Alkaline-Surfactant-Polymer Formulation Evaluation In Live Oil Conditions: The Impact Of Temperature, Pressure And Gas On Oil Recovery Performance

Summary An improved heterogeneity/homogeneity index is introduced that uses the shear-strain rate of the single-phase-velocity field to characterize heterogeneity and rank geological realizations in terms of their impact on secondary-recovery performance. The index is compared with the Dykstra-Parsons coefficient (Dykstra and Parsons 1950) and the dynamic Lorenz coefficient (Shook and Mitchell 2009). The results show that the index's ranking ability is preserved for miscible and immiscible displacements at different viscosity/mobility ratios. Neither the Dykstra-Parsons coefficient (Dykstra and Parsons 1950) nor the dynamic Lorenz coefficient (Shook and Mitchell 2009) can consistently discriminate between different realizations in terms of breakthrough time and oil recovery at 1 pore volume injected (PVI) for tracer flow or adverse-viscosity-ratio miscible and immiscible floods.

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SOME SPECIFIC FEATURES OF THE IMPACT OF GEOLOGICAL-TECHNICAL MEASURES ON THE EFFICIENCY OF OIL RECOVERY ENHANCEMENT BY USING A NON-STATIONARY (CYCLIC) WATER-FLOODING

Oilfield Engineering ◽

10.30713/0207-2351-2018-10-26-34 ◽

2018 ◽

pp. 26-34

Author(s):

M.R. Dulkarnaev ◽

◽

N.P. Zakharova ◽

N.A. Demyanenko ◽

E.N. Malshakov ◽

...

Keyword(s):

Oil Recovery ◽

Water Flooding ◽

The Impact ◽

Technical Measures

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Experimental study of the supercritical CO 2 diffusion coefficient in porous media under reservoir conditions

Royal Society Open Science ◽

10.1098/rsos.181902 ◽

2019 ◽

Vol 6 (6) ◽

pp. 181902 ◽

Cited By ~ 1

Author(s):

Junchen Lv ◽

Yuan Chi ◽

Changzhong Zhao ◽

Yi Zhang ◽

Hailin Mu

Keyword(s):

Porous Media ◽

Diffusion Coefficient ◽

Oil Recovery ◽

Carbon Capture ◽

Carbon Capture And Storage ◽

Elevated Pressure ◽

Experimental Results ◽

Saturated Porous Media ◽

Reservoir Conditions ◽

The Impact

Reliable measurement of the CO 2 diffusion coefficient in consolidated oil-saturated porous media is critical for the design and performance of CO 2 -enhanced oil recovery (EOR) and carbon capture and storage (CCS) projects. A thorough experimental investigation of the supercritical CO 2 diffusion in n -decane-saturated Berea cores with permeabilities of 50 and 100 mD was conducted in this study at elevated pressure (10–25 MPa) and temperature (333.15–373.15 K), which simulated actual reservoir conditions. The supercritical CO 2 diffusion coefficients in the Berea cores were calculated by a model appropriate for diffusion in porous media based on Fick's Law. The results show that the supercritical CO 2 diffusion coefficient increases as the pressure, temperature and permeability increase. The supercritical CO 2 diffusion coefficient first increases slowly at 10 MPa and then grows significantly with increasing pressure. The impact of the pressure decreases at elevated temperature. The effect of permeability remains steady despite the temperature change during the experiments. The effect of gas state and porous media on the supercritical CO 2 diffusion coefficient was further discussed by comparing the results of this study with previous study. Based on the experimental results, an empirical correlation for supercritical CO 2 diffusion coefficient in n -decane-saturated porous media was developed. The experimental results contribute to the study of supercritical CO 2 diffusion in compact porous media.

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Waterflooding in Carbonate Reservoirs: Does the Salinity Matter?

SPE Reservoir Evaluation & Engineering ◽

10.2118/170254-pa ◽

2014 ◽

Vol 17 (03) ◽

pp. 304-313 ◽

Cited By ~ 50

Author(s):

A.M.. M. Shehata ◽

M.B.. B. Alotaibi ◽

H.A.. A. Nasr-El-Din

Keyword(s):

Oil Recovery ◽

Sudden Change ◽

Oil Production ◽

Deionized Water ◽

Production Performance ◽

Shallow Aquifer ◽

Secondary Recovery ◽

Tertiary Recovery ◽

The Impact ◽

Indiana Limestone

Summary Waterflooding has been used for decades as a secondary oil-recovery mode to support oil-reservoir pressure and to drive oil into producing wells. Recently, the tuning of the salinity of the injected water in sandstone reservoirs was used to enhance oil recovery at different injection modes. Several possible low-salinity-waterflooding mechanisms in sandstone formations were studied. Also, modified seawater was tested in chalk reservoirs as a tertiary recovery mode and consequently reduced the residual oil saturation (ROS). In carbonate formations, the effect of the ionic strength of the injected brine on oil recovery has remained questionable. In this paper, coreflood studies were conducted on Indiana limestone rock samples at 195°F. The main objective of this study was to investigate the impact of the salinity of the injected brine on the oil recovery during secondary and tertiary recovery modes. Various brines were tested including deionized water, shallow-aquifer water, seawater, and as diluted seawater. Also, ions (Na+, Ca2+, Mg2+, and SO42−) were particularly excluded from seawater to determine their individual impact on fluid/rock interactions and hence on oil recovery. Oil recovery, pressure drop across the core, and core-effluent samples were analyzed for each coreflood experiment. The oil recovery using seawater, as in the secondary recovery mode, was, on the average, 50% of original oil in place (OOIP). A sudden change in the salinity of the injected brine from seawater in the secondary recovery mode to deionized water in the tertiary mode or vice versa had a significant effect on the oil-production performance. A solution of 20% diluted seawater did not reduce the ROS in the tertiary recovery mode after the injection of seawater as a secondary recovery mode for the Indiana limestone reservoir. On the other hand, 50% diluted seawater showed a slight change in the oil production after the injection of seawater and deionized water slugs. The Ca2+, Mg2+, and SO42− ions play a key role in oil mobilization in limestone rocks. Changing the ion composition of the injected brine between the different slugs of secondary and tertiary recovery modes showed a measurable increase in the oil production.

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Understanding the Enhanced Oil Recovery Performance of Low Salinity Water Injection: Which Mechanism is Predominant?

10.3997/2214-4609.202113065 ◽

2021 ◽

Author(s):

K. Hassani ◽

A. Saeibehrouzi ◽

B. Rostami ◽

A. Fathollahi

Keyword(s):

Enhanced Oil Recovery ◽

Oil Recovery ◽

Water Injection ◽

Low Salinity ◽

Low Salinity Water ◽

Salinity Water ◽

Recovery Performance ◽

Low Salinity Water Injection

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Modeling to support physicochemical enhancement techniques

Oil and Gas Studies ◽

10.31660/0445-0108-2021-3-79-90 ◽

2021 ◽

pp. 79-90

Author(s):

Т. A. Pospelova

Keyword(s):

Enhanced Oil Recovery ◽

Oil Recovery ◽

Oil And Gas ◽

Chemical Modeling ◽

Comparative Structure ◽

Water Cut ◽

Physical And Chemical ◽

Oil And Gas Companies ◽

The Impact ◽

Selection Of

The article discusses ways to increase the oil recovery factor in already developed fields, special attention is paid to the methods of enhanced oil recovery. The comparative structure of oil production in Russia in the medium term is given. The experience of oil and gas companies in the application of enhanced oil recovery in the fields is analyzed and the dynamics of the growth in the use of various enhanced oil recovery in Russia is estimated. With an increase in the number of operations in the fields, the requirements for the selection of candidates inevitably increase, therefore, the work focuses on hydrodynamic modeling of physical and chemical modeling, highlights the features and disadvantages of existing simulators. The main dependences for adequate modeling during polymer flooding are given. The calculation with different concentration of polymer solution is presented, which significantly affects the water cut and further reduction of operating costs for the preparation of the produced fluid. The possibility of creating a specialized hydrodynamic simulator for low-volume chemical enhanced oil recovery is considered, since mainly simulators are applicable for chemical waterflooding and the impact is on the formation as a whole.

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The Impact of Ionic Liquid and Nanoparticles on Stabilizing Foam for Enhanced Oil Recovery

ChemistrySelect ◽

10.1002/slct.201802404 ◽

2018 ◽

Vol 3 (44) ◽

pp. 12461-12468

Author(s):

Lei Jiang ◽

Jingtao Sun ◽

Jiqian Wang ◽

Qi Xue ◽

Songyan Li ◽

...

Keyword(s):

Ionic Liquid ◽

Enhanced Oil Recovery ◽

Oil Recovery ◽

The Impact

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Investigation of Oil Recovery in Fractured Carbonate Rock by

Energy and Environment Research ◽

10.5539/eer.v6n1p14 ◽

2016 ◽

Vol 6 (1) ◽

pp. 14

Author(s):

H. Karimaie ◽

O. Torsæter

Keyword(s):

Oil Recovery ◽

Gas Injection ◽

Water Injection ◽

Co2 Injection ◽

Recovery Method ◽

Asmari Limestone ◽

Fractured Carbonate ◽

Efficient Recovery ◽

Live Oil ◽

Non Equilibrium

The purpose of the three experiments described in this paper is to investigate the efficiency of secondary andtertiary gas injection in fractured carbonate reservoirs, focusing on the effect of equilibrium gas,re-pressurization and non-equilibrium gas. A weakly water-wet sample from Asmari limestone which is the mainoil producing formation in Iran, was placed vertically in a specially designed core holder surrounded withfracture. The unique feature of the apparatus used in the experiment, is the capability of initializing the samplewith live oil to obtain a homogeneous saturation and create the fracture around it by using a special alloy whichis easily meltable. After initializing the sample, the alloy can be drained from the bottom of the modified coreholder and create the fracture which is filled with live oil and surrounded the sample. Pressure and temperaturewere selected in the experiments to give proper interfacial tensions which have been measured experimentally.Series of secondary and tertiary gas injection were carried out using equilibrium and non-equilibrium gas.Experiments have been performed at different pressures and effect of reduction of interfacial tension werechecked by re-pressurization process. The experiments showed little oil recovery due to water injection whilesignificant amount of oil has been produced due to equilibrium gas injection and re-pressurization. Results alsoreveal that CO2 injection is a very efficient recovery method while injection of C1 can also improve the oilrecovery.

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