Analytical model of steam-assisted gravity drainage (SAGD) process in relation to constant injection rate

Zargar, Zeinab; Razavi, Seyed Mahdi; Ali, S.M. Farouq

doi:10.1016/j.fuel.2019.116772

Cited by 18 publications

(4 citation statements)

References 9 publications

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“…Over 95% of oil in Canada is located in oil sands reservoirs. One of the most popular methods to develop the oil sands reservoirs is Steam-Assisted Gravity Drainage (SAGD) (Butler, 1997;Zargar et al, 2020). In this recovery method, two horizontal wells including one injector and one producer are drilled near to the bottom of a reservoir (Butler, 1997).…”

Section: Introductionmentioning

confidence: 99%

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Chen

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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Intraformational water zones are widely reported in Canadian oil sands fields. In order to pressurize a thief zone, one of the initiatives is to inject gas. However, the evaluation of gas injectivity based on a pore size distribution is still a big challenge. This study provides a multi-scale approach to study the effect of a pore size distribution on gas injectivity in intraformational water zones. The results indicate the gas effective permeability increases in a less complex and more discrete pore network. The enhancement of gas effective permeability with increased gas saturation weakens with higher complexity and lower discreteness of a pore network. A less complex and more discrete pore network better benefits the gas injectivity index.

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Section: Introductionmentioning

confidence: 99%

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Chen

2020

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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“…where K is the permeability of the sand-pack model, μm 2 ; μ is the viscosity of the injected fluid, μm 2 ; A is the inner cross-sectional area of the sand-pack model, cm 2 ; Q is the flow rate of the fluid, mL/s; ΔP is differential pressure, atm; and L is the length of the sand-pack model, cm. 3 Geofluids A two-layer model with two parallel homogeneous cores with different permeabilities was also utilized in the flooding experiments to simulate the nonhomogeneity of the reservoir.…”

Section: Stability Experimentsmentioning

confidence: 99%

“…Heavy-oil reservoirs are one of the most important unconventional resources, with an enormous economic value and an abundant quantity of reserves. The application of thermal methods to enhance heavy-oil recovery has some crucial challenges due to economic and environmental obstacles [1,2]. For example, SAGD is a thermal process requiring energy to turn water into steam, and it is commercially expensive.…”

Section: Introductionmentioning

confidence: 99%

Study on a Novel Water-Soluble Hydrophobically Associating Polymer as an Enhanced Heavy Oil Recovery Agent

Qiao

Wang

et al. 2021

Geofluids

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In this study, emulsion-free radical reaction was applied to synthesize a novel sulfomethylating hydrophobically associating copolymer (HPDS) by using acrylamide, acrylic acid, NaHSO3, HCHO, and a laboratory-made N,N-divinylnonadeca-1,10-dien-2-amine to enhance heavy-oil recovery. The structure and properties of HPDS were characterized by a range of experiments, which showed that HPDS had better stability and enhanced heavy-oil recovery capacity than hydrolyzed polyacrylamide (HPAM). One-dimensional flooding experiments illustrated that HPDS performed better in establishing resistance factor (RF) and residual RF (RRF), and approximately 19.8% oil recovery could be enhanced by injecting 1500 mg/L of HPDS solution compared with that of HPAM at only 14.1%. HPDS has a promising application prospect in enhancing heavy-oil recovery.

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“…Given the response of different reservoir parameters (initial injection capacity, mobile water saturation, and reservoir heterogeneity) to the SAGD process in the Cold Lake, Tavallali et al 21 used a fully implicit reservoir thermal simulation system to conduct sensitivity analysis on the SAGD of the improved well type and identify the most promising new well configuration. Zargar et al 22 developed an analytical SAGD model with the constant injection rate from three stages (encompassing steam chamber rise stage, sideways expansion stage, and the confinement phases stage) to evaluate the SAGD performance. Canbolat 23 analyzed the variation of heat transfer behavior by conduction and convection on heavy oil production using heat fluxes via the coinjection of noncondensable gas during SAGD.…”

Section: Introductionmentioning

confidence: 99%

Visualization Experimental Study on Well Spacing Optimization of SAGD with a Combination of Vertical and Horizontal Wells

Tao

Yuan

et al. 2021

ACS Omega

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For oil sand reservoirs, the steam-assisted gravity drainage (SAGD) technique is one of the most efficient thermal recovery technologies. However, the high oil viscosity and the severe heat loss seriously affect the production effect of SAGD in developing thin oil sand reservoirs by the traditional SAGD technology. Therefore, it is essential to improve the SAGD technology to enhance the recovery of the thin oil sand reservoir. In this paper, SAGD with a combination of vertical and horizontal well (VH-SAGD) technology was adopted, and the influence of different well spacings (horizontal distance between vertical steam injection wells and horizontal production wells) on the development of steam chambers was investigated. By the similarity criterion, the experimental parameters were obtained. After that, an improved 2D visualization physical model was designed with 9 × 9 high-precision thermocouples installed inside the device to monitor the real-time temperature. This experimental physical model can not only accurately capture the temperature distribution but also display the continuous change process of the chamber inside the model by the visible window. Finally, different well spacing cases (10, 15, and 20 cm) were tested to observe the development of the steam chamber and analyze the production data. Both the temperature distribution and visual window showed that the steam chamber has four obvious stages, and reasonable well spacing can promote the development of the steam chamber. When the well spacing is relatively small, the unswept area of the cold oil on both sides is large, and the area of the steam chamber overlaps more. When the well spacing is relatively moderate, the steam chamber is the most complete and the recovery factor is the highest. When the well spacing is relatively large, although the unswept area of the cold oil on both sides is small, the middle cold oil area is larger than the previous two groups. Therefore, the best well spacing for oil sand reservoirs of about 15 m thickness is 15–20 m, where the VH-SAGD method has a better displacement effect and higher oil recovery. The experimental conclusions can provide theoretical support for the production of thin oil sand reservoirs.

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Analytical model of steam-assisted gravity drainage (SAGD) process in relation to constant injection rate

Cited by 18 publications

References 9 publications

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Impacts of pore size distribution on gas injection in intraformational water zones in oil sands reservoirs

Study on a Novel Water-Soluble Hydrophobically Associating Polymer as an Enhanced Heavy Oil Recovery Agent

Visualization Experimental Study on Well Spacing Optimization of SAGD with a Combination of Vertical and Horizontal Wells

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