... was performed using two stacked plugs from Field A at 279 °F and an injection pressure of 3000 psig. After cleaning with a 50:50 Toluene-Methanol mix, the core plugs were saturated with synthetic formation water. Once saturated, the core plugs were aged in Field A reservoir fluid (Oil A) for 40 days...

... of steam chamber. Equation (2) calculates the oil rate proposed by Reis: os o am HSkg Lq µ 2 2 = (2) where q = oil production rate L = SAGD length k = permeability = reservoir thermal diffusivity = oil density = porosity S = (initail residual) oil saturation H = the height from production...

... of the three depressurisation regimes. Introduction In solution gas drive, bubbles nucleate and grow within saturated oil when the reservoir pressure is lowered below the bubble point. A period of internal gas-phase expansion maintains reservoir pressure, driving oil to the wellbore region. After some time...

... reservoirs (where no initial liquid-hydrocarbon saturation is or ever has been present) because of the strong spreading coefficient of water in such a situation. The retention of increased water saturation in the pore system after the injection of water-based completion fluids can restrict the flow...

... saturation producer production history general decline trend variation perturbation injection water injection clear decline trend reservoir fluctuation oil rate enhanced recovery water flood production rate injection rate injector cumulative oil upstream oil & gas...

... analyzed. At the end of this depletion period, the reservoir has a substantial amount of condensate that has dropped out from the produced gas, giving an average oil saturation of 0.19 in the model. The dew point pressure of this fluid is 5330 psia. The base case has injection of 40 Mscf/d of CO2...

... in the characterization (fluid saturations and pressures) of the oil sand pack at the start of the solvent injection process. The history match of the subsequent 6 solvent injection cycles was used to validate the numerical model of the CSI process developed at the Alberta Research Council. This model includes non...

.... The CO2 storage capacity in water as dissolved gas is much less than that of CO2 as supercritical gas. Meanwhile, the residual oil saturation after most tertiary recovery methods is still as high as 30%[4]. The remaining water and residual oil restrict the CO2 storage capacity in the depleted oil...

... mcmurray formation drainage time recovery process reservoir solvent test bitumen solvent process saturation enhanced recovery thermal method diffusivity equation viscosity porosity sagd carbonate reservoir steam-assisted gravity drainage grosmont reservoir permeability...

... is recovered as water in oil emulsion. The emulsion viscosity is greater than the oil viscosity (Vittoratos, 1991). This is more than compensated by the increased oil saturation (and therefore increased oil relative permeability) due to oil phase swelling resulting from the water in the emulsion. In later...

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... during thermal production of heavy oil and bitumen reservoirs, which complicates the interpretation of 4D seismic data: changes in oil viscosity, fluid saturations, pore pressure, etc. The workflow is based on the generation of a geological model inspired from a real field case of the McMurray Fm...

... oil saturation css enhanced recovery sagd performance cumulative sor operation clearwater formation steam-assisted gravity drainage bottom water upstream oil & gas producer bitumen sagd operation thermal method cnrl sagd modeling & simulation sagd project well pair...

... of such effects. Theory Consider a block of reservoir rock saturated with oil and water. The edges of the block are impermeable. If capillary pressure is negligible and the oil is less dense than the water, all the oil will eventually rise to the top and of the block and all the water will sink to the bottom...

... in pore pressure. Based on the experimental results, a petrophysical model was formulated to express Vp as a function of temperature, pressure, and water saturation. The high pressure and high temperature zone of the SAGD process should generate differences between the first (2002) and second (2006) Vp...

... conditions at fluid- fluid and fluid-solid interfaces are thus considered as similar, although this, in fact, is not true. Another questionable assumption inherited by the conventional formulation for multiphase flow through porous media is the sole dependence of relative permeabilities on saturation...

.... Intuitively, nature of resulting distribution depends upon pressurization, solubility, diffusion coefficients, heterogeneity, and flow/saturation distributions. Upon flow back (production); many of the above factors are not fully reversed, leading to significant gas retention. It is surmised that generalized...

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