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• W2005438863 abstract "Abstract The potential for the more economic recovery of heavy oil has encouraged many researchers to investigate the steam-assisted gravity drainage process. These studies have usually involved physical models. One problem which is encountered is in the scaling of a field well to a laboratory well. In this paper, from considerations of the pressure gradient along the well, it is shown that the scaling factor for the radius of the horizontal well Is not proportional to the geometrical ratio for the laboratory model and the field but to the one-fourth power of this ratio. A computer program was developed to predict the pressure profile of the production well, the oil flow rate along the well and the gravity head of the heated oil backed up by the flow resistance of the well. The computer program was used to study the effect of the viscosity of the fluids (or the wellbore temperature) within the well, the well size and the well length. Calculations performed by the computer program shows that the drainage of the produced fluids can be Impeded if the wellbore temperature is too low or if the well size is too small. Introduction Canada has abundant deposits of heavy oil. The potential of using horizontal wells for the recovery of these deposits has encouraged many researchers to investigate the steam-assisted gravity drainage (SAGD) process using physical models. In the SAGD process steam is injected continuously so as to form a steam chamber. Oil drains from around the perimeter of the chamber to a production well which is located below. Gravity provides the driving force which causes the heated oil to flow. Because gravity drainage is relatively slow, a horizontal production well is employed so as to provide more reservoir contact and greater production. As the steam condenses the condensateis removed along with the draining oil. The steam chamber grows in size as the process continues. The process is illustrated in Figure 1. he principal driving force for the drainage of produced fluids toward the perforated horizontal well from around a constant pressure steam chamber is the fluid static head (or gravity head). Some of the available head must be used to drain the produced liquids that flow along the wellbore. It is crucial that the size of the horizontal well be sufficiently large so that the head dissipated in moving the produced fluids along the well is not excessive. Erroneous experimental results (oil production rate or steam chamber propagation rate) can be obtained in laboratory models if the wellbore flow resistance is excessive compared to that in the field. In this paper, the effect of wellbore flow resistance has been studied and it is found that laboratory models require surprisingly large wellbore radii. Scaling the Horizontal Well For scaling of field conditions to laboratory conditions, Butler(1) proposed that the dimensionless number. B3 and the dimensionless time, T', must be equal for both field and laboratory conditions." @default.
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• W2005438863 date "1990-11-01" @default.
• W2005438863 modified "2023-09-27" @default.
• W2005438863 title "Wellbore Flow Resistance In Steam-Assisted Gravity Drainage" @default.
• W2005438863 doi "https://doi.org/10.2118/90-06-04" @default.
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