CN111208048A - Jamin effect dynamic change quantitative characterization method based on phase permeation test - Google Patents
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- 238000004364 calculation method Methods 0.000 claims description 16
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Abstract
The invention discloses a Giardia effect dynamic change quantitative characterization method based on a phase permeability test, which utilizes oil-water relative permeability values under different water saturation obtained by a phase permeability curve test to quantitatively characterize the Giardia effect dynamic change by the ratio of oil-water two-phase flow injection pressure difference under different water saturation to single-phase oil flow injection pressure difference under irreducible water saturation, can truly reflect the process that the Giardia effect degree changes along with the fluid saturation in the water flooding process, and provides a new method for quantitatively characterizing the Giardia effect. The method can be used for evaluating the Jamin effect change in the water drive process of different types of oil reservoirs.
Description
Technical Field
The invention belongs to the technical field of oil layer physical core analysis, and particularly relates to a Jamin effect dynamic change quantitative characterization method based on a phase permeability test.
Background
The low permeability reservoir is mainly characterized by small pore radius of fluid flow and large flow resistance, and particularly, the interaction between liquid-liquid or gas-liquid interfaces has larger influence on water injection development. The giardiasis effect is an additional drag effect that occurs when globules (liquid globules or bubbles) in a liquid-liquid or gas-liquid two-phase seepage flow pass through a pore throat or pore throat. The Jamin effect is ubiquitous in the porous medium of hydrocarbon reservoirs. Compared with a medium-high-permeability oil reservoir, the capillary resistance generated by liquid beads or bubbles in the multiphase seepage process of the low-permeability compact oil and gas reservoir is superposed to have a huge value, and the influence on the fluid seepage cannot be ignored.
The conventional Gi sensitivity effect quantitative characterization is generally represented by a Gi sensitivity index, the method refers to an evaluation standard of sensitivity in a reservoir sensitivity experiment evaluation method SY/T5358-2012, and the permeability injury degree is taken as the evaluation standard of the Gi sensitivity effect. However, the method cannot truly reflect the dynamic change process of the Jamin effect in the flowing process of the multiphase fluid, and can only represent the size of the Jamin effect at the end of injection. In the process of water (gas) injection of an actual oil reservoir, the Jamin effect also dynamically changes along with the change of the fluid saturation, and the parameter cannot give consideration to the dynamic change process and the final result of the Jamin effect along with the fluid injection process.
Disclosure of Invention
Aiming at the problem that the conventional method for quantitatively characterizing the Jamin effect cannot truly reflect the dynamic change of the Jamin effect in a porous medium along with the fluid saturation, the method for dynamically characterizing the Jamin effect based on the water-driven oil phase permeability curve is provided according to the fact that the Jamin effect is an additional resistance effect in the two-phase (multi-phase) flow process and the relative permeability is a reaction of the two-phase flow resistance.
In order to achieve the purpose, the invention adopts the following technical scheme:
a Jamin effect dynamic change quantitative characterization method based on a phase permeation test utilizes a phase permeation curve test to obtain water phase relative permeability K under different water saturationrwRelative permeability to oil phase KroAnd characterizing dynamic change of the Jamin effect by the ratio of the oil-water two-phase flow injection pressure difference under different water saturation degrees to the single-phase oil flow injection pressure difference under the irreducible water saturation degree.
Further, dynamic changes in the Jamin effect are recorded as Jamin coefficient J (S)w) Jamin coefficient J (S)w) The calculation formula of (2) is as follows:
in the formula: krwRelative permeability of the aqueous phase, KroRelative permeability of the oil phase, KreRelative permeability at the point of isotonicity; mu.swThe viscosity of the experimental water at the reservoir temperature; mu.soThe viscosity of the experimental oil at the reservoir temperature;
the oil-water viscosity ratio.
Further, Jamin coefficient J (S)w) The derivation of the calculation formula is as follows:
the flow rate Q when the monophase oil flows at irreducible water saturation is calculated as:
when oil-water two-phase flow is carried out:
1) water flow rate Q in oil-water two-phase flow processwThe calculation formula of (2) is as follows:
2) oil and waterFlow rate Q of phase flow process oiloThe calculation formula of (2) is as follows:
when Q is Qo+QWThen, it can be obtained from the formulae (1) to (3):
in the above formula: q is the flow rate at which the single phase oil flows at the irreducible water saturation; qwThe water flow rate is the oil-water two-phase flow process; qoThe flow rate of oil in the oil-water two-phase flow process; koMaximum permeability of oil phase for single-phase oil flow under irreducible water saturation, cross-sectional area of core A, length of core L, △ P1Pressure difference between injection and production when single-phase oil flows under irreducible water saturation △ P2Injection-production pressure difference when oil-water phase flows under the saturation of the bound water.
Further, the viscosity of the experimental water at reservoir temperature, muwThe formation crude oil physical property analysis method is adopted to measure the formation crude oil physical property.
Further, the viscosity of the experimental oil at reservoir temperature, μoThe formation crude oil physical property analysis method is adopted to measure the formation crude oil physical property.
Further, relative permeability K of the aqueous phaserwThe method is measured according to a method for measuring the relative permeability of the two-phase fluid in the rock.
Further, relative permeability K of oil phaseroThe method is measured according to a method for measuring the relative permeability of the two-phase fluid in the rock.
Further, the Jamin coefficient J (S) at the isotonic pointw) And the maximum value exists, and the calculation formula of the gamma coefficient is as follows:
Krerelative permeability at the point of isotonicity.
Compared with the prior art, the method has at least the following beneficial technical effects that the dynamic change of the Jamin effect is quantitatively represented by the ratio of the oil-water two-phase flow injection pressure difference under different water saturation degrees and the single-phase oil flow injection pressure difference under the irreducible water saturation degree by utilizing the oil-water relative permeability values under different water saturation degrees obtained by the phase permeability curve test, the process that the Jamin effect degree changes along with the fluid saturation degree in the water flooding process can be truly reflected, and a novel method is provided for quantitatively representing the Jamin effect. The method can be used for evaluating the change of the Jamin coefficient along with the fluid saturation in the water flooding process of different types of oil reservoirs.
The sensitivity coefficient is an additional resistance effect caused by capillary force superposition in the multiphase flow process, the phase permeation curve is used for researching the relation between multiphase flow saturation and relative permeability, the distribution state of oil and water in a porous medium is changed due to the change of the saturation in different stages, and therefore the degree of the capillary resistance superposition effect is changed. In theory, the flow resistance in single-phase flow is viscous force, the resistance in multiphase flow comprises viscous force and tube force, and the difference between the viscous force and the tube force is the resistance superposition caused by multiphase flow. Therefore, the dimensionless fold increase of flow resistance due to the Jamin effect can be reflected by the ratio of the oil-water two-phase flow injection pressure differential at different water saturations to the single-phase oil flow injection pressure differential at the irreducible water saturation.
Drawings
FIG. 1 is a schematic diagram of dynamic changes of oil-water phase permeability and Jamin coefficient in a 2.19mD water flooding process;
FIG. 2 is a schematic diagram of dynamic changes of oil-water phase permeability and Jamin coefficient in the process of oil displacement with water at K ═ 0.86 mD.
Detailed Description
The present invention will be described in detail below with reference to the accompanying drawings and specific embodiments.
A Jamin effect dynamic change quantitative characterization method based on a phase permeability test is characterized in that oil-water relative permeability values under different water saturation obtained by testing oil-water relative permeability of oil-water in a rock core are utilized, and Jamin effect dynamic change is quantitatively characterized by the ratio of oil-water two-phase flow injection pressure difference under different water saturation to single-phase oil flow injection pressure difference under irreducible water saturation, wherein the ratio is a reaction of Jamin effect degree and is also called Jamin coefficient.
And (3) a Jamin coefficient calculation formula derivation process:
the flow rate Q when the monophase oil flows at irreducible water saturation is calculated as:
when oil-water two-phase flow is carried out:
1) water flow rate Q in oil-water two-phase flow processwThe calculation formula of (2) is as follows:
2) oil flow rate Q in oil-water two-phase flow processoThe calculation formula of (2) is as follows:
at the same flow rate; i.e. Q ═ Qo+QwWhen the temperature of the water is higher than the set temperature,
namely, it is
In the formula:
q-flow velocity in the flow of monophase oil at irreducible water saturation, cm3/min；
QwWater flow velocity in cm during oil-water two-phase flow3/min；
Qo-flow velocity of oil in oil-water two-phase flow process, cm3/min；
KoThe maximum permeability of the oil phase during the flow of the single-phase oil at irreducible water saturation, 10-3μm2；
A-Cross-sectional area of core, cm2；
L is the core length, cm;
△P1-injection and production differential pressure, MPa, when the monophase oil flows under the irreducible water saturation;
△P2the injection-production pressure difference is MPa when the oil-water phase flows under the saturation of the bound water;
Krwrelative permeability of the aqueous phase, KroRelative permeability of the oil phase, KreThe relative permeability of the isotonic point is decimal;
μwthe viscosity of experimental water at reservoir temperature, mPa · s; mu.soThe viscosity of the experimental oil at the reservoir temperature, mPa · s;
J(Sw) -gamma coefficient, dimensionless.
J(Sw) The physical meaning of (a) is a dimensionless multiple of the two-phase flow injection pressure differential compared to the single-phase oil flow injection pressure differential at the same flow rate. Since the relative permeability is influenced by the water saturation, the course of the Giardian effect as a function of the water saturation can be calculated by the above formula. Meanwhile, the maximum value of the gamma coefficient is at the isotonic point, and the calculation formula is as follows:
the key parameters are obtained as follows:
(1) and (3) testing the viscosity of the fluid: according to SY/T5542-2000 stratum crude oil physical property analysis method, the viscosity of crude oil and stratum water at the oil reservoir temperature is tested, and the oil-water viscosity ratio is calculated
(2) Obtaining a relative permeability value: obtaining the relative permeability value of oil and water and the relative permeability K of an isotonic point under different water saturation degrees according to SY/T5354-2007 determination of relative permeability of two-phase fluid in rockre；
(3) And calculating the gamma sensitivity coefficients of different water saturation according to the formula to obtain a dynamic change curve of the gamma sensitivity coefficients along with the water saturation and the maximum gamma sensitivity coefficient at an isotonic point.
Example 1: dynamic change of Jamin effect in reservoir water flooding process when K is 2.19mD
The length of rock sample is 7.6cm, the diameter is 2.50cm, the gas permeability is 2.19mD, the experimental temperature is 50 ℃, the oil-water viscosity ratio is 2.0, and the oil-water phase permeability curve is obtained by water displacement, such as K in figure 1rwAnd KroShown; in fig. 1, the abscissa is the water saturation, the left ordinate is the relative permeability obtained by the experimental test, and the right ordinate is the gamma sensitivity coefficient obtained by the established method; and then obtaining a change curve of the gamma coefficient along with the water saturation according to the established gamma coefficient calculation formula, wherein the maximum value of the gamma coefficient is 2.67 at the isotonic point.
Example 2: dynamic change of Jamin effect in reservoir water flooding process when K is 0.26mD
The length of rock sample is 8.2cm, the diameter is 2.52cm, the gas permeability is 0.26mD, the experimental temperature is 50 ℃, the oil-water viscosity ratio is 2.0, and the oil-water phase permeability curve is obtained by water displacement, such as K in figure 2rwAnd KroIn fig. 2, the abscissa represents the water saturation, the left ordinate represents the relative permeability obtained by the experimental test, and the right ordinate represents the gamma sensitivity coefficient calculated by the method of the present invention; and obtaining a change curve of the gamma coefficient along with the water saturation according to the established gamma coefficient calculation formula, wherein the maximum value of the gamma coefficient is 5.29 at the isotonic point.
The above-mentioned contents are only for illustrating the technical idea of the present invention, and the protection scope of the present invention is not limited thereby, and any modification made on the basis of the technical idea of the present invention falls within the protection scope of the claims of the present invention.
Claims (8)
1. A Jamin effect dynamic change quantitative characterization method based on a phase permeation test is characterized in that a phase permeation curve test is utilized to obtain water phase relative permeability K under different water saturation degreesrwRelative permeability to oil phase KroAnd characterizing dynamic change of the Jamin effect by the ratio of the oil-water two-phase flow injection pressure difference under different water saturation degrees to the single-phase oil flow injection pressure difference under the irreducible water saturation degree.
2. The method for quantitatively characterizing the dynamic change of the Jamin effect based on the phase-permeation test of claim 1, wherein the dynamic change of the Jamin effect is recorded as a Jamin coefficient J (S)w) The Jamin coefficient J (S)w) The calculation formula of (2) is as follows:
in the formula: kroRelative permeability of the oil phase, KrwRelative permeability of the aqueous phase, μwIs the viscosity, mu, of experimental water at reservoir temperatureoIs the viscosity of the experimental oil at the reservoir temperature,
the oil-water viscosity ratio.
3. The dynamic Jamin effect change quantitative characterization method based on the phase permeation test as claimed in claim 2, characterized in that the Jamin coefficient J (S) isw) The derivation of the calculation formula is as follows:
the flow rate Q when the monophase oil flows at irreducible water saturation is calculated as:
when oil-water two-phase flow is carried out:
1) water flow rate Q in oil-water two-phase flow processwThe calculation formula of (2) is as follows:
2) oil flow rate Q in oil-water two-phase flow processoThe calculation formula of (2) is as follows:
when Q is Qo+QWThen, it can be obtained from the formulae (1) to (3):
in the above formula: q is the flow rate at which the single phase oil flows at the irreducible water saturation; qwThe water flow rate is the oil-water two-phase flow process; qoThe flow rate of oil in the oil-water two-phase flow process; koFor the maximum permeability of oil phase during the flowing of single-phase oil under the irreducible water saturation, A is the cross-sectional area of the core, L is the length of the core, △ P1△ P for injection-production pressure difference during single-phase oil flow under irreducible water saturation2The injection-production pressure difference is adopted when oil-water two-phase flow is carried out under the irreducible water saturation.
4. The method for quantitatively characterizing the Jamin effect dynamic change based on the phase-permeation test as claimed in claim 2, wherein the viscosity μ of the experimental water at the reservoir temperaturewMeasured according to the physical property analysis method of the crude oil in the stratum.
5. The method for quantitatively characterizing the Jamin effect dynamic change based on the phase-permeation test as claimed in claim 2, wherein the viscosity μ of the experimental oil at the reservoir temperatureoMeasured according to the physical property analysis method of the crude oil in the stratum.
6. The dynamic Jamin effect change quantitative characterization method based on the phase permeation test according to claim 2, characterized in that the relative permeability K of the water phase isrwThe method is measured according to a method for measuring the relative permeability of the two-phase fluid in the rock.
7. The dynamic Jamin effect change quantitative characterization method based on the phase permeation test according to claim 2, characterized in that the oil phase relative permeability K isroThe method is measured according to a method for measuring the relative permeability of the two-phase fluid in the rock.
8. The dynamic Jamin effect change quantitative characterization method based on the phase permeation test as claimed in claim 2, characterized in thatJamin coefficient J (S) at the point of percolationw) And the maximum value exists, and the calculation formula of the gamma coefficient is as follows:
Krerelative permeability at the point of isotonicity.
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