... The setup for the MCP estimation is shown schematically in Fig. 1 (a) . The improvements on this design were based on work by Hawthorne et al. (2016) . Three capillary tubes (World Precision Instruments) with an inner diameter of 1.12 mm, 0.84 mm, and 0.68 mm were used in the experiment...

... (undersaturated) and another with 160 bar (below bubble point). This kind of experimental design ( Table 2 ) can add an extra dimension to EOS matching, making the evaluation more robust. Figure 10 Slimtube experiment results for Reservoir II Table 2 Injected gas compositions for Reservoir II...

... Eq. 4 { m i }   i = 1 , … , L These L different models are then deterministically forward simulated by a reservoir simulator that simulates our physical lab experiment to obtain L different data ( Eq. 5 ), each corresponding to a model. The data resulting from...

... the total pore volume (PV), with which the initial oil and water saturations were calculated. Experimental conditions and procedures The huff-n-puff experiment was performed at reservoir temperature of 84 °C, and the pressure for the pressurization cycle was set at 5,000 psi, which is 13.6% higher...

... is achieved, it is maintained constant for the entire duration of the diffusion experiment, using an external pump system ( Fig. 1-b ). Figure 1 (a) High pressure-high temperature cell with transparent windows (yellow box). The cell is kept inside an oven to achieve a target temperature in the tests...

... with concomitant microbial growth indicating the presence of scleroglucan degrading organisms in the inoculum. However, anaerobic samples at temperatures above 60 °C and salinities greater than 7 % retained viscosity during the experiment illustrating polymer stability under conditions similar to those of harsh...

... Abstract Despite promising natural gas huff ‘n’ puff (HnP) field-pilot results, the dominant oil-recovery mechanisms during this process are poorly understood. We conduct systematic natural-gas (C 1 and a mixture of C 1 /C 2 with the molar ratio of 70/30) HnP experiments on an ultratight core...

...' surfactant projects, and Figure 4 shows the locations of the wells included in the program. Surfactant Laboratory Experiments An experimental program was executed from 1990 to 2000 to investigate parameters relevant to the success of surfactant injection in Yates field. Key parameters that were...

.... The aqueous stable surfactants were tested for contact angles on the mineral surface. Seven surfactant candidates were selected for spontaneous imbibition experiments, where oil recovery was monitored as a function of time. Wettability-altering surfactants increase the oil recovery by spontaneous imbibition...

... The SFA experiment were carried out with calcite surfaces in contact for the duration of the experiment. Ideally, the surfaces should be separated by a few micrometers between each data collection. Despite this limitation we nevertheless found interesting and unexpected results, see Results...

... of 38μm. Figure 2 a) Experimental design used for snap-off test. b) Oil bubble generating system including flowrate used for the experiment. c). Pore throat system used for the crude oil snap-off test. During the experiments, the microfluidic device is initially fully saturated...

... on a group of Woodford shale core samples. The oil saturated shale cores were soaked in different urea solutions kept in pressurized (1500 and 4000 psi) and heated extraction vessels at temperature of 250 °F. The adopted treatment step closely simulates the huff-and-puff technique. A series of experiments...

... experimental conditions from the onset of the experiments. It can be seen that fine-textured bubbles with spherical configuration were produced in the HT-HP cell, and then slowly distorted into polyhedra. All the conventional and NCF-CO 2 foams coarsened no later than 28 hours. The proposed NCF-CO 2 foam...

... Abstract Any aqueous solution viscosified by a polymer (or glycerol) should improve the recovery of a very viscous oil to some degree, but it has long been thought that the detailed rheology of the solution would not play a major role. However, recent heavy oil displacement experiments have...

... to the QCM surface, water micro-droplet were visualized with Environmental Scanning Electron Microscopy (ESEM) and their composition was assessed. Duboué et al. (2019a , 2019b ), used experiments with water vapor in order to demonstrate the osmotic nature of the phenomenon. In this paper, the evaluation...

... formulation adsorption enhanced recovery carbonate reservoir experiment field trial surfactant surfactant injection brine oil saturation wettability alteration reservoir characterization complex reservoir coreflood concentration injectivity gain formulation oil recovery reservoir conditions...

... water to enter the matrix pores and pushing oil out. In oil-wet shale reservoirs, this osmotic pressure allows brine imbibition into the matrix that promotes counter-current flow of oil into the fractures. In our research, this phenomenon was studied via carefully designed osmotic imbibition experiments...

... of three kinds of gases, namely, methane, nitrogen, and flue gas. The experimental results indicate that more oil produced in the nitrogen and flue gas injection process compare to the methane, which is caused by the dissolution of methane slug. Moreover, the attic oil development experiment with a strong...

... to be based on experimental measurements. There have been a great amount of experiments on relative permeability in the oil patch but most are a function of wettability and/or media type. Only a few have looked at the effect of composition. Bardon and Longeron (1980) obtained measurements on how relative...

... experiments using fractured tight cores with/without initial water were performed. The experimental results were analyzed by the material balance for components: oil, brine, and surfactant. The analysis resulted in a quantitative evaluation of the imbibed fraction of the injected components (brine...