CN116044391A - Method for determining dosage of profile control agent of low permeability reservoir horizontal well - Google Patents
Method for determining dosage of profile control agent of low permeability reservoir horizontal well Download PDFInfo
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- 230000001105 regulatory effect Effects 0.000 abstract description 11
- 238000011161 development Methods 0.000 abstract description 8
- 238000004364 calculation method Methods 0.000 description 6
- 238000002347 injection Methods 0.000 description 4
- 239000007924 injection Substances 0.000 description 4
- 239000003129 oil well Substances 0.000 description 3
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Abstract
The invention provides a method for determining the dosage of a profile control agent for a low permeability reservoir horizontal well, and belongs to the technical field of oilfield development. The method comprises the following steps: acquiring production data and reservoir geological data of a horizontal well; acquiring the large Kong Zhanbi and high permeability layer oil production contribution rate of the reservoir; the profile control agent dosage is obtained through a preset algorithm based on the production data of the horizontal well, the geological data of the reservoir, the large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer. The method considers the regulation depth and well spacing in the actual production process, also considers the influence of the hypertonic layer on regulation through the oil production and the hypertonic layer proportion, also considers the influence of the fracturing volume which is easiest to ignore in the actual production process, finally calculates the dosage of the regulating agent, and has smaller difference between the final calculated result and the actual situation and higher accuracy compared with the traditional method. Therefore, the dosage of the regulator in the dense oil reservoir can be guided, and corresponding technical support is provided for actual production.
Description
Technical Field
The invention relates to the technical field of oilfield development, in particular to a method for determining the dosage of a profile control agent for a horizontal well of a hypotonic oil reservoir.
Background
In the process of water flooding of an ultralow permeability oil reservoir, a water flooding phenomenon inevitably occurs, and injected water rapidly bursts along a hypertonic channel, so that a series of problems such as ineffective circulation of the injected water, reduction of oil well yield and the like are caused. In order to improve the water absorption profile, expand the swept volume of injected water and improve the water recovery efficiency of water flooding, a large number of indoor experiments and field experiments show that the regulation and control of the water injection well is an effective means for solving the water flooding problem. However, in the current horizontal well control process, the dosage of the control agent still does not form a more authoritative calculation method.
The existing calculation method is as follows
Wherein V is the injection amount of the profile control agent and cubic meters; r is a profile control radius and m; l is the length of the horizontal section of the water injection well, m; h is the effective thickness of the oil layer, m; />
Is the porosity of the oil layer, and is dimensionless; alpha is the percentage of the thickness of the high permeable layer to the thickness of the oil layer, and is dimensionless; delta is a direction coefficient, and is dimensionless; beta is a profile control area coefficient, and is dimensionless.
However, the existing calculation method does not consider the artificial reconstruction volume formed by the development of the horizontal well volume fracturing; meanwhile, the high permeable layer of the horizontal well has a short thickness relative to the whole horizontal well section, is not easy to read in a well logging curve of the horizontal well, and has permeability as well as an effective sand body which does not contain oil in a reservoir, but the method does not consider. Therefore, the profile control dosage obtained by the method has larger difference from the actual situation, and is difficult to apply in actual engineering.
Disclosure of Invention
In order to solve at least one of the problems, the invention provides a method for determining the dosage of the profile control agent for the horizontal well of the low permeability reservoir. The dosage of the regulating agent obtained by the method has smaller difference from the actual situation and higher accuracy.
In order to achieve the above object, the technical scheme of the present invention is as follows: a method for determining the dosage of a profile control agent for a horizontal well of a low permeability reservoir comprises the following steps of
S1, acquiring production data and reservoir geological data of a horizontal well;
s2, acquiring the large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer;
s3, obtaining the dosage of the profile control agent through a preset algorithm based on production data of the horizontal well, geological data of the reservoir, large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer, wherein the preset algorithm is as follows:
wherein V is z To regulate the volume of dosage, m 3 The method comprises the steps of carrying out a first treatment on the surface of the D is well spacing, m; h is the effective sand thickness, m; phi is the average porosity corresponding to the thickness of the effective sand body,%; τ is a control depth coefficient, which means the ratio of the control depth to the distance between adjacent wells, ranging from 0 to 1; l (L) k1 Length of the hypertonic section, m; l is the length of a horizontal section of the horizontal well, and m; v (V) k Controlling volume for horizontal well, m 3 ；V frc For frac volume, m 3 ；V h For the current accumulated oil production, m 3 ；V b Calibrating water drive oil recovery for oil reservoir, m 3 The method comprises the steps of carrying out a first treatment on the surface of the χ is the oil recovery contribution rate of the high permeable layer,%; η is larger than Kong Zhanbi, dimensionless.
The beneficial effects are that: the method of the invention considers the regulation depth and well spacing in the actual production process, considers the influence of the high permeability layer on regulation through the oil recovery and the high permeability layer proportion, considers the influence of the fracturing volume which is easiest to ignore in the actual production process, and finally calculates the dosage of the regulating agent. Therefore, the dosage of the regulator in the dense oil reservoir can be guided, and corresponding technical support is provided for actual production.
Drawings
FIG. 1 is a horizontal well development horizon profile.
FIG. 2 shows oil production at different profile depth factors for example 1;
FIG. 3 shows the water content at different profile depth factors in example 1.
Detailed Description
The following detailed description of the invention will be clearly and fully described in connection with the examples which are set forth to illustrate, but are not necessarily all embodiments of the invention.
The invention is further described below with reference to examples:
in the following examples, unless otherwise specified, the operations described are conventional in the art.
S1, acquiring production data and reservoir geological data of a horizontal well; the production data of the horizontal well comprises the length of a horizontal well section and the plane control range of the horizontal well, and the current accumulated oil yield and water drive calibration oil production; the reservoir geological parameters comprise artificial fracture transformation volume, fracture half-joint length, effective sand thickness of a development horizon, average porosity of a horizontal segment and percentage of the length of a high permeability segment to the length of the horizontal segment. These data can be obtained easily by simple logging and lithology analysis.
S2, acquiring the large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer;
wherein, large Kong Zhanbi of the reservoir refers to the percentage of macropore volume to all void volume, which can be obtained by lithology analysis: for example, the ratio of the large pore area of the nuclear magnetism T2 spectrogram to the total area of the spectrogram is obtained; or, the large pore limit is defined by nuclear magnetism, and the large Kong Zhanbi coefficient is obtained by pore size distribution. Meanwhile, macropores in the embodiment of the present invention refer to macropores in the nuclear magnetic spectrum.
For reservoirs, which are typically heterogeneous, the term hypertonic layer in the examples herein refers to a reservoir that is 10 times greater than the lowest permeability of the reservoir, i.e., a relatively hypertonic layer with a 10 permeability differential. The percentage of the oil production of the high permeability layer to the accumulated oil production can be obtained by a plurality of modes such as a parallel core displacement experiment, a heterogeneous multi-layer permeability core displacement experiment, a nuclear magnetic scanning experiment or a numerical simulation method, and the like, and the methods belong to the prior art, so that the method is suitable for the field of oil production.
S3, obtaining the dosage of the profile control agent through a preset algorithm based on production data of the horizontal well, geological data of the reservoir, large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer, wherein the preset algorithm is as follows:
wherein V is z To regulate the volume of dosage, m 3 The method comprises the steps of carrying out a first treatment on the surface of the D is well spacing, m; h is the effective sand thickness, m;
average porosity corresponding to effective sand thickness,%; τ is a control depth coefficient, which means the ratio of the control depth to the distance between adjacent wells, ranging from 0 to 1; l (L) k1 Length of the hypertonic section, m; l is the length of a horizontal section of the horizontal well, and m; v (V) k Controlling the volume for a horizontal well, m3; v (V) frc For frac volume, m 3 ；V h For the current accumulated oil production, m 3 ；V b Calibrating water drive oil recovery quantity for an oil reservoir, and m3; χ is the oil recovery contribution rate of the high permeable layer,%; η is larger than Kong Zhanbi, dimensionless.
As shown in FIG. 1, the effective sand thickness h of the development horizon is regarded as the height of the regulation volume, and is obtained by averaging the division thickness of the horizons of the vertical wells adjacent to the horizontal well, wherein the calculation mode is the average value of the thicknesses of the two adjacent vertical wells of the horizontal well section to be measured at the horizon of the horizontal well section, namely
In the actual production process, the adjustment depth coefficient τ is usually set to different values according to different actual conditions, such as different lithology, fracture conditions and oil extraction conditions, in some wells, the adjustment depth needs to be larger, and in other wells, the adjustment depth needs to be controlled within a certain level. Therefore, when calculating the above predetermined algorithm, a person skilled in the art can set the corresponding τ value according to the actual situation in the field.
In the predetermined algorithm, the regulation depth and the well spacing in the actual production process are considered, meanwhile, the influence of the hypertonic layer on regulation is considered through oil production and the hypertonic layer proportion, and the influence of the fracturing volume which is most easily ignored in the actual production process is considered, so that the finally obtained result has better accuracy compared with the conventional method.
However, at present, each large oil field usually determines τ value through on-site situation and production experience, so that a certain error exists in the obtained result, and therefore, in the embodiment of the invention, a more accurate result can be obtained by the following method: when the preset algorithm is adopted for calculation, a plurality of different values of common regulating depth coefficients in the field are set in the range of 0-1, then the values are calculated respectively to obtain a plurality of different regulating agent dosages, then the regulation simulation is carried out by adopting conventional commercial simulation software, and finally, a regulation means with higher cost performance is optimized according to indexes such as the oil content of produced liquid, the oil yield and the like. The commercial simulation software may employ CMG-Stars software commonly used in the art.
As can be seen from the above description, the method for determining the dosage of the low-permeability horizontal well regulator provided by the embodiment considers the absolute regulation capability of the reservoir and the flooding degree of the oil well in different water breakthrough periods, thereby reasonably designing the dosage design of the horizontal well regulation and control and meeting the field regulation and control requirements.
Example 1
The average permeability of a certain oil reservoir development layer is 10mD, the average porosity is 10%, the length of a horizontal well section is 800m, the injection and production well spacing is 500m, and the effective sand thickness of a reservoir is 10m. The development mode is that the horizontal well is subjected to volume fracturing, and the fracturing volume is 63744m 3 The large Kong Zhanbi is 0.35, the length of the high permeable layer is calculated to be 0.375 of the length of the horizontal well, and the current accumulated oil yield is 60410m 3 The water drive calibrated oil recovery is 300000m 3 The oil extraction contribution rate of the tested high-permeability layer is 0.7.
According to a predetermined algorithm
Calculating, wherein the adjacent well distance is 500m, when the regulating depth is 50m, 100m, 200m, 300m, 400m and 500m, the regulating depth coefficients are 0.1, 0.2, 0.4, 0.6, 0.8 and 1 respectively, and the dosage of the profile control agent required by calculation is 4789m 3 、9578m 3 、19156m 3 、28734m 3 、38312m 3 、47890m 3 。
And establishing a water drive model of the oil well pattern by CMG-Stars software, and simulating profile control effects of different control depths. As shown in fig. 2 and 3, the relationship between the oil yield and the water content of the produced fluid under the condition of different regulating depth coefficients is shown, and it can be seen from the graph that when the regulating depth coefficient is 0.8, the oil yield is higher, and the water content of the produced fluid is relatively lower, so that the economical efficiency is higher at present, and therefore, the preferential result is that: the regulating depth coefficient is 0.8, and the dosage of regulating agent is 38312m 3 。
The present invention is not limited to the above-mentioned embodiments, but is intended to be limited to the following embodiments, and any modifications, equivalents and modifications can be made to the above-mentioned embodiments without departing from the scope of the invention.
Claims (6)
1. A method for determining the amount of a profile control agent for a horizontal well in a low permeability reservoir, comprising the steps of:
s1, acquiring production data and reservoir geological data of a horizontal well;
s2, acquiring the large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer;
s3, obtaining the dosage of the profile control agent through a preset algorithm based on production data of the horizontal well, geological data of the reservoir, large Kong Zhanbi of the reservoir and the oil production contribution rate of the hypertonic layer, wherein the preset algorithm is as follows:
wherein V is z To regulate the volume of dosage, m 3 The method comprises the steps of carrying out a first treatment on the surface of the D is well spacing, m; h is the effective sand thickness, m; phi is the average porosity corresponding to the thickness of the effective sand body,%; τ is a control depth coefficient, which means the ratio of the control depth to the distance between adjacent wells, ranging from 0 to 1; l (L) k1 Length of the hypertonic section, m; l is the length of a horizontal section of the horizontal well, and m; v (V) k Controlling volume for horizontal well, m 3 ；V frc For frac volume, m 3 ；V h For the current accumulated oil production, m 3 ；V b Calibrating water drive oil recovery for oil reservoir, m 3 The method comprises the steps of carrying out a first treatment on the surface of the χ is the oil recovery contribution rate of the high permeable layer,%; η is larger than Kong Zhanbi, dimensionless.
2. The method of claim 1, wherein the large Kong Zhanbi of the reservoir is obtained by the ratio of the large pore area of the nuclear magnetic T2 spectrum to the total area of the spectrum; or, the large pore limit is defined by nuclear magnetism, and the large Kong Zhanbi coefficient is obtained by pore size distribution.
3. The method of claim 1, wherein the high permeability layer oil recovery contribution is obtained by a parallel core displacement experiment, a heterogeneous multi-layer permeability core displacement experiment, a nuclear magnetic scan experiment, or a numerical simulation method.
4. A method according to claim 3, wherein the hypertonic layer oil recovery contribution is: the ratio of the accumulated oil recovery rate of the high permeability layer to the accumulated oil production rate.
5. The method of claim 1, wherein the effective sand thickness is an average value of thicknesses of two adjacent vertical wells of the horizontal well section to be measured at a level of the horizontal well section.
6. The method of claim 1, wherein the plurality of profile control agent amounts are obtained by setting values of a plurality of control depth coefficients, and then the profile control agent amounts are optimized using software CMG-Stars.
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