CN115755195A - Wettability characterization method under reservoir rock simulated production condition - Google Patents
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Abstract
The invention discloses a wettability characterization method under reservoir rock simulated production conditions, which comprises the following steps: fully saturating the rock sample with manganese chloride solution, and testing the nuclear magnetic resonance T of the rock sample 1 ‑T 2 A spectral curve; displacing rock sample with formation crude oil to bound water state, aging at formation temperature, and measuring T 1 ‑T 2 A spectral curve; respectively carrying out water flooding experiments on the aged rock samples under the conditions of simulating different production pressure differences, and measuring the T of the rock samples after displacement pressure differences at all levels 1 ‑T 2 A spectral curve; the completely saturated water, the bound water and the T after each stage of pressure difference displacement 2 Extracting a spectrum curve; t according to bound water state and fully saturated water state 2 The deviation of the spectral curve determines the initial wettability of the rock sample; according to T after displacement pressure difference and under full saturated water at each stage 2 The shift of the spectral curve determines the wettability of the rock sample at each level of displacement pressure differential.The method can determine the wettability and the change characteristics of the reservoir rock at different production stages, and makes up the defect that the conventional wettability scheme cannot dynamically monitor the wettability.
Description
Technical Field
The invention relates to a wettability characterization method under reservoir rock simulation production conditions, and belongs to the technical field of oil and gas exploration and development.
Background
Wettability of reservoir rock refers to the ability or propensity of a fluid in two phases to spread out over the rock surface when the fluid is present in the rock pore space. The wettability of reservoir rock is one of the most basic physical characteristics of a reservoir, and is a key factor influencing the microscopic distribution of oil and water in the pore space of the reservoir rock, the seepage characteristics of fluid in the pore space, and the oil and water saturation of an oil reservoir.
During the development of a hydrocarbon reservoir, the process of substantial fluid displacement in the reservoir rock results in the fluid properties changing constantly, and therefore the wettability of the rock changes with different stages of development. However, the existing commonly used wettability evaluation methods such as the contact angle method, the Amott method and the USBM method can only represent the wettability of the rock in an initial state or a final state, and the dynamic change of the rock wettability in the oil reservoir development process is difficult to represent. At present, the research related to the dynamic change of the reservoir rock wettability is still few, and a set of complete dynamic wettability evaluation flow or an experimental method is not formed for a while. The nuclear magnetic resonance is a technology which can accurately, quickly and nondestructively acquire the interaction information of fluid molecules and the surface of the rock pore, and provides possibility for judging the wetting property of the surface of the rock pore.
The method provides a dynamic wettability evaluation method based on the nuclear magnetic resonance technology, can accurately represent the dynamic change of the reservoir rock wettability under the production condition, and has important significance for the reasonable adjustment of oil reservoir development schemes in different stages and the implementation of the recovery efficiency improvement scheme.
Disclosure of Invention
In order to overcome the problems and the defects in the prior art, the invention provides a wettability characterization method under reservoir rock simulation production conditions, and the invention realizes dynamic characterization of wettability.
The technical scheme provided by the invention for solving the technical problems is as follows: a method for characterizing wettability under reservoir rock simulated production conditions, comprising the steps of:
s1, selecting a plunger rock sample, washing oil and drying the plunger rock sample, and measuring the dry weight, length, diameter, porosity and permeability of the rock sample according to related industry standards, wherein the dry weight, length, diameter, porosity and permeability are respectively recorded as m 0 、L、D、φ He And K;
s2, putting the rock sample into an intermediate container, vacuumizing and pressurizing to saturate a manganese chloride solution with a certain concentration for 48 hours, taking out the rock sample, weighing the rock sample and recording the weight m 1 Calculating the effective porosity of the rock sample according to the formula (1) and the formula (2); when the obtained effective porosity and the porosity obtained by referring to the industrial standard meet the formula (3), judging that the rock sample is vacuumized and saturated to meet the requirement; if the formula (3) is not satisfied, judging that the rock sample is not vacuumized and saturated, and saturating the rock sample again until the formula (3) is satisfied; measuring and simultaneously obtaining nuclear magnetic resonance T of rock sample saturated manganese chloride solution after complete saturation 1 -T 2 A spectral curve;
in the formula: v peff Effective pore volume of rock sample, cm 3 ；
m 1 、m 0 -the mass of the rock sample after saturation and before saturation, g;
ρ -density of fluid for saturation, g/cm 3 ；
φ p -effective porosity, decimal fraction, of the rock sample;
V-Total volume of rock sample, cm 3 。
S3, filling the saturated rock sample into a rock sample holder, connecting a displacement device, and displacing the rock sample with stratum crude oil until water does not flow out, and stopping a displacement experiment; soaking the rock sample after the displacement in the crude oil in the stratum, and aging and recovering for not less than 10 days under the condition of stratum temperature; measuring nuclear magnetic resonance T of rock sample in bound water state after aging is completed 1 -T 2 A spectral curve;
s4, loading the aged rock sample into a rock sample holder, and developing a pre-configured manganese chloride aqueous solution oil displacement experiment with a certain concentration under each stage of displacement pressure difference, wherein the setting of each stage of displacement pressure difference is determined according to the production pressure difference of a reservoir where the rock sample is located, and the displacement pressure difference at least comprises 4 displacement pressure differences, and is increased step by step in the water displacement experiment; stopping the displacement after the pressure difference of each stage of displacement is displaced until oil is not produced any more, and measuring the nuclear magnetic resonance T when the rock sample corresponds to the pressure difference 1 -T 2 Obtaining the nuclear magnetic resonance T of the rock sample under the displacement differential pressure of each level finally by a spectrum curve 1 -T 2 A spectral curve;
s5, carrying out T treatment on the nuclear magnetic resonance water phase in a completely saturated water state, a bound water state and each level of displaced pressure difference 2 Spectral curve from corresponding nuclear magnetic resonance T 1 -T 2 Extracting from a spectral curve;
step S6, calculating T of the rock sample in the completely saturated manganese chloride solution and in the bound water state according to the formula (4) and the formula (5) 2 Geometric mean and calculating the nuclear magnetic resonance T of the reservoir rock according to equation (6) 2 Spectrum migration degree, obtaining initial wettability of reservoir rock;
in the formula: t is a unit of 2gm -the geometric mean of the transverse relaxation times, ms;
φ NMR nuclear magnetic porosity, decimal fraction, of the rock sample;
a-nuclear magnetic resonance T 2 Spectral signal size, dimensionless;
a. b-calibration coefficient, dimensionless;
v-total volume of rock sample, cm 3 ；
T 2 -nuclear magnetic resonance transverse relaxation time, ms;
T 2gm(0) -geometric mean of transverse relaxation times of fully saturated water, ms;
T 2gm(i) -geometric mean of transverse relaxation times of the different states, ms;
i-nuclear magnetic resonance T 2 The degree of spectral shift is dimensionless.
S7, calculating T of the rock sample after water flooding with different displacement differential pressures according to the formulas (4) and (5) 2 Geometric mean value and calculating the nuclear magnetic resonance T of the reservoir rock at different water flooding stages according to the formula (6) 2 And (3) spectrum shifting degree, and acquiring the wettability change condition of the reservoir rock according to the evaluation standard of the table 1.
The further technical scheme is that the mass concentration of the manganese chloride solution with a certain concentration in the step S2 is 4-10g/L.
The further technical scheme is that the experimental oil in the step S3 is formation crude oil, and crude oil required for research can also be used.
The further technical proposal is that the rock sample nuclear magnetic resonance T measured in the step S3 under the state of bound water 1 -T 2 Aqueous phase T with occurrence of separation of spectra 2 Spectral curves and oil phase T 2 A spectral curve; if the aqueous and oily phases T 2 If the spectra cannot be separated, the steps S2 and S3 should be repeated to adjust the mass concentration of the manganese chloride solution until T of the water phase and the oil phase 2 And (5) separating spectral curves.
The further technical scheme is that nuclear magnetic resonance water phase T after displacement differential pressure water flooding at each stage is adopted in the steps S6 and S7 2 Nuclear magnetic resonance T of spectral curve and fully saturated water state 2 And calculating the deviation degree of the spectral curve to obtain the initial wettability of the reservoir rock and the wettability of the reservoir rock under each level of displacement pressure difference. The invention has the following beneficial effects:
the invention utilizes the characteristics of two-dimensional nuclear magnetic resonance technology of accurate, rapid and nondestructive measurement of fluid saturation in rock samples, and preferably selects the nuclear magnetic resonance T 1 -T 2 The concentration of the separation of the aqueous phase and the oil phase signals in the spectra and the use of manganese chloride solutions of this concentration in the subsequent experimental waters. A rock sample is saturated with a manganese chloride solution with a certain concentration, bound water saturation is established through oil-flooding water, water flooding experiments with different displacement pressure differences are carried out after aging, and then nuclear magnetic resonance T of the rock sample after each displacement experiment is finished is obtained 1 -T 2 Nuclear magnetic resonance T of spectrum curve and extracting oil phase and water phase from it 2 Spectra. According to nuclear magnetic resonance T in bound water and saturated water states 2 Calculating the initial wettability of reservoir rock according to the deviation degree of the spectral curve, and then performing water-driven nuclear magnetic resonance T on the spectral curve and the saturated water state after different displacement pressure differences 2 The deviation degree of the curve calculates the change characteristics of the wettability of the reservoir rock along with different mining stages.
The method determines the wettability change conditions of reservoir rock at different mining stages, realizes dynamic detection of wettability, and makes up for the defects of the existing wettability evaluation method. The method also has the advantages of simple process, short experimental time and accurate evaluation result.
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In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the drawings needed to be used in the embodiments will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art that other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a flow chart of an embodiment of the method of the present invention;
Detailed Description
The technical solutions of the present invention will be described clearly and completely with reference to the accompanying drawings, and it is to be understood that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
As shown in fig. 1, a wettability characterization method under reservoir rock simulation production conditions includes the following steps:
s1, selecting a cylindrical rock sample with the length of more than 4cm, washing oil and drying the cylindrical rock sample, measuring the dry weight, the length, the diameter, the porosity and the permeability of the rock sample according to the regulations in the national standard GB/T29172-2012 rock sample analysis method, and respectively recording the dry weight, the length, the diameter, the porosity and the permeability as m 0 、L、D、φ He And K;
s2, putting the rock sample into an intermediate container, vacuumizing and pressurizing to saturate a manganese chloride solution with certain concentration for 48 hours, taking out the rock sample, weighing the rock sample and recording the weight m 1 Calculating the effective porosity of the rock sample according to the formula (1) and the formula (2);
in the formula: v peff Effective pore volume of rock sample, cm 3 ；
m 1 、m 0 -mass of rock sample after saturation and before saturation, g;
ρ -density of fluid for saturation, g/cm 3 ；
φ p -effective porosity, decimal fraction, of the rock sample;
v-total volume of rock sample, cm 3 。
S3, when the obtained effective porosity and the porosity obtained by referring to the industrial standard meet the formula (3), judging that the rock sample is vacuumized and saturated to meet the requirement; if the formula (3) is not satisfied, judging that the rock sample is not vacuumized and saturated, and saturating the rock sample again until the formula (3) is satisfied; measuring and simultaneously obtaining nuclear magnetic resonance T of rock sample saturated manganese chloride solution after complete saturation 1 -T 2 A spectral curve;
s4, filling the saturated rock sample into a rock sample holder, connecting a displacement device, and displacing the rock sample with formation crude oil until water does not flow out, and stopping a displacement experiment; soaking the rock sample after the displacement in the crude oil of the stratum, and aging and recovering for not less than 10 days under the condition of stratum temperature according to related industrial standards; obtaining the nuclear magnetic resonance T of the rock sample in a bound water state after the aging is finished 1 -T 2 A spectral curve;
s5, loading the aged rock sample into a rock sample holder, and performing a manganese chloride solution oil displacement experiment under the displacement differential pressure of 0.6 MPa; stopping the displacement experiment after no oil is produced, and testing the nuclear magnetic resonance T of the obtained rock sample 1 -T 2 A spectral curve;
s6, reloading the rock sample into the rock sample holder, and performing a manganese chloride solution oil displacement experiment under the displacement differential pressure of 1.2 MPa; stopping the displacement experiment after the oil is not discharged any more, and testing the nuclear magnetic resonance T of the obtained rock sample 1 -T 2 A spectral curve;
s7, reloading the rock sample into the rock sample holder, and performing a manganese chloride solution oil displacement experiment under the displacement differential pressure of 2.5 MPa; stopping the displacement experiment after the oil is not discharged any more, and testing the nuclear magnetic resonance T of the obtained rock sample 1 -T 2 A spectral curve;
s8, reloading the rock sample into the rock sample holder, and performing a manganese chloride solution oil displacement experiment under the displacement differential pressure of 4.5 MPa; stopping the displacement experiment after no oil is produced, and testing the nuclear magnetic resonance T of the obtained rock sample 1 -T 2 A spectral curve;
s9, carrying out T treatment on the nuclear magnetic resonance water phase in a fully saturated water state, a bound water state and all levels of displacement pressure differences 2 Spectral curve from corresponding nuclear magnetic resonance T 1 -T 2 Extracting from a spectrum curve;
step S10, calculating the nuclear magnetic resonance T of the rock sample under different states according to the formula (4) and the formula (5) 2 A geometric mean;
in the formula: t is a unit of 2gm -the geometric mean of the transverse relaxation times, ms;
φ NMR nuclear magnetic porosity, decimal fraction, of the rock sample;
a-nuclear magnetic resonance T 2 Spectral signal size, dimensionless;
a. b is a calibration coefficient without dimension;
V-Total volume of rock sample, cm 3 ；
T 2 -nuclear magnetic resonance transverse relaxation time, ms;
step S11, calculating the nuclear magnetic resonance T of the reservoir rock in the bound water state, the different displacement differential pressure water drive and the initial fully saturated water state according to the formula (6) 2 Spectral shift degree to obtain wetting of reservoir rockCharacteristic of sex change.
In the formula: i-nuclear magnetic resonance T 2 The degree of spectral shift is dimensionless.
T 2gm(0) -the geometric mean of the transverse relaxation times of the fully saturated water, ms;
T 2gm(i) -geometric mean of transverse relaxation times of the different states, ms;
although the present invention has been described with reference to the above embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the present invention.
Claims (6)
1. A wettability characterization method under reservoir rock simulated production conditions is characterized by comprising the following steps:
s1, selecting a plunger rock sample, washing oil and drying the plunger rock sample, and measuring the dry weight, length, diameter, porosity and permeability of the rock sample according to related industry standards, wherein the dry weight, length, diameter, porosity and permeability are respectively recorded as m 0 、L、D、φ He And K;
s2, putting the rock sample into an intermediate container, vacuumizing and pressurizing to saturate a manganese chloride solution with certain concentration for 48 hours, taking out the rock sample, weighing the rock sample and recording the weight m 1 Calculating the effective porosity of the rock sample according to the formula (1) and the formula (2); when the effective porosity of the rock sample and the porosity obtained by referring to the industrial standard meet the formula (3), judging that the vacuumizing saturation of the rock sample meets the requirement; if the formula (3) is not met, the rock sample is judged to be vacuumized and saturated and does not meet the requirement, and the rock sample needs to be saturated againUntil formula (3) is satisfied; measuring and simultaneously obtaining nuclear magnetic resonance T of rock sample saturated manganese chloride solution after complete saturation 1 -T 2 A spectral curve;
in the formula: v peff Effective pore volume of rock sample, cm 3 ；
m 1 、m 0 -mass of rock sample after saturation and before saturation, g;
rho-density of fluid for saturation, g/cm 3 ；
φ p -effective porosity, decimal fraction, of the rock sample;
v-total volume of rock sample, cm 3 ；
S3, filling the saturated rock sample into a rock sample holder, connecting a displacement device, and displacing the rock sample with stratum crude oil until water does not flow out, and stopping a displacement experiment; soaking the rock sample after the displacement in the crude oil in the stratum, and aging and recovering for not less than 10 days under the condition of stratum temperature; measuring nuclear magnetic resonance T of rock sample in bound water state after aging is completed 1 -T 2 A spectral curve;
s4, loading the aged rock sample into a rock sample holder, and developing a pre-configured manganese chloride aqueous solution oil displacement experiment with a certain concentration under each stage of displacement pressure difference, wherein the setting of each stage of displacement pressure difference is determined according to the production pressure difference of a reservoir where the rock sample is located, and the displacement pressure difference at least comprises 4 displacement pressure differences, and is increased step by step in the water displacement experiment; the displacement differential pressure of each stage is displaced to the point that the displacement differential pressure is not requiredStopping displacement after oil is produced, and measuring nuclear magnetic resonance T when the rock sample corresponds to the displacement 1 -T 2 Obtaining the nuclear magnetic resonance T of the rock sample under the displacement differential pressure of each level finally by a spectrum curve 1 -T 2 A spectral curve;
s5, carrying out T treatment on the nuclear magnetic resonance water phase in a completely saturated water state, a bound water state and each level of displaced pressure difference 2 Spectral curve from corresponding nuclear magnetic resonance T 1 -T 2 Extracting from a spectral curve;
s6, calculating T of the rock sample in the completely saturated manganese chloride solution and in the bound water state according to the formula (4) and the formula (5) 2 Geometric mean and calculating the nuclear magnetic resonance T of the reservoir rock according to equation (6) 2 Spectrum migration degree, and obtaining the initial wettability of the reservoir rock according to the wetting evaluation standard in the table 1;
in the formula: t is 2gm -geometric mean of transverse relaxation times, ms;
φ NMR nuclear magnetic porosity, decimal fraction, of the rock sample;
a-nuclear magnetic resonance T 2 Spectral signal size, dimensionless;
a. b-calibration coefficient, dimensionless;
V-Total volume of rock sample, cm 3 ；
T 2 -nuclear magnetic resonance transverse relaxation time, ms;
T 2gm(0) -geometric mean of transverse relaxation times of fully saturated water, ms;
T 2gm(i) -the geometric mean of the transverse relaxation times of the different states, ms;
i-nuclear magnetic resonance T 2 The shift degree of the spectrum is dimensionless;
s7, calculating T of the rock sample after water flooding with different displacement differential pressures according to the formulas (4) and (5) 2 The geometric mean value is calculated, and the nuclear magnetic resonance T of the reservoir rock at each stage of water flooding is calculated according to the formula (6) 2 And (3) spectrum shifting degree, and acquiring the wettability change condition of the reservoir rock according to the evaluation standard of the table 1.
TABLE 1 wetting evaluation criteria
2. A method for characterizing wettability of a reservoir rock under simulated production conditions according to claim 1, wherein the plunger rock sample in step S1 has a length of 4-5cm and a diameter of 2.5cm.
3. The method for characterizing the wettability of the reservoir rock under the simulated production condition according to claim 1, wherein the mass concentration of the manganese chloride solution with a certain concentration in the step S2 is 4-10g/L.
4. The method for characterizing wettability of reservoir rock under simulated production conditions according to claim 1, wherein the experimental oil in step S3 is a formation crude oil, which can also be used for research.
5. A method for characterizing wettability of a reservoir rock under simulated production conditions according to claim 1, wherein said rock sample in a water-bound state in NMR T measured in step S3 1 -T 2 Aqueous phase T with occurrence of separation of spectra 2 Spectral curves and oil phase T 2 A spectral curve; if the aqueous and oily phases T 2 If the spectral curves cannot be separated, it should be adjustedThe mass concentration of the manganese chloride solution is repeated until the T of the water phase and the oil phase 2 And (5) separating spectral curves.
6. The method for characterizing the wettability of reservoir rock under the simulated production condition according to claim 1, wherein the nuclear magnetic resonance water phase T after water flooding at each level of displacement differential pressure is adopted in the steps S6 and S7 2 Nuclear magnetic resonance T of spectral curve and fully saturated water state 2 And calculating the deviation degree of the spectral curve to obtain the initial wettability of the reservoir rock and the wettability of the reservoir rock under each level of displacement pressure difference.
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| CN116223553B (en) * | 2023-03-14 | 2023-11-14 | 西南石油大学 | Shale wettability fine characterization method based on nuclear magnetic resonance |
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