Comparative evaluation of immiscible, near miscible and miscible CO2 huff-n-puff to enhance oil recovery from a single matrix–fracture system (experimental and simulation studies)

Torabi, Farshid; Firouz, Alireza Qazvini; Kavousi, Ali; Asghari, Koorosh

doi:10.1016/j.fuel.2011.08.037

Cited by 75 publications

(24 citation statements)

References 15 publications

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“…Gas flooding has been widely used to enhance oil recovery in conventional oil reservoirs, either in simultaneous injection or in water-alternating-gas (WAG) mode. Huff and puff to enhance oil recovery in conventional oil reservoirs has been studied by numerous researchers through laboratory studies (Haines and Monger, 1990;Monger and Coma, 1988;Torabi and Asghari, 2010;Torabi et al, 2012), as well as field tests (Bernard and Miller, 1998;Schenewerk et al, 1992;Miller and Gaudin, 2000;Thomas and Monger-McClure, 1991;Monger et al, 1991;Artun et al, 2008). However, to the best of our knowledge, no gas injection has been tried in shale oil or shale liquid-rich reservoirs, although some laboratory tests and simulation studies have been performed.…”

Section: Gas Injectionmentioning

confidence: 99%

Enhanced oil recovery in shale reservoirs by gas injection

Sheng

2015

Journal of Natural Gas Science and Engineering

284

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The current available technique to produce shale oil and gas condensate is through primary depletion using horizontal wells with multiple transverse fractures. The oil recovery factor is only a few percent. There is a big prize to be claimed in terms of enhanced oil recovery (EOR). Because gas price is low and oil price is high, maximizing liquid oil production from gas condensate reservoirs becomes shale producers' top interest. This paper provides the status of enhanced oil recovery (EOR) in shale oil and gas condensate reservoirs by gas injection. It starts with the discussion of possible EOR options in shale reservoirs. For the gas injection option, the huff and puff mode is compared with the gas flooding mode. Different modes of water injection in shale oil reservoirs are also compared. The discussion and comparison show that gas injection is more feasible in shale reservoirs than waterflooding and any other EOR methods. The rest of the paper focuses on review of gas injection in shale reservoirs, which covers the following. • Mechanisms of gas injection • Experimental results on huff and puff gas injection • Simulation results on huff and puff gas injection • Gas injection in gas condensate reservoirs This paper summarizes the EOR efforts which has been made in the industry and provides the direction for the industry future efforts to maximize liquid oil production.

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Section: Gas Injectionmentioning

confidence: 99%

Enhanced oil recovery in shale reservoirs by gas injection

Sheng

2015

Journal of Natural Gas Science and Engineering

284

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“…Such phenomenon occurs when the solution gas is released from oil to form small dispersed, trapped gas bubbles inside the oil which flow with the oil because of the high viscosity of heavy oil. As a result, the oil is expanded and its viscosity is reduced due to gas bubbles (Yu and Shen 2008;Peng et al 2009;Wang et al 2009;Torabi et al 2012). However, when the reservoir pressure is below the pseudo-bubble point pressure, the gasoil ratio of the reservoir increases quickly, and the oil production rate decreases sharply because the gas bubbles trapped in the oil begin to coalesce together to form free gas phase (Liu et al 2011;Sun et al 2013).…”

Section: Introductionmentioning

confidence: 99%

Diffusion coefficients of natural gas in foamy oil systems under high pressures

et al. 2015

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The diffusion coefficient of natural gas in foamy oil is one of the key parameters to evaluate the feasibility of gas injection for enhanced oil recovery in foamy oil reservoirs. In this paper, a PVT cell was used to measure diffusion coefficients of natural gas in Venezuela foamy oil at high pressures, and a new method for determining the diffusion coefficient in the foamy oil was developed on the basis of experimental data. The effects of pressure and the types of the liquid phase on the diffusion coefficient of the natural gas were discussed. The results indicate that the diffusion coefficients of natural gas in foamy oil, saturated oil, and dead oil increase linearly with increasing pressure. The diffusion coefficient of natural gas in the foamy oil at 20 MPa was 2.93 times larger than that at 8.65 MPa. The diffusion coefficient of the natural gas in dead oil was 3.02 and 4.02 times than that of the natural gas in saturated oil and foamy oil when the pressure was 20 MPa. However, the gas content of foamy oil was 16.9 times higher than that of dead oil when the dissolution time and pressure were 20 MPa and 35.22 h, respectively.

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“…However, only a few papers have been published with respect to cyclic stimulation techniques on heavy oil reservoirs (Sayegh and Maini, 1984;Palmer et al, 1986;Monger and Coma, 1988;Simpson, 1988;Brock and Bryan, 1989;Haskin and Alston, 1989;Miller, 1990; Thomas and Monger-McClure, 1991;Shayegi, 1996;Mohammed-Singh et al, 2006;Asghari, 2010, Qazvini Firouz, 2011;Torabi et al, 2012). However, only a few papers have been published with respect to cyclic stimulation techniques on heavy oil reservoirs (Sayegh and Maini, 1984;Palmer et al, 1986;Monger and Coma, 1988;Simpson, 1988;Brock and Bryan, 1989;Haskin and Alston, 1989;Miller, 1990; Thomas and Monger-McClure, 1991;Shayegi, 1996;Mohammed-Singh et al, 2006;Asghari, 2010, Qazvini Firouz, 2011;Torabi et al, 2012).…”

Section: Introductionmentioning

confidence: 99%

Feasibility Study of Solvent-Based Huff-n-Puff Method (Cyclic Solvent Injection) to Enhance Heavy Oil Recovery

Firouz

Torabi

2012

All Days

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Solvent-based processes have demonstrated a significant potential to enhance heavy oil recovery. However, their applicability needs to be investigated for different solvents and operating conditions. In this study, a comprehensive experimental and reservoir simulation analysis was conducted on the feasibility of solvent-based, huff-n-puff method to enhance heavy oil recovery. Carbon dioxide (CO 2 ), methane (CH 4 ), propane (C 3 H 8 ), and butane (C 4 H 10 ) were tested under different operating conditions. A physical model with a1800-md permeability and 24% porosity Berea core mounted in a high-pressure core holder was designed. For all tests, the core was saturated with a Saskatchewan heavy oil with viscosity of 1423 mPa·s at 22 °C. Fourteen huff-n-puff experiments were conducted. The effect of operating pressure, soaking time, and solvent composition were investigated. According to the results, for all types of solvent the produced oil at elevated pressure was lighter (in terms of density and viscosity) and the recovery factor was higher. The highest recovery of 71% was obtained by injecting pure CO 2 at near-supercritical conditions (7239 kPa at 28 °C), while pure CH 4 at the highest operating pressure of 6895 kPa was 50%. Also, adding 19% hydrocarbon solvent to pure CO 2 increased the recovery factor by 10% at aoperating pressure (e.g., 2317kPa). The governing mechanisms that contributed to the production were recognized to be solution gas drive, viscosity reduction, extraction of lighter components, formation of foamy oil, and to a lesser degree, the diffusion process. The oil viscosity was reduced to 62 mPa·s by injecting CO 2 at 7239 kPa. The highest incremental recovery for CO 2 -based solvents and CH 4 occurred at the 2 nd and 3 rd cycle, respectively. Longer soaking time improved the incremental recovery of the first cycles, though the final recovery did not noticeably change. The result of history matching with the simulated model was quite reasonable with maximum 10% discrepancy between recovery factors of these two approaches.

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Comparative evaluation of immiscible, near miscible and miscible CO2 huff-n-puff to enhance oil recovery from a single matrix–fracture system (experimental and simulation studies)

Cited by 75 publications

References 15 publications

Enhanced oil recovery in shale reservoirs by gas injection

Enhanced oil recovery in shale reservoirs by gas injection

Diffusion coefficients of natural gas in foamy oil systems under high pressures

Feasibility Study of Solvent-Based Huff-n-Puff Method (Cyclic Solvent Injection) to Enhance Heavy Oil Recovery

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