Dilute Surfactant Flooding Studies in a Low-Permeability Oil-Wet Middle East Carbonate

2014 ◽  
Author(s):  
Martin V. Bennetzen ◽  
Kristian Mogensen ◽  
Soren Frank ◽  
Kishore Mohanty
Keyword(s):  
Middle East ◽  
Low Permeability ◽  
Surfactant Flooding ◽  
Dilute Surfactant Flooding

Injectivity and Propagation of Sulfonated Acrylamide-Based Copolymers in Low Permeability Carbonate Reservoir Cores in Harsh Salinity and Temperature Conditions : Challenges and Learnings from a Middle East Onshore Case Study

2021 ◽  
Author(s):  
Nicolas Gaillard ◽  
Matthieu Olivaud ◽  
Alain Zaitoun ◽  
Mahmoud Ould-Metidji ◽  
Guillaume Dupuis ◽  
...  
Keyword(s):  
Middle East ◽  
Polymer Solutions ◽  
Carbonate Reservoir ◽  
Core Material ◽  
Low Permeability ◽  
The Core ◽  
Reservoir Conditions ◽  
Carbonate Cores ◽  
The Impact ◽  
Mobility Reduction

Abstract Polymer flooding is one of the most mature EOR technology applied successfully in a broad range of reservoir conditions. The last developments made in polymer chemistries allowed pushing the boundaries of applicability towards higher temperature and salinity carbonate reservoirs. Specifically designed sulfonated acrylamide-based copolymers (SPAM) have been proven to be stable for more than one year at 120°C and are the best candidates to comply with Middle East carbonate reservoir conditions. Numerous studies have shown good injectivity and propagation properties of SPAM in carbonate cores with permeabilities ranging from 70 to 150 mD in presence of oil. This study aims at providing new insights on the propagation of SPAM in carbonate reservoir cores having permeabilities ranging between 10 and 40 mD. Polymer screening was performed in the conditions of ADNOC onshore carbonate reservoir using a 260 g/L TDS synthetic formation brine together with oil and core material from the reservoir. All the experiments were performed at residual oil saturation (Sor). The experimental approach aimed at reproducing the transport of the polymer entering the reservoir from the sand face up to a certain depth. Three reservoir coreflood experiments were performed in series at increasing temperatures and decreasing rates to mimic the progression of the polymer in the reservoir with a radial velocity profile. A polymer solution at 2000 ppm was injected in the first core at 100 mL/h and 40°C. Effluents were collected and injected in the second core at 20 mL/h and 70°C. Effluents were collected again and injected in the third core at 4 mL/h and 120°C. A further innovative approach using reservoir minicores (6 mm length disks) was also implemented to screen the impact of different parameters such as Sor, molecular weight and prefiltration step on the injectivity of the polymer solutions. According to minicores data, shearing of the polymer should help to ensure good propagation and avoid pressure build-up at the core inlet. This result was confirmed through an injection in a larger core at Sor and at 120°C. When comparing the injection of sheared and unsheared polymer at the same concentration, core inlet impairment was suppressed with the sheared polymer and the same range of mobility reduction (Rm) was achieved in the internal section of the core although viscosity was lower for the sheared polymer. Such result indicates that shearing is an efficient way to improve injectivity while maximizing the mobility reduction by suppressing the loss of product by filtration/retention at the core inlet. This paper gives new insights concerning SPAM rheology in low permeability carbonate cores. Additionally, it provides an innovative and easier approach for screening polymer solutions to anticipate their propagation in more advanced coreflooding experiments.

Fractal Application in Micro Rock Mechanics of Low-Permeability Oil Reservoirs and Its Relationship with Enlarging Producing Reserves by Gemini Surfactant Flooding

2010 ◽  
Vol 29-32 ◽  
pp. 170-176 ◽  
Author(s):  
Heng Wei ◽  
Lei Wei ◽  
Jian Hui Yin ◽  
Fu Ling Yin ◽  
Jun Han Liu ◽  
...  
Keyword(s):  
Rock Mechanics ◽  
Gemini Surfactant ◽  
Fractal Dimensions ◽  
Oil Reservoirs ◽  
Low Permeability ◽  
Surfactant Flooding ◽  
High Permeability ◽  
Fractal Method ◽  
Pore Structures ◽  
Conventional Methods

Low permeability oil reservoirs were usually considered low quality reserves. However, low permeability oil reservoirs account for more and more percent of the proven reserves year by year in China. Conventional methods for analyzing medium-hign permeability cores are not suitable to low-permeability cores. Based on fractal method and the mercury injection curve data, the fractal dimensions of the pore structures of low permeability oil reservoirs are different from those of medium-high permeability oil reservoirs. The fractal dimensions of the pore structures of low permeability oil reservoirs are less than 2. Low permeability oil reservoirs which were not able to be developed are able to be developed by gemini surfactant flooding. This helps more and more low quality reserves be turned into producing reserves.

The effect of oil properties on oil recovery in dilute surfactant flooding

2016 ◽  
Vol 34 (8) ◽  
pp. 759-764 ◽  
Author(s):  
Wan-Fen Pu ◽  
Shuai Zhao ◽  
Xin-Bian Lu ◽  
Cheng-Dong Yuan ◽  
Song Wang ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Surfactant Flooding ◽  
Dilute Surfactant Flooding
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