A New Method for Measuring Solvent Diffusivity in Heavy Oil by Dynamic Pendant Drop Shape Analysis (DPDSA)

Abstract

Summary This paper presents a new experimental method and its computational scheme for measuring solvent diffusivity in heavy oil under practical reservoir conditions by DPDSA. In the experiment, a see-through windowed high-pressure cell is filled with a test solvent at desired pressure and temperature. Then, a heavy-oil sample is introduced through a syringe delivery system to form a pendant oil drop inside the pressure cell. The subsequent diffusion of the solvent into the pendant oil drop causes its shape and volume to change until an equilibrium state is reached. The sequential digital images of the dynamic pendant oil drop are acquired and digitized by applying computer-aided digital image-acquisition and -processing techniques. Physically, variations of the shape and volume of the dynamic pendant oil drop are attributed to the interfacial tension reduction and the well-known oil-swelling effect as the solvent gradually dissolves into heavy oil. Theoretically, the interfacial profile of the dynamic pendant oil drop is governed by the Laplace equation of capillarity, and the molecular diffusion process of the solvent into the pendant oil drop is described by the diffusion equation. An objective function is constructed to express the discrepancy between the numerically predicted and experimentally observed interfacial profiles of the dynamic pendant oil drop. The solvent diffusivity in heavy oil and the mass-transfer Biot number are used as adjustable parameters and thus are determined once the minimum objective function is achieved. This novel experimental technique is tested to measure diffusivities of carbon dioxide in a brine sample and a heavy-oil sample, respectively. It should be noted that, with the present technique, a single diffusivity measurement can be completed within an hour and only a small amount of oil sample is required. The interface mass-transfer coefficient at the solvent/heavy-oil interface can also be determined. In particular, this new technique allows the measurement of solvent diffusivity in an oil sample at constant prespecified high pressure and temperature. Therefore, it is especially suitable for studying the mass-transfer process of injected solvent into heavy oil during solvent-based post-cold heavy-oil production (post-CHOP). Introduction Western Canada has tremendous heavy oil and bitumen resources (Farouq Ali 2003, Miller et al. 2002). Approximately 80 to 95% of the original-oil-in-place is still left behind at the economic limit after cold heavy-oil production (Miller et al. 2002). This is a large oil-in-place target for follow-up enhanced oil recovery (EOR) processes. After primary production, most Canadian heavy-oil reservoirs cannot be further exploited economically by thermal recovery processes because reservoir formations are thin and/or there is active bottomwater. In the literature, some studies have been conducted to evaluate the other recovery methods for these heavy-oil reservoirs (Miller et al. 2002, Das 1995, Frauenfeld et al. 1998, Metwally 1998). Among these methods, vapor extraction (VAPEX) and other solvent-based post-CHOP processes are probably the most promising EOR techniques. In practice, the solvent can be carbon dioxide, flue gas, and light hydrocarbon gases, such as methane, ethane, propane, and butane.

Experimental and Theoretical Determination of Equilibrium Interfacial Tension for the Solvent(s)–CO2–Heavy Oil Systems

“…PR EOS Model. Because of its wide application in the petroleum and chemical industries, the PR EOS 19 is chosen as the EOS for describing the phase behavior of 0.786 C 39 1.583 C 10 0.844 C 40 1.600 C 11 1.037 C 41 0.750 C 12 1.267 C 42 0.830 C 13 1.817 C 43 1.380 C 14 1.950 C 44 0.929 C 15 2.300 C 45 0.929 C 16 2.143 C 46 0.700 C 17 2.286 C 47 0.833 C 18 2.238 C 48 0.792 C 19 2.048 C 49 0.792 C 20 1.857 C 50 0.733 C 21 2.071 C 51 0.750 C 22 1.329 C 52 0.717 C 23 1.743 C 53 0.717 C 24 1.571 C 54 0.683 C 25 1.714 C 55 0.650 C 26 1.600 C 56 0.650 C 27 1.583 C 57 0.667 C 28 1.650 C 58 0.667 C 29 1.452 C 59 0.667 C 30 1.281 C 60+ 36.164 …”

“…16 The dissolved CO 2 functions as a surface-active agent, which is responsible for the IFT reduction. 17 The addition of rich solvents, such as C 3 H 8 and/or n-C 4 H 10 , to the CO 2 stream is a promising technique that can improve the performance of immiscible CO 2 processes in heavy oil reservoirs.…”

An analytical method of estimating diffusion coefficients of gases in liquids from pressure decay tests

“…Therefore, the indirect methods are preferable in engineering applications. The indirect methods are composed of the pressure‐decay method, the electromagnetic method, the PH method, density method, the swelling of a pendant droplet method, and visualized dye method, among others. The indirect physical data, such as pressure change and PH distribution, are used to measure the diffusion coefficient of the liquid/gas mixture.…”

Suggesting a numerical pressure-decay method for determining CO2 diffusion coefficient in water

“…The former methods deal with techniques that use either detectable parameters [1,4,[31][32][33][34] or thermodynamic parameters [21,[35][36][37] to correlate concentration and find DC by comparing with the analytical results of diffusion equation. Methods that are based on thermodynamic parameters are widespread and affordable.…”