Relative permeability and capillary pressure curves for low salinity water flooding in sandstone rocks

2015 ◽  
Vol 25 ◽  
pp. 30-38 ◽  
Author(s):  
Mohammad-Javad Shojaei ◽  
Mohammad Hossein Ghazanfari ◽  
Mohsen Masihi
Keyword(s):  
Capillary Pressure ◽  
Relative Permeability ◽  
Water Flooding ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Salinity Water ◽  
Capillary Pressure Curves

A Novel Method To Model Low-Salinity-Water Injection in Carbonate Oil Reservoirs

SPE Journal ◽  
2015 ◽  
Vol 20 (05) ◽  
pp. 1154-1166 ◽  
Author(s):  
Emad W. Al-Shalabi ◽  
Kamy Sepehrnoori ◽  
Mojdeh Delshad ◽  
Gary Pope
Keyword(s):  
Capillary Pressure ◽  
Relative Permeability ◽  
Oil Recovery ◽  
Carbonate Rocks ◽  
History Matching ◽  
Water Injection ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Salinity Water ◽  
Low Salinity Water Injection

Summary There are few low-salinity-water-injection (LSWI) models proposed for carbonate rocks, mainly because of incomplete understanding of complex chemical interactions of rock/oil/brine. This paper describes a new empirical method to model the LSWI effect on oil recovery from carbonate rocks, on the basis of the history matching and validation of recently published corefloods. In this model, the changes in the oil relative permeability curve and residual oil saturation as a result of the LSWI effect are considered. The water relative permeability parameters are assumed constant, which is a relatively fair assumption on the basis of history matching of coreflood data. The capillary pressure is neglected because we assumed several capillary pressure curves in our simulations in which it had a negligible effect on the history-match results. The proposed model is implemented in the UTCHEM simulator, which is a 3D multiphase flow, transport, and chemical-flooding simulator developed at The University of Texas at Austin (UTCHEM 2000), to match and predict the multiple cycles of low-salinity experiments. The screening criteria for using the proposed LSWI model are addressed in the paper. The developed model gives more insight into the oil-production potential of future waterflood projects with a modified water composition for injection.

A Comparison of Different Nanoparticles' Effect on Fine Migration by Low Salinity Water Injection for Oil Recovery: Introducing an Optimum Condition

2021 ◽  
pp. 1-22 ◽  
Author(s):  
Ali Madadizadeh ◽  
Alireza Sadeghein ◽  
Siavash Riahi
Keyword(s):  
Porous Media ◽  
Zeta Potential ◽  
Oil Recovery ◽  
Fine Particles ◽  
Production Equipment ◽  
Water Flooding ◽  
Sand Production ◽  
Low Salinity ◽  
Low Salinity Water ◽  
Salinity Water

Abstract Today, enhance oil recovery (EOR) methods are attracting more attention to increase the petroleum production rate. Some EOR methods such as low salinity water flooding (LSW) can increase the amount of fine migration and sand production in sandstone reservoirs which causes a reduction in permeability and inflict damages on to the reservoir and the production equipment. One of the methods to control fine migration is using nanotechnology. Nanoparticles (NPs) can reduce fine migration by various mechanisms such as reducing the zeta potential of fine particles' surfaces. In this paper, three NPs including SiO2, MgO, and Al2O3 's effects on controlling fine migration and sand production were investigated in two scenarios of pre-flush and co-injection by using sandpack as a porous media sample. When NPs are injected into the porous media sample, the outflow turbidity and zeta potential of particles decreases. Experiments showed that SiO2 has the best effect on controlling fine migration in comparison with other NPs and it could reduce fine migration 69% in pre-flush and 75% in co-injection. Also, MgO and Al2O3 decreased fine migration 65% and 33% in the pre-flush scenario and 49%,13% in the co-injection scenario, respectively.

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