CN107340219B - Oil reservoir dynamic capillary effect evaluation experiment data processing method - Google Patents

Oil reservoir dynamic capillary effect evaluation experiment data processing method Download PDF

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CN107340219B
CN107340219B CN201710549525.4A CN201710549525A CN107340219B CN 107340219 B CN107340219 B CN 107340219B CN 201710549525 A CN201710549525 A CN 201710549525A CN 107340219 B CN107340219 B CN 107340219B
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李海涛
李颖
崔小江
卢昱
李斌斌
蒋贝贝
阳明君
王科
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Southwest Petroleum University
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Abstract

The invention discloses a dynamic capillary effect evaluation experiment data processing method, which sequentially comprises the following steps: (1) finishing baseThe parameters; (2) average water saturation of core
Figure DDA0001344045060000011
And average oil saturation
Figure DDA0001344045060000012
Determination of (1); (3) determination of dynamic capillary force: correcting the in-situ dynamic capillary force measured by each test point, determining the geometric centers of the rock core, the oil phase and the water phase, and calculating the average oil phase pressure of the essential phase<po>And pressure of the aqueous phase<pw>Determining dynamic capillary force; (4) determining the oil phase and water phase dynamic relative permeability: calculating effective water saturation
Figure DDA0001344045060000013
Taking the water saturation on the capillary force curve as SpCentral water saturation point of (2), saturation SpCalculating the logarithmic coordinate slope (F) of the point with the corresponding capillary pressure of P, fitting a Genuchten model to obtain a parameter m, and respectively calculating the dynamic relative permeability (K) of the water phaserw) And oil phase dynamic relative permeability (K)ro)。

Description

Oil reservoir dynamic capillary effect evaluation experiment data processing method
Technical Field
The invention belongs to the technical field of indoor experiments of oil and gas field development, and particularly relates to a dynamic capillary effect evaluation experiment data processing method.
Background
Dynamic capillary effect, i.e. capillary force and relative permeability during oil-water two-phase percolation, is a function of not only saturation, but also saturation change rate. Typically, the capillary forces used in the study are measured under static or quasi-static conditions, i.e. the saturation distribution no longer changes over time. However, since the 60's of the 19 th century, it was discovered that the capillary phenomenon produced by heterogeneous percolation in porous media was dynamic. The difference between static and dynamic capillary forces has been demonstrated by many studies, and is even greater, particularly in hypotonic or tight reservoirs. The relative permeability is also affected by the difference between the dynamic and static capillary forces. The dynamic phase permeation curve under the action of the dynamic capillary effect is unstable and has a larger difference with the static phase permeation curve measured during stabilization. Therefore, accurate evaluation experiments and data processing methods are needed to obtain accurate dynamic capillary force and dynamic phase permeability curves, evaluate the dynamic capillary effect and provide guidance for reservoir development.
At present, the data processing method of the oil reservoir rock dynamic capillary effect evaluation experiment has large deviation, so that the reliability of the dynamic capillary force, saturation and relative permeability data obtained by calculation is not strong. The measured saturation data, relative permeability and pressure of each phase fluid all need to be reasonably averaged. Especially in the case of a large fluid viscosity or a fast pressure change, the response time of the pressure sensor causes a delay in the test data, and the measured fluid pressure needs to be corrected.
Disclosure of Invention
The invention aims to provide a dynamic capillary force evaluation experiment data processing method, which overcomes the defects of the existing experiment data processing method, can accurately correct the fluid pressure of each phase, reasonably and averagely calculate the saturation and the fluid pressure, accurately calculate the dynamic relative permeability and provide accurate data support for evaluating the dynamic capillary effect of an oil reservoir.
The purpose of the invention is realized by the following technical scheme:
a method for processing experimental data of oil reservoir dynamic capillary effect evaluation comprises the steps of determining average fluid saturation, correcting fluid pressure of each phase, determining dynamic capillary force and determining dynamic relative permeability, and sequentially comprises the following steps:
1. arranging basic parameters including the core length; position of each test section
Figure GDA0002385939010000021
Certain in situ water saturation
Figure GDA0002385939010000022
And a certain in situ oil saturation
Figure GDA0002385939010000023
Water phase pressure of each pressure test point
Figure GDA0002385939010000024
And oil phase pressure
Figure GDA0002385939010000025
Original water saturation SiAnd irreducible water saturation Srw；
2. Average water saturation of core
Figure GDA0002385939010000026
And average oil saturation
Figure GDA0002385939010000027
Determination of (1):
Figure GDA0002385939010000028
Figure GDA0002385939010000029
j represents each saturation test point, N represents the total number of test points,
Figure GDA00023859390100000210
for a certain in-situ water saturation,
Figure GDA00023859390100000211
a certain in situ oil saturation;
Figure GDA00023859390100000212
in order to contain the average water saturation,
Figure GDA00023859390100000213
is the average oil saturation;
3. determination of dynamic capillary force:
1) correcting the measured in-situ dynamic capillary force of each test point:
Figure GDA00023859390100000214
Figure GDA00023859390100000215
Figure GDA00023859390100000216
and
Figure GDA00023859390100000217
respectively the water phase pressure and the oil phase pressure before correction;
Figure GDA00023859390100000218
corrected pressure for aqueous phase;
Figure GDA00023859390100000219
the corrected pressure of the oil phase; k is a response time related characterization parameter which is a constant, and the size of the k is determined by the porous medium liquid system and the semi-permeable material of the sensor;
2) determining the geometric centers of the rock core, the oil phase and the water phase:
Zaverage＝0.5H
Figure GDA0002385939010000031
Figure GDA0002385939010000032
Zaverageis the geometric center of the rock core,<Zo>is the geometric center of the oil phase,<Zw>is the geometric center of the water phase;
3) calculating the average oil phase pressure<Po>And pressure of the aqueous phase<Pw>：
Figure GDA0002385939010000033
Figure GDA0002385939010000034
j represents each saturation test point, and N represents the total number of the test points;
Figure GDA0002385939010000035
for a certain in-situ water saturation,
Figure GDA0002385939010000036
a certain in situ oil saturation;
Figure GDA0002385939010000037
and
Figure GDA0002385939010000038
respectively the water phase pressure and the oil phase pressure before correction;
4) determination of dynamic capillary force:
Figure GDA0002385939010000039
Figure GDA00023859390100000310
4. determining the oil phase and water phase dynamic relative permeability:
1) calculating effective water saturation
Figure GDA00023859390100000311
Figure GDA00023859390100000312
Wherein S isrwTo restrict water saturation, SwA certain water saturation;
2) taking the water saturation on the capillary force curve as SpCentral water saturation point of (2), saturation SpThe corresponding capillary pressure is P, and the logarithmic coordinate slope (F) of the point is calculated:
Figure GDA0002385939010000041
Figure GDA0002385939010000042
wherein S isiThe water saturation at full saturation.
3) Fitting a Genuchten model (Van Genuchten M T. allocated-form estimation for predicting the hydraulic conductivity of unsorted waters [ J ]. Soil science location of America J ournal,1980,44(5): 892) 898.) to obtain a parameter M associated with the Van Genuchten pore size distribution coefficient:
Figure GDA0002385939010000043
4) the dynamic relative permeability (K) of the aqueous phase was calculated separatelyrw) And oil phase dynamic relative permeability (K)ro)(Goel G,Abidoye L K,Chahar B R,et al.Scale dependency of dynamic relativepermeability–satuartion curves in relation with fluid viscosity and dynamiccapillary pressure effect.Environmental Fluid Mechanics[J],2016,16(5):945-963.)：
Figure GDA0002385939010000044
Figure GDA0002385939010000045
The invention has the following advantages:
the in-situ water saturation of the rock core and the in-situ oil-phase water-phase pressure measured in the water flooding process are directly utilized, the dynamic capillary force and the dynamic relative permeability are conveniently and efficiently calculated, accurate data support is provided for evaluating the dynamic capillary effect, and the design of an oil field development scheme is guided.
Drawings
FIG. 1 is a flow chart of the experimental data processing method for evaluating the dynamic capillary effect of an oil reservoir.
FIG. 2 is a data acquisition point corresponding to the oil reservoir dynamic capillary effect evaluation experiment data processing method.
FIG. 3 is a graph of dynamic capillary force calculated according to the method of the present invention for an embodiment.
FIG. 4 is a graph of dynamic phase permeation for an embodiment calculated according to the method of the present invention.
In fig. 2, 1-a first aqueous phase pressure test point, 2-a second aqueous phase pressure test point, 3-a first oil phase pressure test point, 4-a second oil phase pressure test point, 5-a first water saturation test point, 6-a second water saturation test point.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the present invention will be further described with reference to the drawings and application examples of experimental data processing methods in the embodiments of the present invention. It is to be understood that the embodiments described are only a few, and not all, embodiments of the invention. For a person skilled in the art, other figures can be derived from these figures without inventive effort.
The method comprises the following specific steps:
as shown in fig. 1, which is a specific flow chart of the data processing method, a dynamic capillary effect evaluation experiment is performed on a certain oilfield core, and the steps are as follows:
1. as shown in fig. 2, for the data point collection of this example, during the experiment, the data at a certain time collected from the first water phase pressure test point 1, the second water phase pressure test point 2, the first oil phase pressure test point 3, the second oil phase pressure test point 4, the first water saturation test point 5, and the second water saturation test point 6 are as follows:
Figure GDA0002385939010000051
Figure GDA0002385939010000061
2. determining the average water saturation and the average oil saturation of the rock core:
Figure GDA0002385939010000062
Figure GDA0002385939010000063
3. determining dynamic capillary force:
1) correcting the in-situ dynamic capillary force for each test point:
Figure GDA0002385939010000064
Figure GDA0002385939010000065
Figure GDA0002385939010000066
Figure GDA0002385939010000067
2) determining the geometric centers of the rock core, the oil phase and the water phase:
Zaverage＝0.5H＝5
Figure GDA0002385939010000068
Figure GDA0002385939010000071
3) calculating the average oil phase pressure<Po>And pressure of the aqueous phase<Pw>：
Figure GDA0002385939010000072
Figure GDA0002385939010000073
4) Determination of dynamic capillary force:
Figure GDA0002385939010000074
Figure GDA0002385939010000075
Figure GDA0002385939010000076
3. determining the oil phase and water phase dynamic relative permeability:
1) calculating effective water saturation
Figure GDA0002385939010000077
Figure GDA0002385939010000078
Wherein S isrwTo restrict water saturation, SwThe water saturation.
2) Taking the saturation on the capillary force curve as SpPoint of (2), saturation SpThe corresponding capillary pressure is P, and the logarithmic coordinate slope (F) of the point is calculated:
Figure GDA0002385939010000079
Figure GDA00023859390100000710
3) fitting a Genuchten model to obtain a parameter m:
Figure GDA0002385939010000081
4) calculating the dynamic relative permeability of the water phase and the oil phase:
Figure GDA0002385939010000082
Figure GDA0002385939010000083
as shown in fig. 3, is a dynamic capillary force curve at different water saturations calculated according to this procedure. As shown in fig. 4, the dynamic relative permeability curve calculated according to this procedure is shown.

Claims (1)

1. A method for processing experimental data of oil reservoir dynamic capillary effect evaluation is characterized by sequentially comprising the following steps:
1) arranging basic parameters including the core length; position Z of each test sectionj：
Figure FDA0002564318700000011
Certain in situ water saturation
Figure FDA0002564318700000012
And a certain in situ oil saturation
Figure FDA0002564318700000013
Aqueous phase pressure before correction
Figure FDA0002564318700000014
And the oil phase pressure before correction
Figure FDA0002564318700000015
Original water saturation SiAnd irreducible water saturation Srw；
2) Average water saturation of core
Figure FDA0002564318700000016
And average oil saturation
Figure FDA0002564318700000017
Determination of (1):
Figure FDA0002564318700000018
Figure FDA0002564318700000019
j represents each saturation test point, N represents the total number of test points,
Figure FDA00025643187000000110
for a certain in-situ water saturation,
Figure FDA00025643187000000111
a certain in situ oil saturation;
Figure FDA00025643187000000112
in order to average the degree of water saturation,
Figure FDA00025643187000000113
is the average oil saturation;
3) determination of dynamic capillary force:
correcting the in-situ dynamic capillary force measured by each test point:
Figure FDA00025643187000000114
Figure FDA00025643187000000115
Figure FDA00025643187000000116
and
Figure FDA00025643187000000117
respectively the water phase pressure and the oil phase pressure before correction;
Figure FDA00025643187000000118
corrected pressure for aqueous phase;
Figure FDA00025643187000000119
the corrected pressure of the oil phase; k is a response time related characterization parameter which is a constant, and the size of the k is determined by the porous medium liquid system and the semi-permeable material of the sensor;
determining the geometric centers of the rock core, the oil phase and the water phase:
Zaverage＝0.5H
Figure FDA0002564318700000021
Figure FDA0002564318700000022
Zaverageis the geometric center of the rock core,<Zo>is the geometric center of the oil phase,<Zw>is the geometric center of the water phase;
③ finding the average oil phase pressure<Po>And pressure of the aqueous phase<Pw>：
Figure FDA0002564318700000023
Figure FDA0002564318700000024
j represents each saturation test point, and N represents the total number of the test points;
Figure FDA0002564318700000025
for a certain in-situ water saturation,
Figure FDA0002564318700000026
a certain in situ oil saturation;
determination of dynamic capillary force:
Figure FDA0002564318700000027
Figure FDA0002564318700000028
4) determining the oil phase and water phase dynamic relative permeability:
① calculating effective water saturation
Figure FDA0002564318700000029
Figure FDA00025643187000000210
Wherein S isrwTo restrict water saturation, SwA certain water saturation;
② taking the water saturation on the capillary force curve as SpCentral water saturation point of (2), saturation SpAnd (3) calculating the slope F of the logarithmic coordinate of the point, wherein the corresponding capillary pressure is P:
Figure FDA0002564318700000031
Figure FDA0002564318700000032
wherein S isiWater saturation at full water saturation;
thirdly, fitting a Genuchten model to obtain a parameter m related to a Van Genuchten pore size distribution coefficient:
Figure FDA0002564318700000033
④ calculation of the dynamic relative permeability K of the aqueous phaserwAnd oil phase dynamic relative permeability Kro：
Figure FDA0002564318700000034
Figure FDA0002564318700000035
And according to the dynamic capillary force curves at different water saturation at different moments obtained by the calculation in the step.
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