CN110529079B - Method and device for controlling oil production liquid yield - Google Patents
Method and device for controlling oil production liquid yield Download PDFInfo
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- CN110529079B CN110529079B CN201910750824.3A CN201910750824A CN110529079B CN 110529079 B CN110529079 B CN 110529079B CN 201910750824 A CN201910750824 A CN 201910750824A CN 110529079 B CN110529079 B CN 110529079B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
Abstract
The invention relates to a method and a device for controlling oil production and liquid production, belonging to the technical field of development and informatization construction of oil-water wells, wherein the maximum negative pressure delta p is calculated according to physical parameters of a production zone, and is a negative pressure critical value for promoting particles to move; calculating the working fluid level height delta h corresponding to the maximum negative pressure delta p according to the pressure balance relation; calculating the liquid level descending depth s in the oil-water well according to the working liquid level height delta h; selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure delta p; the production is carried out by the liquid production amount, and the problem that the oil-water well in the prior art cannot maintain high-efficiency and stable production for a long time is solved.
Description
Technical Field
The invention relates to a method and a device for controlling oil production and liquid production, belonging to the technical field of development informatization construction of oil-water wells.
Background
In the actual production process of the oil field, in order to maximize the industrial quantity and obtain the highest yield during fixed-production oil extraction, the pumping unit needs to adjust the pumping frequency according to the constantly changing parameters of the oil well so as to achieve a reasonable working state. However, in the existing production process, a proper liquid extraction system is usually established for production according to the magnitude of the production pressure difference. According to the production pressure difference, the larger the working fluid level depth of the oil-water well is reduced, the higher the oil production yield can be known according to the Q-s model, but in the actual situation, the lower the working fluid level can cause the sinking degree of the oil-well pump to be reduced, and the lower the yield is. Therefore, on one hand, in order to continuously increase the yield, the pump diameter and the pump hanging depth of the underground oil extraction device are continuously increased, and the submergence degree is ensured to meet the requirement of the pump displacement, however, the bottom hole negative pressure exceeds the bearing capacity of a production layer due to excessive yield, the interlayer is damaged due to light weight, interlayer channeling is caused, and the yield is reduced; the serious causes the oil-water well casing to be damaged and scrapped to stop production, so that the service life of the oil production well is greatly reduced;
on the other hand, in order to avoid damage to oil wells and oil extraction equipment, field workers usually reserve the pump submergence degree when establishing the production pressure difference, so that the production process is not carried out with the maximum yield all the time, the yield is low, the energy consumption is high, and the development and utilization efficiency of the oil field is not high and the production is unstable.
Therefore, the existing oil production well cannot maintain efficient and stable production for a long time due to unreasonable production pressure difference customization. How to set a set of reasonable and efficient oil extraction liquid production amount control method is crucial to the oil-water well condition.
Disclosure of Invention
The invention aims to provide a method and a device for controlling the oil production liquid yield, which solve the problem that an oil-water well in the prior art cannot maintain efficient and stable production for a long time.
In order to achieve the purpose, the technical scheme of the invention is as follows: the invention provides a method for controlling oil production liquid yield, which comprises the following steps:
1) calculating the maximum negative pressure delta p according to the physical property parameters of the production layer, wherein the maximum negative pressure delta p is a negative pressure critical value for promoting the migration of particles; calculating the working fluid level height delta h corresponding to the maximum negative pressure delta p according to the pressure balance relation;
2) calculating the liquid level descending depth s in the oil-water well according to the working liquid level height delta h;
3) selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure delta p;
4) and producing according to the liquid production amount.
The invention also provides an oil recovery production control device, which comprises a processor, a memory and a computer program stored on the memory and running on the processor, wherein the processor executes the computer program to realize the following steps:
1) calculating the maximum negative pressure delta p according to the physical property parameters of the production layer, wherein the maximum negative pressure delta p is a negative pressure critical value for promoting the migration of particles; calculating the working fluid level height delta h corresponding to the maximum negative pressure delta p according to the pressure balance relation;
2) calculating the liquid level descending depth s in the oil-water well according to the working liquid level height delta h;
3) selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure delta p;
4) and producing according to the liquid production amount.
For the method and the device, the maximum negative pressure is calculated according to the physical property parameters of the production layer, and the working fluid level height corresponding to the maximum negative pressure is obtained, so that the descending depth of the liquid level in the well under the maximum negative pressure is obtained, the liquid production amount corresponding to the maximum negative pressure is obtained, the working fluid level is controlled in the safe negative pressure in the production process, the damage effect on the stratum rock framework and the damage of a well bottom pipe column are avoided, and the oil-water well can maintain the long-term and stable production process; and the maximum liquid production amount corresponding to the maximum negative pressure is obtained, so that an optimal production plan is formulated, the most efficient production process is realized, and the oil field development efficiency is improved.
Further, with regard to the method and the device, in order to accurately obtain the maximum negative pressure in the oil-water well, the method for calculating the maximum negative pressure Δ p according to the physical property parameters of the production zone is as follows: when the permeability of the near-well reservoir is less than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
when the permeability of the near-well reservoir is more than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
in the formula:
production zone communicated porosity,%; dpThe diameter of a perforation hole or the width of a crack of a production layer of the oil-water well is mm; Δ p is the maximum negative pressure, MPa; k is the permeability of the oil-water well production zone, mD.
Further, with respect to the method and the apparatus, in order to accurately obtain the working fluid level height corresponding to the maximum negative pressure, the manner of calculating the working fluid level height Δ h corresponding to the maximum negative pressure Δ p according to the pressure balance relationship is as follows: substituting the maximum negative pressure delta p into the following formula to calculate the working fluid level height delta h:
wherein, PfThe formation pressure of the oil-water well is MPa; delta h is the working fluid level height m; g is Newton's gravitational acceleration coefficient, 9.8m/s2(ii) a Rho is the liquid density, kg/m3。
Further, for the method and the device, in order to obtain a reasonable liquid level drop depth and guide production, the method for calculating the liquid level drop depth s in the oil-water well according to the working fluid level height Δ h comprises the following steps: substituting the working fluid level height delta h into the following formula to calculate the liquid level descending height s:
s＝H-Δh-H0
in the formula: s is the liquid level descending depth m; h is the depth of the middle part of the production layer of the oil-water well, m; h0The depth of the static liquid level of the oil-water well is m.
Further, for the method and the device, in order to obtain accurate fluid production and avoid the problem of large maximum fluid production calculation error caused by inaccurate model selection by manually utilizing well test data, the process of selecting the Q-s model according to the stratum condition of the production zone comprises the following steps:
(1) calculating the curvature coefficient distinguished by the oil-water well Q-s model according to the oil-water well test data: respectively reading three groups of well testing yield sequences (Q) in well testing data of the oil-water well1，Q2，Q3And corresponding liquid level down depth s1，s2，s3And selecting two groups of well testing yield sequences and corresponding liquid level descending depths, and calculating the curvature coefficient according to the following formula:
(2) selecting an oil-water well Q-s model: according to the calculated curvature coefficient, selecting a model according to the following rules: when n is>And 2, selecting the Q-s model as a logarithmic model: q ═ a + bln s; when n is 2, the Q-s model is selected to be parabolic: s is a × Q + b × Q2(ii) a When 1 is<n<When 2, the Q-s model is selected as a power function type: ln Q ═ ln a + b × ln s; when n is 1, selecting the Q-s model as a straight line type: q ═ a + b × s; when n is<1, if the well testing data of the oil-water well is wrong, the correct well testing data needs to be obtained again;
(3) determining coefficients a and b in the Q-s model: and determining coefficients a and b in Q-S models before and after the acidizing and fracturing construction of the oil-water well by using the three groups of read well testing yield sequences and the corresponding liquid level descending depths by adopting a least square method.
Drawings
FIG. 1 is a flow chart of a maximum liquid production calculation procedure of an oil-water well according to the present invention;
FIG. 2 is a flow chart of the well testing data processing and fluid production model selection process of the present invention.
Detailed Description
Under the condition of sufficient liquid supply, the larger the decrease of the working fluid level depth of the oil-water well is, the higher the yield is; however, after the physical properties and the pressure of the stratum are considered, the yield has an inflection point, and when the yield exceeds the inflection point, the rock cementing skeleton is broken, the sand is produced from the stratum, and the yield is not increased any more but is reduced; continuously amplifying the yield, wherein the liquid level is excessively reduced, the bottom negative pressure is increased, and the light part causes the interlayer damage, the interlayer channeling is caused, and the yield is reduced; the serious cause is the damage and the abandonment of the oil-water well casing. The basic principle of the method is that the fluid at the far end of the stratum rapidly flows to a near wellbore zone under the action of differential pressure by utilizing that the pressure of a liquid column of the wellbore is lower than the pressure of a reservoir layer, so that a scouring effect is generated, the blockage is removed, and the fluid is taken out of the wellbore, thereby achieving the purpose of removing the blockage. For oil-water wells, if the negative pressure is too high, the skeleton of the far-end stratum is easily damaged, so that the sand production of the stratum is more serious or underground casings and pipe columns are damaged.
The method comprises the following steps:
in the embodiment, the bottom negative pressure is taken into consideration, the oil production liquid yield control method is designed, the maximum bottom negative pressure is calculated, and the maximum liquid yield is obtained under the condition that a production zone, a bottom pipe column and the like are not damaged, so that production is realized according to the liquid yield, and long-term stable and efficient production of the oil-water well is realized.
Embodiments of the present invention will be described in further detail below with reference to the accompanying drawings.
This embodiment provides a method for controlling oil production, as shown in fig. 1, which gives a specific flowchart:
1) calculating the maximum negative pressure according to the physical property parameters of the production layer, wherein the maximum negative pressure is a negative pressure critical value for promoting the migration of stratum particles; and calculating the height of the working fluid level corresponding to the maximum negative pressure according to the pressure balance relation.
In the production process of the oil-water well, the continuous stable production period is improved, firstly, the stratum rock framework is ensured not to be damaged, the migration of reservoir particles is avoided, and the pipe column in the well can keep normal operation. The method for calculating the maximum negative pressure of the oil-water well comprises the following steps: when the permeability of the negative pressure layer is less than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
when the permeability of the near-well reservoir is more than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
in the formula:
production zone communicated porosity,%; dpThe diameter of a perforation hole or the width of a crack of a production layer of the oil-water well is mm; Δ p is the maximum negative pressure, MPa; k is the permeability of the oil-water well production zone, mD.
As another embodiment, the present invention is not limited to the above algorithm for calculating the maximum negative pressure, and a calculation method designed by Conoco corporation in the united states may be used: ln Δ P ═ 17.24/k0.3Or a maximum negative pressure calculation formula obtained according to an empirical relationship: ln Δ P-5.471-0.3668 ln k, where k is the permeability of the producing formation.
Then the height of the working fluid level corresponding to the maximum negative pressure is obtained according to the maximum negative pressure, and the height of the working fluid level corresponding to the maximum negative pressure is calculated according to the pressure balance relationship, wherein the method specifically comprises the following steps:
wherein, PfThe formation pressure of the oil-water well is MPa; delta h is the height from the working fluid level to the middle part of the production layer of the oil-water well, m; g is Newton's gravitational acceleration coefficient, 9.8m/s2(ii) a Rho is the liquid density, kg/m3。
2) Calculating the liquid level descending depth s in the oil-water well according to the dynamic liquid level height;
substituting the height of the working fluid level into the following formula to calculate the height s of the liquid level drop:
s＝H-Δh-H0
in the formula: s is the liquid level descending depth m; h is the depth of the middle part of the production layer of the oil-water well, m; delta h is the height from the working fluid level to the middle of the production layer, m; h0The depth of the static liquid level of the oil-water well is m.
3) Selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure;
the yield change rule in the production process of the oil-water well is usually described by adopting a Q-s model, and the actual model is selected by adopting a method for calculating the curvature coefficient in the embodiment so as to obtain the maximum liquid production amount corresponding to the maximum negative pressure. As shown in FIG. 2, the present invention provides a flow chart for selecting a Q-s model by using a curvature method, and the specific selection steps are as follows:
(1) calculating the curvature coefficient n distinguished by the oil-water well Q-s model according to the oil-water well test data: respectively reading three groups of well testing yield sequences (Q) in well testing data of the oil-water well1’，Q2’，Q3' } and corresponding liquid level descent depth s1’，s2’，s3' }, the curvature coefficient is calculated according to the following formula.
(2) Selecting an oil-water well Q-s model according to the curvature coefficient obtained by calculation: according to the calculated curvature coefficient, selecting a model according to the following rules:
when n >2, the Q-s model is selected to be logarithmic: q ═ a + bln s;
when n is 2, the Q-s model is selected to be parabolic: s is a × Q + b × Q2；
When 1< n <2, the Q-s model is chosen to be a power function: ln Q is lna + b × ln s;
when n is 1, selecting the Q-s model as a straight line type: q ═ a + b × s;
when n <1, the well testing data of the oil-water well is wrong, and the correct well testing data needs to be obtained again.
(3) After the corresponding Q-s model is selected, the Q-s model needs to be determinedCoefficients a and b of (a): using reading three sets of well test production sequences { Q1，Q2，Q3And corresponding liquid level down depth s1，s2，s3And determining coefficients a and b in the Q-S model before and after the acidizing and fracturing construction of the oil-water well by adopting a least square method. As a further improvement to the above embodiment, in determining the coefficients a and b, in addition to the least square method, a graphical method and an equalization error method may be used for the determination.
In this embodiment, the Q-s model is selected by the curvature method, and as another embodiment, the Q-s model may be selected by a difference method, which may be represented by a curve fitting error c, and different from the above method, three groups of well testing yield sequences { Q } are required to be used1’，Q2’，Q3' } and corresponding liquid level descent depth s1’，s2’，s3' } to calculate the fitting error.
4) And producing according to the liquid production amount.
And after the liquid production amount corresponding to the maximum negative pressure is obtained, production is carried out according to the maximum liquid production amount, so that the maximum liquid production amount is obtained in the safety negative pressure when the yield of the oil-water well is determined in the production process. And then, a reasonable and efficient oil production plan is formulated by adjusting the depth and the sinking degree of the oil extraction pump and stroke sprint.
The embodiment of the device is as follows:
the oil recovery liquid production amount control device provided by the invention comprises a processor and a memory, wherein a computer program for running on the processor is stored in the memory, the processor can be realized by adopting a single chip microcomputer, an FPGA, a DSP, a PLC, an MCU or the like, the memory can be a RAM memory, a flash memory, a ROM memory, an EPROM memory, an EEPROM memory, a register, a hard disk, a removable disk, a CD-ROM or any other form of storage medium known in the art, the storage medium can be coupled to the processor so that the processor can read information from the storage medium, or the storage medium can be a component of the processor.
Execution of the computer program by the processor enables the following scheduling steps to be implemented: 1) calculating the maximum negative pressure according to the physical parameters of the production layer, wherein the maximum negative pressure is a negative pressure critical value for promoting the migration of particles; calculating the height of the working fluid level corresponding to the maximum negative pressure according to the pressure balance relation;
2) calculating the liquid level descending depth s in the oil-water well according to the dynamic liquid level height;
3) selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure;
4) and producing according to the liquid production amount.
The specific implementation of each step has been described in detail in the method embodiments, and is not described herein again.
The key point of the present invention is to provide a thought, and any method and device for controlling the oil production liquid amount under the maximum negative pressure are within the protection scope of the present invention.
Claims (8)
1. The method for controlling the oil production liquid yield is characterized by comprising the following steps:
1) calculating the maximum negative pressure delta p according to the physical property parameters of the production layer, wherein the maximum negative pressure delta p is a negative pressure critical value for promoting the migration of particles of the stratum where the production layer is located in an oil-water well corresponding to the production layer; calculating the working fluid level height delta h corresponding to the maximum negative pressure delta p according to the pressure balance relation;
2) calculating the liquid level descending depth s in the oil-water well according to the working liquid level height delta h;
3) selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure delta p; the process of selecting the Q-s model according to the formation conditions of the producing layer comprises the following steps:
(1) calculating the curvature coefficient distinguished by the oil-water well Q-s model according to the oil-water well test data: respectively reading three groups of well testing yield sequences (Q) in well testing data of the oil-water well1，Q2，Q3And corresponding liquid level drop depthDegree { s }1，s2，s3And selecting two groups of well testing yield sequences and corresponding liquid level descending depths, and calculating the curvature coefficient according to the following formula:
(2) selecting an oil-water well Q-s model: according to the calculated curvature coefficient, selecting a model according to the following rules: when n is>And 2, selecting the Q-s model as a logarithmic model: q ═ a + blns; when n is 2, the Q-s model is selected to be parabolic: s is a × Q + b × Q2(ii) a When 1 is<n<When 2, the Q-s model is selected as a power function type: lnQ ═ lna + b × lns; when n is 1, selecting the Q-s model as a straight line type: q ═ a + b × s; when n is<1, if the well testing data of the oil-water well is wrong, the correct well testing data needs to be obtained again;
(3) determining coefficients a and b in the Q-s model: determining coefficients a and b in Q-S models before and after the acidizing and fracturing construction of the oil-water well by using the three groups of read well testing yield sequences and the corresponding liquid level descending depths;
4) and producing according to the liquid production amount.
2. The method for controlling the amount of produced fluid for oil recovery according to claim 1, wherein the maximum negative pressure Δ p is calculated from the physical property parameters of the production zone by: when the permeability of the near-well reservoir is less than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
when the permeability of the near-well reservoir is more than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
in the formula:
communicating porosity,%, to the production zone; dpThe diameter of a perforation hole or the width of a crack of a production layer of the oil-water well is mm; Δ p is the maximum negative pressure, MPa; and k is the permeability of the oil-water well production zone, mD.
3. The method for controlling the amount of produced fluid in oil recovery according to claim 1, wherein the calculation of the working fluid level Δ h corresponding to the maximum negative pressure Δ p based on the pressure balance relationship is performed by: substituting the maximum negative pressure delta p into the following formula to calculate the working fluid level height delta h:
wherein, PfThe formation pressure of the oil-water well is MPa; delta h is the working fluid level height m; g is Newton's gravitational acceleration coefficient, 9.8m/s2(ii) a Rho is the liquid density, kg/m3。
4. The method for controlling the amount of produced fluid in oil recovery according to claim 1, wherein the manner of calculating the lowering depth s of the fluid level in the oil-water well according to the working fluid level Δ h is as follows: substituting the working fluid level height delta h into the following formula to calculate the liquid level descending height s:
s＝H-Δh-H0
in the formula: s is the liquid level descending depth m; h is the depth of the middle part of the production layer of the oil-water well, m; h0The depth of the static liquid level of the oil-water well is m.
5. An oil recovery production control device comprising a processor and a memory, and a computer program stored on the memory and running on the processor, the processor implementing the following steps when executing the computer program:
1) calculating the maximum negative pressure delta p according to the physical property parameters of the production layer, wherein the maximum negative pressure delta p is a negative pressure critical value for promoting the migration of particles of the stratum where the production layer is located in an oil-water well corresponding to the production layer; calculating the working fluid level height delta h corresponding to the maximum negative pressure delta p according to the pressure balance relation;
2) calculating the liquid level descending depth s in the oil-water well according to the working liquid level height delta h;
3) selecting a Q-s model according to the stratum condition of a production layer, substituting the liquid level descent depth s into the selected Q-s model, and obtaining the liquid production amount corresponding to the maximum negative pressure delta p; the process of selecting the Q-s model according to the formation conditions of the producing layer comprises the following steps:
(1) calculating the curvature coefficient distinguished by the oil-water well Q-s model according to the oil-water well test data: respectively reading three groups of well testing yield sequences (Q) in well testing data of the oil-water well1，Q2，Q3And corresponding liquid level down depth s1，s2，s3And selecting two groups of well testing yield sequences and corresponding liquid level descending depths, and calculating the curvature coefficient according to the following formula:
(2) selecting an oil-water well Q-s model: according to the calculated curvature coefficient, selecting a model according to the following rules: when n is>And 2, selecting the Q-s model as a logarithmic model: q ═ a + blns; when n is 2, the Q-s model is selected to be parabolic: s is a × Q + b × Q2(ii) a When 1 is<n<When 2, the Q-s model is selected as a power function type: lnQ ═ lna + b × lns; when n is 1, selecting the Q-s model as a straight line type: q ═ a + b × s; when n is<1, if the well testing data of the oil-water well is wrong, the correct well testing data needs to be obtained again;
(3) determining coefficients a and b in the Q-s model: determining coefficients a and b in Q-S models before and after the acidizing and fracturing construction of the oil-water well by using the three groups of read well testing yield sequences and the corresponding liquid level descending depths;
4) and producing according to the liquid production amount.
6. The oil recovery product of claim 5The liquid amount control device is characterized in that the mode of calculating the maximum negative pressure delta p according to the physical property parameters of the production layer is as follows: when the permeability of the near-well reservoir is less than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
when the permeability of the near-well reservoir is more than 100 multiplied by 10-3μm2When the temperature of the water is higher than the set temperature,
in the formula:
communicating porosity,%, to the production zone; dpThe diameter of a perforation hole or the width of a crack of a production layer of the oil-water well is mm; Δ p is the maximum negative pressure, MPa; and k is the permeability of the oil-water well production zone, mD.
7. The oil recovery liquid yield control device according to claim 5, wherein the working fluid level height Δ h corresponding to the maximum negative pressure Δ p is calculated from the pressure balance relationship by: substituting the maximum negative pressure delta p into the following formula to calculate the working fluid level height delta h:
wherein, PfThe formation pressure of the oil-water well is MPa; delta h is the working fluid level height m; g is Newton's gravitational acceleration coefficient, 9.8m/s2(ii) a Rho is the liquid density, kg/m3。
8. The oil recovery production rate control device according to claim 5, wherein the calculation of the liquid level lowering depth s in the well from the working fluid level Δ h is performed by: substituting the working fluid level height delta h into the following formula to calculate the liquid level descending height s:
s＝H-Δh-H0
in the formula: s is the liquid level descending depth m; h is the depth of the middle part of the production layer of the oil-water well, m; h0The depth of the static liquid level of the oil-water well is m.
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| "低液面抽油机井合理间抽制度的确定";刘良华 等;《长江大学学报（自科版）》;20141130;第11卷(第32期);第122-124页 * |
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| CN110529079A (en) | 2019-12-03 |
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