1. Introduction
Gas flooding is one enhanced oil recovery (EOR) method that injects CO
2 or other gases into reservoirs to displace oil. It has been researched and applied in the fields since the 1950s [
1,
2,
3]. Since 2006, the gas flooding projects account for more than half of all the EOR projects worldwide [
4], showing the utmost importance of this EOR method. To obtain a high recovery factor in a gas flooding project, the injected gas should develop miscibility with the in-situ oil [
5]. This minimum pressure, at which the miscibility is reached, is defined as the minimum miscibility pressure (MMP). MMP is an essential design parameter of gas flooding projects.
There are various experimental and computational methods to determine MMP. Experimental methods include the rising bubble experiment method [
6,
7], the vanishing interfacial tension method [
8,
9], and the slim-tube method [
5,
10,
11]. Among these methods, the slim-tube method is an industrially accepted experimental method. Its procedure is briefly summarized as follows. At a given pressure level (such as the bubble point pressure of the reservoir oil), we conduct a displacement test by injecting gas into a slim-tube apparatus to displace oil. We then record the oil recovery factor when the injected gas volume reaches 1.2 times the slim-tube pore volume (PV). This displacement test is repeated at increased pressure levels. The oil recovery factors corresponding to 1.2 PV injection are plotted against pressure. The MMP can be finally determined as the pressure at the inflection point of the trend line exhibited by the data points. Slim-tube experiments are not only easy to implement but also capable of providing reliable MMP measurements [
12]. However, as an experimental method, the slim-tube method is inevitably costlier and more time-consuming than its counterpart slim-tube simulation method.
The slim-tube simulation method [
13,
14,
15] is a straightforward computational method to estimate MMP by simulating the slim-tube experiments in a fine one-dimensional (1D) compositional simulation model. Such a 1D model consists of a row of multiple grid cells. To increase the estimation accuracy of the numerical model, an important treatment is to calculate the extrapolated infinite-cell recovery factor. For example, as in Høier’s implementation [
15], three numerical displacement tests are conducted by 100-, 200- and 500-grid-cell models, respectively, to record three recovery factors. The three recovery factors are used to fit a pre-defined curve model and the fitted curve is extrapolated to obtain the infinite-cell recovery factor. This exercise is then repeated at different pressure levels. Similar to the real slim-tube experiments, the final step is to identify the inflection point in the plot of recovery factor vs. pressure.
The slim-tube simulation method can be further simplified as the multiple-mixing-cell (MMC) method [
16] where a grid cell is simplified as a mixing cell. Specifically, in each mixing cell, flow dynamics are neglected and only the isobaric-isothermal (PT) equilibria of oil and gas mixtures are considered. Similarly, this MMC method consists of two key parts. The first part is the 1D numerical MMC model (a simplified slim-tube simulation model) that can generate the infinite-cell recovery factors, while the second part is the specific pressure search algorithm for MMP determination. Originally, this MMC model was designed to perform oil vaporization calculations by Cook et al. [
17]. It was later modified by Metcalfe et al. [
18] and Pederson et al. [
19] to study miscibility mechanisms. Jaubert et al. [
16] successfully applied this MMC model for MMP estimations. In the following discussion, we refer to this method as the J-MMC method and the corresponding numerical model as the J-MMC model.
Figure 1 shows a simple schematic of the J-MMC model. In
Figure 1, we have used 5 mixing cells and 5 batches, forming a 5 × 5 matrix. The topology of the matrix is controlled by three key parameters, i.e., cell number (analogous to grid number), batch number (analogous to time step number), and gas-oil mixing ratio (
). In the matrix, each row represents the 1D model at one batch (time step). Note that the parameter
is irrelevant to the conventional definition in the oil and gas industry, but it can be interpreted as the “injection speed” of gas in the 1D model.
Figure 2 shows the simulation workflow of the 1D model at a certain batch and at a specified pressure. As shown in
Figure 2, a specified volume of gas is “injected” and mixed with the oil in the 1st cell. In the mixing at the 1st cell, the ratio of the injected-gas volume to the original oil volume in the 1st cell is defined as
. To calculate the fluid’s volume at equilibrium after mixing, one PT phase equilibrium calculation is conducted. At equilibrium, the fluid in the 1st cell will expand and the “excessive” volume as defined by Jaubert et al. [
16] will be transferred to the 2nd cell and contact the oil therein.
Figure 3 shows the detailed procedure to transfer the excessive fluid [
16]. As shown in
Figure 3, if the fluid at equilibrium appears as a single phase (scenario 1), directly transfer the excessive volume; if the fluid at equilibrium appears as two phases and the liquid phase volume is smaller than the cell volume (scenario 2), transfer a part of the vapor phase; if the fluid at equilibrium appears as two phases and the liquid phase volume is larger than the cell volume (scenario 3), transfer the whole vapor phase and a part of the liquid phase. We repeat such transferring calculations until reaching the last cell from which the excessive volume is finally “produced”. Subsequently, we proceed to the next-batch calculations by using the same amount of injected gas. The calculation is completed until a total of 1.2 PV of gas is injected. Eventually, the oil recovery factor of this n-cell model at a specified pressure level can be determined as the summation of the produced oil volumes from all the batches divided by the original oil volume in the n-cells, both at the standard condition.
In the J-MMC method, different from the previous slim-tube simulation method, we only need to conduct one simulation run by using the largest number of required cells to calculate the infinite-cell recovery factor. For example, as stated by Jaubert et al. [
16], only a simulation run using a 500-cell model needs to be conducted, from which the 50-, 100-, 200-, and 500-cell recovery factors can be obtained at the same time. These four data points are used to fit a linear model (i.e., a straight line) and the fitted model is extrapolated to calculate the infinite-cell recovery factor. Besides, a pressure search algorithm is executed to determine three pressure points to calculate the corresponding infinite-cell recovery factors. Then, the three points of infinite-cell recovery factor vs. pressure are used for fitting an exponential model. Finally, the pressure corresponding to a 97% recovery factor is determined as MMP [
16].
Except for the J-MMC method, Ahmadi and Johns [
20] proposed another state-of-the-art MMC method, and its computational efficiency is further improved by Zhao et al. [
21]. Similarly, we refer to this method as the AJ-MMC method and the corresponding numerical model as the AJ-MMC model. Different from the J-MMC method, the AJ-MMC method applies the zero-tie-line-length criterion to find the MMP at which the corresponding minimum tie-line length is zero. Such methodology originates from the analytical method-of-characteristics (MOC) method [
22,
23,
24,
25,
26,
27]. One notable innovation of the AJ-MMC method is that the authors design a “triangular” MMC model that can calculate all the tie-line lengths numerically at a specified pressure. Besides, a new pressure search algorithm is implemented to update pressure values until the MMP is determined. On the one hand, Ahmadi and Johns [
20] prove that the estimation accuracy of the AJ-MMC method is as high as the MOC method. On the other hand, the AJ-MMC method can only handle two-phase equilibria. The corresponding three-phase version of the AJ-MMC method [
28] shows that the zero-tie-line-length criterion is not strictly valid in a three-phase displacement case.
Both the J-MMC and AJ-MMC methods can estimate MMPs in a faster way than the slim-tube experiments and the slim-tube simulations. But only the J-MMC method can provide the recovery factor information as the AJ-MMC model contains non-physical mechanisms. Another important feature of the J-MMC method is that the procedure to transfer the excessive fluid volume is physical and general, making it naturally extendable to handle three hydrocarbon phases. This indicates that this method can be used to estimate MMPs of three-phase displacement cases with little modifications.
However, to the best of our knowledge, the MMP estimation accuracy of the J-MMC method has yet been compared with the tie-line-based methods (the AJ-MMC and MOC methods). Our first work is to compare the original J-MMC method to the tie-line-based methods.
Appendix A shows the detailed comparison. We obtain two observations from the comparative analysis. Firstly, the MMPs obtained from the J-MMC method are less accurate than the ones from the tie-line-based methods. Secondly, the pressure search algorithm of the J-MMC method fails in several cases, including the case where the oil-gas MMP is lower than the saturation pressure of the crude oil.
Therefore, the motivation of this paper is to propose a modified MMC method based on the original J-MMC method to increase its robustness, improve its estimation accuracy, and enhance its computational accuracy. This paper is organized as follows. In “Methodology”, we provide a modified MMC model and a new pressure search algorithm. In “Results and Discussion”, we verify the improvements of the modified method and apply the method to estimate the MMPs of several two-phase displacement cases. The MMP estimates are compared with the ones calculated by the original J-MMC method, tie-line-based methods, and slim-tube methods. Finally, the conclusions are drawn in “Conclusions”.