New Optimization Criteria of Waterflood Patterns Preventing Premature Water Breakthrough in The Context of Water-Oil Displacement Front Instability

2021 ◽  
Author(s):  
A.Kh Shakhverdiev ◽  
A.V Denisov ◽  
V.D Tumanova
Keyword(s):  
Optimization Criteria ◽  
Oil Displacement ◽  
Front Instability ◽  
Displacement Front ◽  
Water Breakthrough

scholarly journals Effect of Surface Wettability on Immiscible Displacement in a Microfluidic Porous Media

Energies ◽  
2019 ◽  
Vol 12 (4) ◽  
pp. 664 ◽  
Author(s):  
Jorge Avendaño ◽  
Nicolle Lima ◽  
Antonio Quevedo ◽  
Marcio Carvalho
Keyword(s):  
Porous Media ◽  
Water Injection ◽  
Residual Oil ◽  
Strong Function ◽  
Fluid Displacement ◽  
Oil Displacement ◽  
Displacement Front ◽  
Final Volume ◽  
Displacement Experiments ◽  
Effect Of Surface

Wettability has a dramatic impact on fluid displacement in porous media. The pore level physics of one liquid being displaced by another is a strong function of the wetting characteristics of the channel walls. However, the quantification of the effect is still not clear. Conflicting data have shown that in some oil displacement experiments in rocks, the volume of trapped oil falls as the porous media becomes less water-wet, while in some microfluidic experiments the volume of residual oil is higher in oil-wet media. The reasons for this discrepancy are not fully understood. In this study, we analyzed oil displacement by water injection in two microfluidic porous media with different wettability characteristics that had capillaries with constrictions. The resulting oil ganglia size distribution at the end of water injection was quantified by image processing. The results show that in the oil-wet porous media, the displacement front was more uniform and the final volume of remaining oil was smaller, with a much smaller number of large oil ganglia and a larger number of small oil ganglia, when compared to the water-wet media.

scholarly journals Assessment of the Influence of Water Saturation and Capillary Pressure Gradients on Size Formation of Two-Phase Filtration Zone in Compressed Low-Permeable Reservoir

2020 ◽  
Vol 245 ◽  
pp. 569-581
Author(s):  
Valentin Korotenko ◽  
Sergei Grachev ◽  
Nelly Kushakova ◽  
Semyon Mulyavin
Keyword(s):  
Pressure Gradient ◽  
Capillary Pressure ◽  
Lower Limit ◽  
Water Saturation ◽  
Pressure Variation ◽  
Saturation Ratio ◽  
Two Phase ◽  
Oil Displacement ◽  
Displacement Front ◽  
Capillary Pressure Gradient

The paper examines the influence of capillary pressure and water saturation ratio gradients on the size of the two-phase filtration zone during flooding of a low-permeable reservoir. Variations of water saturation ratio s in the zone of two-phase filtration are associated with the pressure variation of water injected into the reservoir; moreover the law of variation of water saturation ratio s(r, t) must correspond to the variation of injection pressure, i.e. it must be described by the same functions, as the functions of water pressure variation, but be subject to its own boundary conditions. The paper considers five options of s(r, t) dependency on time and coordinates. In order to estimate the influence of formation and fluid compressibility, the authors examine Rapoport – Lis model for incompressible media with a violated lower limit for Darcy’s law application and a time-dependent radius of oil displacement by water. When the lower limit for Darcy’s law application is violated, the radius of the displacement front depends on the value of capillary pressure gradient and the assignment of s function.     It is shown that displacement front radii contain coefficients that carry information about physical properties of the reservoir and the displacement fluid. A comparison of two-phase filtration radii for incompressible and compressible reservoirs is performed. The influence of capillary pressure gradient and functional dependencies of water saturation ratio on oil displacement in low-permeable reservoirs is assessed. It is identified that capillary pressure gradient has practically no effect on the size of the two-phase filtration zone and the share of water in the arbitrary point of the formation, whereas the variation of water saturation ratio and reservoir compressibility exert a significant influence thereupon.

STABILITY OF THE OIL DISPLACEMENT FRONT FOR TERRIGENOUS AND CARBONATE RESERVOIRS

2019 ◽  
pp. 69-72
Author(s):  
K.M. Fedorov ◽  
◽  
A.P. Shevelev ◽  
Ya.A. Kryazhev ◽  
V.A. Kryazhev ◽  
...  
Keyword(s):  
Carbonate Reservoirs ◽  
Oil Displacement ◽  
Displacement Front

Laboratory Studies of High-Temperature-Compound Steam Drive on Heavy Oil

2012 ◽  
Vol 524-527 ◽  
pp. 1185-1189
Author(s):  
Hai Huang ◽  
Wei Shi Zheng ◽  
Bo Chen ◽  
Yi Fei Liu
Keyword(s):  
High Temperature ◽  
Heavy Oil ◽  
Formation Condition ◽  
Displacement Efficiency ◽  
Oil Displacement ◽  
Water Breakthrough ◽  
Steam Drive ◽  
Oil Flow ◽  
Oil Displacement Efficiency ◽  
Gas Drive

This paper presents experimental work on the research of the mechanism of oil displacement of steam drive and high-temperature-compound steam drive, which in order to improve the conventional steam drive technology and increase the recovery of heavy oil. Many experiments were done with the sand-packed model under the formation condition. The results show that: (a) the high-temperature-compound steam drive could extend the water breakthrough time, increase the permeability of oil phase, reduce the residual oil saturation; (b) reducing the viscosity by CO2 dissolution, maintaining the pressure, improving the oil flow ratio, dissolved gas drive，Improving oil displacement efficiency，all of above were the increase production mechanism of high- temperature-compound steam drive.

scholarly journals DETERMINATION OF WATER FLOW DIRECTIONS AT FORMATION FLOODING

2016 ◽  
pp. 50-52
Author(s):  
M. L. Karnaukhov ◽  
Caad A. Faik
Keyword(s):  
Water Flow ◽  
Field Data ◽  
Formation Pressure ◽  
Injection Wells ◽  
Water Flows ◽  
Oil Displacement ◽  
Water Breakthrough ◽  
Flow Directions

The articles considers the possibilities to study the directions of water flows in the reservoir during the oil displacement in the systems of formation pressure maintenance. It is proposed to perform simultaneously the studies in development and injection wells. Additionally, to study the field data permitting to establish the time of water breakthrough to the producers

scholarly journals Mutual Dynamics of Heat Dissipation and Oil Displacement Fronts during In-Situ Oil Combustion. One-Dimensional Simulation

2019 ◽  
Vol 62 (5) ◽  
pp. 445-458
Author(s):  
I. A. Koznacheev ◽  
K. V. Dobrego
Keyword(s):  
Oxygen Concentration ◽  
Combustion Front ◽  
Heat Dissipation ◽  
Front Velocity ◽  
Maximum Temperature ◽  
Oil Viscosity ◽  
One Dimensional ◽  
Oil Displacement ◽  
Displacement Front

One-dimensional axis-symmetrical and plane-symmetrical problem of propagation of the combustion and displacement fronts in oil-containing layer in situ has been considered numerically. Two combustible components, viz. liquid (oil) and solid (kerogen, oil sorbate), were considered. The influence of the blast rate, liquid component viscosity, oxygen concentration in blasted air and heat losses (the width of the oil-containing layer) on the dynamics of the heat dissipation and displacement fronts is investigated. In the cylindrical system the oxidizer flow to the combustion front is reducing over time; and the shift-down of the maximum temperature from the solid combustion front to the oil displacement front takes place (the combustion front “jump”). The time of the “jump” may vary from tenths to hundreds of days and the distance of the shift, – up to 10 or more meters, depending on the parameters of the system. After the “jump”, the combustion rate and maximum temperature continue to deteriorate and after the period of time close to the time lapse before the “jump” the chemical reaction ceases. Herewith the transition of combustion to the liquid phase after the “jump” doesn’t influence notably on oils displacement front speed. The time of the “jump”, as well as the velocity of the mutual combustion (maximum temperature) front and displacement front removal nearly linearly depends on incoming gas blast rate and non-linearly – on oil viscosity. When viscosity is low, the displacement front rapidly runs away from the combustion front, time of the “jump” retards and the distance between the fronts at the instance of the “jump” may reach 10 m or more. The oxygen concentration in the gas being blasted influences significantly on the mutual dynamics of the combustion and displacement fronts since combustion front velocity is proportional to oxygen concentration and displacement front velocity is independent on it. Oxygen enrichment of the gas being blasted just after the “jump” may help localize the area of heat release (combustion) near the oil displacement front. The mentioned manipulation may be utilized for sustainability control of the displacement front. However for its practical implementation it is necessary to have information on concentration and temperature fields inside the layer, which may be obtained from indirect data and via modeling. The results of investigation may be utilized for development of technical projects of oil recovery via in-situ combustion.

Quantitative Characterization of Dynamic Heterogeneity in Reservoirs With Stratified Noncommunicating Layers

2016 ◽  
Vol 139 (1) ◽  
Author(s):  
Yongge Liu ◽  
Huiqing Liu ◽  
Jian Hou ◽  
Qing Wang ◽  
Kai Dong
Keyword(s):  
Numerical Simulation ◽  
Water Injection ◽  
Simulation Method ◽  
Water Flooding ◽  
Injection Technique ◽  
Dynamic Heterogeneity ◽  
Oil Viscosity ◽  
Individual Layer ◽  
Oil Displacement ◽  
Water Breakthrough

Due to the difference of permeability in reservoir and viscosities between oil and water, oil displacement efficiencies at different locations differ significantly. Also, along with the water flooding process, the differences of oil displacement efficiencies change in time and manifest dynamic characteristics, which is called dynamic heterogeneity in this paper. A new parameter called “conductivity index” (IC) is defined, and the Gini coefficient of IC (GCIC) is selected to quantitatively characterize the dynamic heterogeneity in reservoirs with stratified noncommunicating layers. Then, the changing laws and influential factors of GCIC are investigated by physical experiments and numerical simulation methods. Finally, the application of dynamic heterogeneity in individual-layer water injection technique is studied. Based on the theory of seepage flow mechanics, the formula of IC is derived. IC not only contains static parameters including permeability, water, and oil viscosity but also contains dynamic parameters including water and oil relative permeabilities, which are both function of water saturation and also function of rock type. Therefore, IC can reflect the dynamic heterogeneity caused by water flooding process. A five parallel sandpacks' water flooding experiment is conducted to investigate the changes of dynamic heterogeneity. Results show that the value of GCIC increases rapidly before the water breakthrough of the sandpack with highest permeability. Then, after water breakthrough, GCIC decreases slowly. A new parameter GCI is defined to represent the average increase of GCIC during the water flooding process. By numerical simulation method, the influences of Gini coefficient of permeability (GCP) and oil viscosity on GCI are studied. Results show that GCI increases along with the increase of oil viscosity. And GCI first increases and then decreases along with the increase of GCP. When GCP equals 0.6, GCI gets its maximum value. Taking block P of Shengli Oilfield in China, for example, the changes of dynamic heterogeneity along the water flooding process are studied. Results show that the dynamic heterogeneity of each well group varies greatly before and after water flooding. For some well groups, the relative sizes of GCIC even reverse. The performances of different cases in individual-layer water injection technique are investigated by numerical simulation method. Results show that the case both considering dynamic heterogeneity and the remaining oil volume gets the best performance.

One of the feasibilities of oil recovery increase in embedded-inhomogeneous reservoir

2020 ◽  
pp. 20-26
Author(s):  
E.V. Gorshkova ◽  
◽  
E.N. Mamalov ◽  
Keyword(s):  
Oil Recovery ◽  
Natural Water ◽  
High Efficiency ◽  
Recovery Factor ◽  
Low Permeability ◽  
Combined Method ◽  
Reservoir Model ◽  
Oil Displacement ◽  
Displacement Front ◽  
Chemical Agents

The paper reviews the feasibility of oil recovery increase in embedded-ingomogeneous reservoir with hydrodynamically isolated layers of various permeability applying chemical agents. As the chemical agents, electrical-chemical modified natural water (catolyte) and catolyte-based polyacrylamide agent (PAA) are used. For oil recovery increase of the inhomogeneous reservoirs, an ecologically safe catolyte with all the properties characteristic for the alkali is applied. For the alignment of displacement front in the layers of different permeability and the flooding decrease of high-permeable reservoir, the polyacrylamide is used. This combined method was previously conducted in homogenous model and showed high efficiency. It allowed testing the method of oil displacement in embedded-ingomogeneous reservoir model. The effectiveness is achieved using catolyte and catoly- te-based PAA solutions in embedded-inhomogeneous reservoir in oil displacement process. Due to this, the low-permeability la-yer is much more involved into the process and the oil recovery factor increases.

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