CN107366538B - Phase permeability curve processing method for reflecting difference of permeability capacities of different reservoirs - Google Patents

Phase permeability curve processing method for reflecting difference of permeability capacities of different reservoirs Download PDF

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CN107366538B
CN107366538B CN201611164620.4A CN201611164620A CN107366538B CN 107366538 B CN107366538 B CN 107366538B CN 201611164620 A CN201611164620 A CN 201611164620A CN 107366538 B CN107366538 B CN 107366538B
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permeability
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relative permeability
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CN107366538A (en
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邴绍献
刘新秀
张海燕
孙成龙
肖武
张超
徐永春
李东玻
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China Petroleum and Chemical Corp
Exploration and Development Research Institute of Sinopec Shengli Oilfield Co
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Exploration and Development Research Institute of Sinopec Shengli Oilfield Co
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Abstract

The invention provides a method for processing a phase permeability curve reflecting the difference of the permeability of different reservoirs, which comprises the following steps: step 1, collecting the data of a phase-permeation curve, and selecting a sample rock sample; step 2, performing conventional normalization processing on the same small-layer phase permeation data; step 3, calculating the seepage capability difference of each small layer, namely calculating the flow coefficient of each small layer respectively
Figure DDA0002443416650000011
And calculates each small layer
Figure DDA0002443416650000012
The weight occupied; and 4, calculating a phase permeation curve of the oilfield block or unit. The method for processing the facies infiltration curve reflecting the difference of the seepage capabilities of different reservoirs considers the influence of the difference heterogeneity of the reservoir layers on the oil reservoir development, and can accurately reflect the difference of the contributions of the different reservoirs to the oil reservoir development by applying the method, so that the processed facies infiltration curve is more in line with objective reality.

Description

Phase permeability curve processing method for reflecting difference of permeability capacities of different reservoirs
Technical Field
The invention relates to the field of oil and gas field development, in particular to a method for processing a phase permeability curve reflecting the difference of the permeability capacities of different reservoirs.
Background
The phase-permeation curve is the comprehensive reflection of the oil-water two-phase seepage characteristics and is the basic objective law followed by the oil-water two-phase seepage process. For a particular oil field, block or unit, a laboratory is required to perform a relative permeability curve experiment on a plurality of core samples (hereinafter referred to as rock samples). Because the reservoir physical properties, fluid physical properties, wettability and the like of each rock sample are different, and the relative permeability curves have certain difference, in order to obtain a representative relative permeability curve, the traditional method is to select a plurality of rock sample relative permeability curves with the reservoir physical properties, the fluid physical properties, the wettability and the like similar to a research oil field (block or unit) and adopt a direct averaging method of a plurality of curves to obtain the average relative permeability curve of the oil field (block or unit).
The method is that the phase permeability curve of each rock sample is firstly standardized, and then the arithmetic mean is carried out to obtain the average relative permeability curve. Firstly, after a sample rock sample is screened, rock samples with very good and very poor physical properties of reservoirs and fluids are artificially removed, and the real situation of an oil field (block or unit) cannot be comprehensively and objectively reflected; secondly, the method is to carry out simple arithmetic mean on each filtered facies cementation curve, namely, each facies cementation curve has the same influence on the finally obtained facies cementation curve, and the influence of reservoir heterogeneity on oil reservoir development is difficult to accurately reflect. For the oil deposit with serious heterogeneity, the area with large difference of physical properties and the flow of the fluid in the oil deposit have large difference, and a phase permeation curve processing method capable of comprehensively and accurately reflecting the difference of the permeation capacities of different reservoirs needs to be established. Therefore, a new method for processing the phase permeability curve reflecting the difference of the permeability capacities of different reservoirs is invented, and the technical problems are solved.
Disclosure of Invention
The invention aims to provide a method for processing a phase permeability curve, which can reflect the difference of different reservoir permeability and contributes different contributions to oil reservoir development and reflects the difference of different reservoir permeability.
The object of the invention can be achieved by the following technical measures: the method for processing the phase permeability curve reflecting the difference of the permeability capacities of different reservoirs comprises the following steps: step 1, collecting the data of a phase-permeation curve, and selecting a sample rock sample; step 2, performing conventional normalization processing on the same small-layer phase permeation data; step 3, calculating the seepage capability difference of each small layer, namely calculating the flow coefficient of each small layer respectively
Figure GDA0002443416640000021
And calculates each small layer
Figure GDA0002443416640000022
The weight occupied; and 4, calculating a phase permeation curve of the oilfield block or unit.
The object of the invention can also be achieved by the following technical measures:
in the step 1, oil-water two-phase permeability experiment rock samples of each small layer of the block to be evaluated are collected, and representative phase permeability curve experiment data of each small layer are respectively selected for later use.
In step 2, normalizing each small layer sample rock sample selected in step 1 by respectively adopting a direct multiple curve averaging method, and calculating to obtain the permeability curve of each small layer.
In step 4, after the phase permeation curves of the small layers in step 2 are subjected to standardization processing, a plurality of curves are weighted and averaged according to the weight occupied in step 3, and the phase permeation curves of the oilfield blocks or units are obtained.
Step 4 comprises the following steps:
(1) respectively standardizing the experimental data of each small layer according to the following formulas 1-3, and drawing a standardized oil-water relative permeability curve:
Figure GDA0002443416640000031
Figure GDA0002443416640000032
Figure GDA0002443416640000033
in the formula
Figure GDA0002443416640000034
——SwNormalized water saturation,%;
Sw-water saturation,%;
Swi-irreducible water saturation,%;
Swmax-maximum water saturation,%;
Figure GDA0002443416640000035
-normalized relative permeability of oil, decimal;
Kro(Sw) -relative permeability of oil, decimal;
Kromax-relative permeability (maximum), decimal, of the oil phase under water-binding conditions;
Figure GDA0002443416640000036
-normalized relative permeability of water, decimal;
Krw(Sw) The relative permeability of water, decimal;
Krwmax-relative permeability (maximum), decimal, of the aqueous phase under residual oil conditions;
k of the relative permeability curve when it is made in the laboratoryromax(Swi) 1.0, there is no need to re-normalize Kro(Sw) Directly order Kro *(Sw *)＝Kro(Sw)；
(2) On the normalized curve, the abscissa Sw *Dividing the layer into m equal parts from 0 to 1, and calculating each small layer S according to formula 4w *K at a branch pointro *And Krw *Thereby obtaining an average Kro *(Sw *) And Krw *(Sw *) And an average normalized relative permeability curve is made,
Figure GDA0002443416640000041
wherein k is 1, 2, …, m;
i＝1，2，…，n；
Figure GDA0002443416640000042
-average, decimal, of the relative permeabilities of the oils after normalization;
Figure GDA0002443416640000043
-average, decimal fraction, of the normalized relative permeability of water;
kiair permeability of the ith sublayer, 10-3μm2；
hi-the effective thickness of the ith sublayer, m;
μi-the viscosity of the surface crude oil of the ith sub-layer, mPa · s;
n-total number of small layers participating in the calculation of the average normalized relative permeability curve;
m-abscissa Sw *A total number of aliquots divided from 0 to 1;
(3) s of each small layerwi、Swmax、Kromax、KrwmaxThese characteristic values are weighted and averaged, respectively, and the average value is taken as the characteristic value of the average relative permeability curve, as shown in the following formula 5:
Figure GDA0002443416640000051
in the formula
Figure GDA0002443416640000052
-irreducible water saturation,%;
Figure GDA0002443416640000053
-maximum water saturation,%;
Figure GDA0002443416640000054
relative permeability (maximum), decimal, of the aqueous phase under water-binding conditions;
Figure GDA0002443416640000055
-relative permeability (maximum), decimal, of the oil phase under water-binding conditions;
(4) s of each point on the average normalized relative permeability curvew *、Kro *、Krw *Conversion to Sw、Kro、KrwThe conversion formula is as follows:
Figure GDA0002443416640000056
when in use
Figure GDA0002443416640000057
There is no need to re-normalize Kro(Sw) Directly order Kro(Sw)＝Kro *(Sw *)；
(5) The arithmetic mean relative permeability curve for an oilfield block or cell is plotted against the values found in equation 6.
The invention discloses a method for processing a phase permeability curve reflecting the difference of the permeability of different reservoirs, and relates to the field of evaluation of development effect and prediction of development indexes in the development process of oil and gas fields, namely reflecting the permeability of different reservoirsThere is a method for processing oil-water two-phase relative permeability curve (hereinafter referred to as "permeability curve") with different contribution to oil reservoir development. The invention introduces a parameter of the difficulty of flowing the fluid in the stratum, namely the flow coefficient
Figure GDA0002443416640000061
Provides a method for processing a percolation curve by fully considering the difference of the percolation between layers, namely according to the flow coefficient of a reservoir where a rock sample is positioned
Figure GDA0002443416640000062
And (3) carrying out weighted average processing on each normalized percolation curve point and characteristic value. The method comprehensively considers the differences of reservoir physical properties and fluid physical properties of each phase permeation curve representing a reservoir on the basis of the original direct averaging method of a plurality of curves. The seepage capacities of the reservoirs are different, the contribution to the oil reservoir development is different, and the result is more objective and practical by adopting a flow coefficient weighted average processing method, so that the method can be more suitable for the requirements of oil reservoir development effect evaluation and trend prediction.
Drawings
FIG. 1 is a flow chart of an embodiment of a facies permeability curve processing method of the present invention reflecting differences in the permeability of different reservoirs;
figure 2 is a graph of the interpenetration of the small layers of the Chengqing 4 patch in an embodiment of the present invention;
figure 3 is a graph of the penetration of the field of Chengqing 4 according to one embodiment of the present invention.
Detailed Description
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
As shown in fig. 1, fig. 1 is a flow chart of a method for processing a facies cementation curve reflecting the difference of the seepage capability of different reservoirs according to the present invention.
Step 101, collecting the data of the phase-permeability curve, and selecting a sample rock sample. And collecting oil-water two-phase permeability experiment rock samples of each small layer of the block to be evaluated, and respectively selecting representative phase permeability curve experiment data of each small layer for later use.
And 103, performing conventional normalization processing on the same small-layer permeability data. And (4) respectively carrying out normalization treatment on the small-layer sample rock samples selected in the step (101) by adopting a direct averaging method of a plurality of curves, and calculating to obtain the permeability curve of each small layer.
And 105, calculating the seepage capability difference of each small layer. And respectively calculating the flow coefficient of each small layer, and calculating the weight occupied by each small layer.
Step 107, calculating the oil field (block or unit) permeability curve. After the phase permeation curves of the small layers in step 103 are normalized, a plurality of curves are weighted and averaged according to the weight occupied in step 105, and an oil field (block or unit) phase permeation curve is obtained.
Taking the Chengdong field Chengqi 4 block as an example, the implementation process of the interpenetration curve processing method reflecting the difference of the seepage capability of different reservoirs is explained.
In step 1, collecting Chengdong oil field interpenetration curve, comparing Chengdong 4 block oil-water well layered physical property parameter table, and selecting Chengdong 4 block five small layer interpenetration curve 10. Wherein 251Layer 3 interpenetration curves, 252Layer 1 interpenetration curve, 321Layer 1 interpenetration curve, 331Layer 3 Permeability curves, 34Layer 2 has two permeation curves.
In step 2, a plurality of phase-permeation curves of the same small layer are normalized into one phase-permeation curve by a direct averaging method of a plurality of curves, namely 251Normalization of the layer 3 percolation curves yields a line 251Layer interpenetration Curve, 331Normalization of the layer 3 percolation curves yields a line 331Layer interpenetration Curve, 34Normalization of the layer 2 percolation curves yields a 34Layer percolation curve, as shown in figure 2.
In step 3, collecting and tidying the air permeability, effective thickness and ground crude oil viscosity of each small layer of the Chengqing 4 block, and calculating the air permeability, effective thickness and ground crude oil viscosity of each small layer
Figure GDA0002443416640000081
Value, and per sublayer
Figure GDA0002443416640000082
Occupies 5 small layers
Figure GDA0002443416640000083
The ratio of the sum is expressed in decimal, and the results are shown in Table 1.
TABLE 1 permeability k, thickness h of each small layer of Chengqing 4 region and per small layer
Figure GDA0002443416640000084
Specific gravity table
Figure GDA0002443416640000085
In step 4, the 5-layer facies percolation curve is normalized using a multi-curve direct averaging method. The method specifically comprises the following steps:
(1) respectively carrying out standardization treatment on the phase permeation curve data of each small layer according to the following formula (formula 1-3), and drawing a standardized oil-water relative permeability curve:
Figure GDA0002443416640000086
Figure GDA0002443416640000087
Figure GDA0002443416640000088
in the formula
Figure GDA0002443416640000091
——SwNormalized water saturation,%;
Sw-water saturation,%;
Swi-irreducible water saturation,%;
Swmax-maximum water saturation,%;
Figure GDA0002443416640000092
-normalized relative permeability of oil, decimal;
Kro(Sw) -relative permeability of oil, decimal;
Kromax-relative permeability (maximum), decimal, of the oil phase under water-binding conditions;
Figure GDA0002443416640000093
-normalized relative permeability of water, decimal;
Krw(Sw) The relative permeability of water, decimal;
Krwmax-relative permeability of the aqueous phase (maximum), fractional number, under residual oil conditions.
K if the relative permeability curve is made in the laboratoryromax(Swi) 1.0, there is no need to re-normalize Kro(Sw) Directly order Kro *(Sw *)＝Kro(Sw)。
(2) On the normalized curve, the abscissa Sw *Dividing the layer into m equal parts from 0 to 1, and calculating each small layer S according to formula 4w *K at a branch pointro *And Krw *Thereby obtaining an average Kro *(Sw *) And Krw *(Sw *). And an average normalized relative permeability curve is made.
Figure GDA0002443416640000094
Wherein k is 1, 2, …, m;
i＝1，2，…，n；
Figure GDA0002443416640000101
normalized relative permeability of oilMean, decimal;
Figure GDA0002443416640000102
-average, decimal fraction, of the normalized relative permeability of water;
kiair permeability of the ith sublayer, 10-3μm2；
hi-the effective thickness of the ith sublayer, m;
μi-the viscosity of the surface crude oil of the ith sub-layer, mPa · s;
n-total number of small layers participating in the calculation of the average normalized relative permeability curve;
m-abscissa Sw *The total number of aliquots divided from 0 to 1.
(3) S of each small layerwi、Swmax、Kromax、KrwmaxAnd respectively carrying out weighted average on the characteristic values, and taking the average value as the characteristic value of the average relative permeability curve. As shown in equation 5 below:
Figure GDA0002443416640000103
in the formula
Figure GDA0002443416640000104
-irreducible water saturation,%;
Figure GDA0002443416640000105
-maximum water saturation,%;
Figure GDA0002443416640000106
relative permeability (maximum), decimal, of the aqueous phase under water-binding conditions;
Figure GDA0002443416640000107
-relative of oil phases under water-binding conditionsPermeability (max), fractional.
(4) S of each point on the average normalized relative permeability curvew *、Kro *、Krw *Conversion to Sw、Kro、Krw. The conversion formula is as follows:
Figure GDA0002443416640000111
if it is not
Figure GDA0002443416640000112
There is no need to re-normalize Kro(Sw) Directly order Kro(Sw)＝Kro *(Sw *)。
(5) The arithmetic mean relative permeability curve for an oil field (block or cell) is plotted against the values found in equation 6.
The method for processing the facies infiltration curve reflecting the difference of the seepage capability of different reservoirs considers the influence of the difference heterogeneity of reservoir layers on the development of the oil reservoir, and can accurately reflect the difference of the contributions of the different reservoirs to the development of the oil reservoir, so that the processed facies infiltration curve is more in line with objective practice.

Claims (4)

1. The method for processing the phase permeability curve reflecting the difference of the permeability capacities of different reservoirs is characterized by comprising the following steps of:
step 1, collecting the data of a phase-permeation curve, and selecting a sample rock sample;
step 2, performing conventional normalization processing on the same small-layer phase permeation data;
step 3, calculating the seepage capability difference of each small layer, namely calculating the flow coefficient of each small layer respectively
Figure FDA0002443416630000011
And calculates each small layer
Figure FDA0002443416630000012
The weight occupied;
step 4, calculating a phase permeability curve of the oil field block or unit;
step 4 comprises the following steps:
(1) respectively standardizing the experimental data of each small layer according to the following formulas 1-3, and drawing a standardized oil-water relative permeability curve:
Figure FDA0002443416630000013
Figure FDA0002443416630000014
Figure FDA0002443416630000015
in the formula Sw *——SwNormalized water saturation,%;
Sw-water saturation,%;
Swi-irreducible water saturation,%;
Swmax-maximum water saturation,%;
Kro *(Sw *) -normalized relative permeability of oil, decimal;
Kro(Sw) -relative permeability of oil, decimal;
Kromax-relative permeability (maximum), decimal, of the oil phase under water-binding conditions;
Krw *(Sw *) -normalized relative permeability of water, decimal;
Krw(Sw) The relative permeability of water, decimal;
Krwmax-relative permeability (maximum), decimal, of the aqueous phase under residual oil conditions;
all right fruitsK of the relative permeability curve made by the laboratoryromax(Swi) 1.0, there is no need to re-normalize Kro(Sw) Directly order Kro *(Sw *)＝Kro(Sw)；
(2) On the normalized curve, the abscissa Sw *Dividing the layer into m equal parts from 0 to 1, and calculating each small layer S according to formula 4w *K at a branch pointro *And Krw *Thereby obtaining an average Kro *(Sw *) And Krw *(Sw *) And an average normalized relative permeability curve is made,
Figure FDA0002443416630000021
wherein k is 1, 2, …, m;
i＝1，2，…，n；
Figure FDA0002443416630000022
-average, decimal, of the relative permeabilities of the oils after normalization;
Figure FDA0002443416630000023
-average, decimal fraction, of the normalized relative permeability of water;
kiair permeability of the ith sublayer, 10-3μm2；
hi-the effective thickness of the ith sublayer, m;
μi-the viscosity of the surface crude oil of the ith sub-layer, mPa · s;
n-total number of small layers participating in the calculation of the average normalized relative permeability curve;
m-abscissa Sw *A total number of aliquots divided from 0 to 1;
(3) s of each small layerwi、Swmax、Kromax、KrwmaxThese characteristic values are weighted and averaged, respectively, and the average value is taken as the characteristic value of the average relative permeability curve, as shown in the following formula 5:
Figure FDA0002443416630000031
in the formula
Figure FDA0002443416630000032
-irreducible water saturation,%;
Figure FDA0002443416630000033
-maximum water saturation,%;
Figure FDA0002443416630000034
relative permeability (maximum), decimal, of the aqueous phase under water-binding conditions;
Figure FDA0002443416630000035
-relative permeability (maximum), decimal, of the oil phase under water-binding conditions;
(4) s of each point on the average normalized relative permeability curvew *、Kro *、Krw *Conversion to Sw、Kro、KrwThe conversion formula is as follows:
Figure FDA0002443416630000036
when in use
Figure FDA0002443416630000041
There is no need to re-normalize Kro(Sw) Directly order Kro(Sw)＝Kro *(Sw *)；
(5) The arithmetic mean relative permeability curve for an oilfield block or cell is plotted against the values found in equation 6.
2. The method for processing the phase permeability curve reflecting the difference of the permeability capacities of different reservoirs according to claim 1, wherein in the step 1, oil-water two-phase permeability experiment rock samples of each small layer of the area to be evaluated are collected, and representative phase permeability curve experiment data of each small layer are respectively selected for later use.
3. The method for processing the permeability curve of different reservoirs according to claim 1, wherein in step 2, normalization processing is performed on each small sample rock sample selected in step 1 by respectively adopting a direct averaging method of a plurality of curves, and the permeability curve of each small sample rock sample is calculated.
4. The method for processing the permeability curve of different reservoirs according to claim 1, wherein in step 4, after the permeability curve of each small layer in step 2 is normalized, the weighted average of a plurality of curves is performed according to the weight occupied in step 3, so as to obtain the permeability curve of an oil field block or unit.
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