C). Then, the effects of the DES/brine solutions on emulsification with oil phase, wettability alteration, oil/solvent interfacial tension (IFT), formation damage, and tertiary heavy-oil recovery were studied. Potential of the DES solution on enhancing heavy-oil recovery was explored by use of coreflood experiments. This was performed at reservoir condition (pressure = 1,200 psi, temperature = 45 to 80°C) with Berea sandstone core samples and fluids from the field of interest (formation brine and crude oil). An increase in IFT rather than a decrease was observed between the DES/brine solution and the oil. The spontaneous-water-imbibition tests suggested that a decrease in oil-wetness led to an increase in oil production. Approximately 52% of residual oil after waterflooding was recovered with the DES from the coreflooding. The results show an increase in oil recovery with reservoir temperature (6, 13, and 16% on the basis of initial oil in place at 45, 60 and 80°C, respectively). The interaction of the DES with the core materials did not lead to formation damage, as demonstrated by the permeability measurements of the DES/brine solution before and after injection. Viscous forces and wettability alteration were found to be the dominant mechanisms for the tertiary oil-recovery enhancement.

New Agent for Formation-Damage Mitigation in Heavy-Oil Reservoir: Mechanism and Application

2008 ◽  
Author(s):  
Yuan Wang ◽  
Apostolos Kantzas ◽  
Binfei Li ◽  
Zhaomin Li ◽  
Qing Wang ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Formation Damage ◽  
Oil Reservoir ◽  
Damage Mitigation ◽  
Heavy Oil Reservoir

Formation Damage Characterization of Horizontal Well in Extra-Heavy Oil Reservoir and Methods of Remedy

2018 ◽  
Author(s):  
Zhangcong Liu ◽  
Changchun Chen ◽  
Xue Lv ◽  
Zhaopeng Yang ◽  
Yang Shen ◽  
...  
Keyword(s):  
Heavy Oil ◽  
Horizontal Well ◽  
Formation Damage ◽  
Oil Reservoir ◽  
Damage Characterization ◽  
Heavy Oil Reservoir
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