RSM for Modelling the CO2 Effect in the Interfacial Tension Between Brine and Waxy Dulang Crude Oil During LSW-WAG EOR

Elastic wave-based oil mobilization of residual oil in heterogeneous reservoirs is a viable, low-cost, and green technology method of enhanced oil recovery (EOR). Applications for elastic (seismic) waves at the reservoir scale are currently in the preliminary stages of investigation and development. We employ a two-layer numerical finite element method (FEM) in this research to investigate the possibility of effective propagation of seismic waves in the low permeability area of a mature oil reservoir when seismic stress load is delivered to the rock matrix via a downhole source. The purpose of this research is to evaluate the potential of fluid and rock matrix displacement amplitudes for crossflow generation in a mature oil reservoir. In a low permeability formation, the numerical results reveal that, as the observation radius approaches the reservoir boundary, the rock matrix time-domain displacement performs better as a wave propagation parameter than the pore fluid displacement. However, crossflow oscillations at a peak mesoscopic frequency of 3.0 Hz produce an instantaneous oil transfer rate (recovery rate) of 2.5% (bypassed oil) from the low permeability area. This method can be used in combination with water flooding to recover more oil from both high and low-permeability areas. Mesoscopic attenuation frequency can therefore be utilized as one of the indicators to assess oil recovery in heterogeneous oil reservoirs.

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Seismic Wave Excitation of Mature Oil Reservoirs for Green EOR Technology

Abdullahi

Jufar

Dzulkarnain³

et al. 2023

“…Fossil energy, specifically hydrocarbons, remains the main energy source worldwide [1][2][3][4]. Hydrocarbons can be produced in the form of gases or oil and can be produced from conventional and unconventional reservoirs [5][6][7]. The rocks that contain conventional hydrocarbon resources (e.g., sandstone) are well-known for having good porosity and permeability [8].…”

Section: Introductionmentioning

confidence: 99%

A Study on the Production Performance of a Horizontal Shale Gas Well Using a Fully Coupled Flow and Geomechanics Modeling

Al-Shami

Jufar

Abdullahi

et al. 2023

Conventional petroleum reservoir simulators use constant rock compressibility to denote rock deformation. However, due to the stress-sensitive nature of the shale formations, using constant rock compressibility in reservoir simulators does not accurately capture the pressure diffusion in the reservoir, leading to a higher error margin in flow rate estimation. Fluid flow coupling with geomechanics is used to account for such a phenomenon numerically. Such an approach is important for shale numerical studies and any energy underground storage modeling (i.e., CO2 storage). Usually, when fluid flow coupling with geomechanics is studied for shale formations, the fluid, and the stimulated reservoir petrophysical properties are overlooked. This paper aims to present a study on the effect of the fluid and reservoir petrophysical properties on the performance of a gas-producing well. In addition, the results from the cases when geomechanics is coupled and decoupled with fluid flow in reservoir simulations are compared. The governing equations were discretized using the Finite Element Method. First, the model was validated against Terzaghi's consolidation theory analytical solution. After that, a history matching for the production flow rate was performed using field production data from Barnett Shale. Then a sensitivity analysis was carried out for the gas viscosity, Stimulated Reservoir Volume (SRV) porosity, and fracture conductivity. Next, the sensitivity analysis was conducted for the coupled and decoupled cases. Finally, the sensitivity analysis results were compared between the coupled and decoupled cases. The results show that lower gas viscosity, higher SRV porosity, and higher fracture conductivity improved horizontal well production performance. In addition, when the geomechanical effects were decoupled, the reservoir simulator overestimated the production flow rate and cumulative production.

“…Gas solubility, vapor-liquid equilibria (VLE) and the related applications have been intensively reported for carbon dioxide (CO2) to apply to new technologies [10][11][12][13][14][15]. However, there are not so many researches of solubility and VLE for CO2 in MMA or EGDMA.…”

Section: Introductionmentioning

confidence: 99%

Peng-Robinson Cubic Equation of State Based on Key Group Contribution and Calculation of Nitrogen Gas Solubility in MMA Dimer

Mohamed

Chong

Lai

et al. 2021

Previously authors have reported facts that nitrogen (N2) and oxygen solubilities in styrene is the same as those in benzene and divinylbenzene at 303 K. Though the three compounds have an atomic composition, (CH)n (n=6, 8 and 10), the gas solubilities are thought to depend on the number of aromatic carbons in the solution. Then, authors named it ‘a key group in solubility’. In this research, the key group was investigated for N2 solubility in methyl methacrylate (MMA) and its dimer, ethylene glycol dimethacrylate (EGDMA). Therefore, the calculations were carried out by Peng-Robinson (PR) equation of state based on group contribution methods. The experimental data employed were those of Lai et al., where N2 solubility are reported in MMA at 303 K. The N2 solubility in EGDMA was assumed to be double of that in MMA at 303 K, because EGDMA has two MMA units in the molecule. Two types of group contribution methods were proposed to calculate N2 solubility in EGDMA. One was for the critical temperature and pressure proposed by Joback and Reid. Using these properties, the attractive and excluded volume parameters in PR equation were evaluated for EGDMA. Other was similar to a method proposed by Orbey and Sandler. The excluded volume parameter in PR equation can be evaluated from those of MMA by multiplying the number of repeating units, and the attractive by multiplying the squared number. Instead of the method, the powers were proposed to be 3/4 and 3/2 for the excluded volume and attractive perimeters, respectively. The powers were come from a scaling theory by de Gennes. The binary parameter for N2 – EGDMA was also set to k12 = 0.224, which was the same as that for N2 –MMA. The calculated N2 solubility in EGDMA was far smaller than the hypothetical N2 solubility in EGDMA at 303 K. Otherwise, to reproduce the hypothetical N2 solubility, a quite different value, k12 = -0.044, was necessary for the method by Joback and Reid. The results suggested that a key group for gas solubility will not be accepted in MMA.