Modelling Injection Strategies for a Reservoir with an Extreme Permeability Contrast: IOR Qualification

Surguchev, L.M.; Hanssen, Jan; Johannessen, Hege Hølmo; Sisk, Carl

doi:10.2523/35504-ms

Cited by 4 publications

(4 citation statements)

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“…In vertical fractures, care should be taken to limit gravity segregated fluid flow during coinjection of aqueous and gaseous phases. During gas injection projects, foam should be injected as early as possible after gas breakthrough (Surguchev et al, 1996). Foam injection in combination with other EOR efforts may also improve economics, for instance foam in combination with ASP flooding or polymer gels (Wang et al, 2006).…”

Section: Eor By Foam Injection In Fractured Reservoirsmentioning

confidence: 99%

Enhanced Oil Recovery in Fractured Reservoirs

Fernø¹

2012

Introduction to Enhanced Oil Recovery (EOR) Processes and Bioremediation of Oil-Contaminated Sites

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Section: Eor By Foam Injection In Fractured Reservoirsmentioning

confidence: 99%

Enhanced Oil Recovery in Fractured Reservoirs

Fernø¹

2012

Introduction to Enhanced Oil Recovery (EOR) Processes and Bioremediation of Oil-Contaminated Sites

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“…For such reservoirs, one of the important factors that affects sweep efficiency is cross-flow from one layer into another layer in the direction perpendicular to the main flow path (Fitzmorris et al, 1992). One possible remedy for cross-flow control is simultaneous injection of fluids with different properties (Rossen et al, 2006;Stone, 2004;Surgchev et al, 1996). Masalmeh and Blom (2011) showed the better performance in oil recovery and vertical sweep efficiency, as a simulation study, by controlling the mobility of the injected fluids in high and low permeable zones to prevent mixing of the two streams, so that the injected fluid was confined in each layer.…”

Section: Introductionmentioning

confidence: 99%

A remedial method of polymer flooding to prevent cross-flow problem in a layered reservoir

Park

Jang

Hwang

et al. 2017

Energy Exploration & Exploitation

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When injecting polymer into an oil reservoir, polymer adsorption onto the grain surface may seriously clog the pore throat and decrease the permeability. This phenomenon may give rise to a severe cross-flow problem in the case of a layered reservoir with a large permeability contrast. Therefore, we proposed a remedial method, which injects polymer solution with different concentrations under the same condition of the frontal velocity at each layer, to overcome the cross-flow problem. In order to perform this task, the experimental system was built as a two-dimensional two-layered sandstone system with a large permeability contrast of 10. From the results of the experimental investigation, conventional polymer flooding was found to be inefficient in oil recovery, because of the cross-flow problem that occurred almost from the beginning of injection. Meanwhile, in the case of the suggested remedial method of polymer flooding, the oil production was significantly enhanced without showing the cross-flow problem, which was accomplished by injecting the polymer solution with different concentrations under the conditions of the same frontal velocity at each layer. Overall, the suggested injecting method was found to be sufficient to overcome the cross-flow problem in a layered reservoir.

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“…Slightly lower recoveries were observed when higher permeability was in the middle of the pay zone. Surguchev et al (1996) presented a comparison study of different IOR methods on a Norwegian field characterized by extreme heterogeneity. The study also included different combinations of horizontal and vertical wells, with and without fracturing of injection and production wells.…”

Section: Introductionmentioning

confidence: 99%

Miscible CO2 Injection in Highly Heterogeneous Carbonate Cores: Experimental and Numerical Simulation Studies

Eidan

Mamora

2011

All Days

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We have conducted a miscible CO 2 flood using carbonate cores and 31° API west Texas oil under four injection modes: simultaneous water and CO 2 (SWACO 2 ), water alternating CO 2 (WACO 2 ), continuous gas injection (CGI), and waterflood (WF). Then, a pseudo-miscible black oil simulator was used to match the experimental results. The matched simulation model was extended to conduct a sensitivity study on permeability variation in the core, WACO 2 ratio and slug size, and SWACO 2 ratio. Three permeability values were chosen to represent a flow barrier, average matrix permeability, and high permeability streak. These values were arranged to represent a layered reservoir and then aligned in series to represent a sequenced reservoir. The four injection modes were conducted in all six permutations of these three values in both the layered and sequenced arrangements. The oil recovery from the coreflood experiments was measured to be 90, 86, 75, and 54 % of OIIP for SWACO 2 , WACO 2 , CGI, and WF, respectively. The simulation results may be summarized as follows: for all injection modes during the layered permeability arrangements, the best oil recovery was obtained when the flow barrier is in the middle of the core. Conversely, lower recoveries were obtained when the barrier was not in the middle and the high permeability was located at the top with significant decrease in oil recovery (up to 40%). In sequenced reservoirs, each injection mode showed different preference to the permeability arrangements. For example, CGI showed higher recovery (5% increase) when the low permeability is near the outlet which allowed for more controlled displacement but with high differential pressure across the core. The WACO 2 ratio study in the homogenous (base) case showed that a 1:2 ratio had the highest oil recovery but the optimum ratio was 1:1 based on the amount of injected CO 2 . In layered reservoirs, each permeability arrangement had higher recovery at different WACO 2 ratios depending on the location of the flow barrier. However, in most cases 1:1 ratio was the optimum except for two cases, where the high permeability was at top, the 3:1 (increasing water ratio) was the optimum WACO 2 ratio.

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Modelling Injection Strategies for a Reservoir with an Extreme Permeability Contrast: IOR Qualification

Cited by 4 publications

References 0 publications

Enhanced Oil Recovery in Fractured Reservoirs

Enhanced Oil Recovery in Fractured Reservoirs

A remedial method of polymer flooding to prevent cross-flow problem in a layered reservoir

Miscible CO2 Injection in Highly Heterogeneous Carbonate Cores: Experimental and Numerical Simulation Studies

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