CN113294148A - Method and device for determining pumping cycle of oil-water two-phase pumping well of water-drive thin oil reservoir - Google Patents
Method and device for determining pumping cycle of oil-water two-phase pumping well of water-drive thin oil reservoir Download PDFInfo
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- CN113294148A CN113294148A CN202010750981.7A CN202010750981A CN113294148A CN 113294148 A CN113294148 A CN 113294148A CN 202010750981 A CN202010750981 A CN 202010750981A CN 113294148 A CN113294148 A CN 113294148A
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- 238000005086 pumping Methods 0.000 title claims abstract description 220
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 60
- 238000000034 method Methods 0.000 title claims abstract description 37
- 239000007788 liquid Substances 0.000 claims abstract description 217
- 239000012530 fluid Substances 0.000 claims description 97
- 238000004519 manufacturing process Methods 0.000 claims description 61
- 230000000630 rising effect Effects 0.000 claims description 36
- 239000003921 oil Substances 0.000 claims description 35
- 239000010779 crude oil Substances 0.000 claims description 32
- 238000004590 computer program Methods 0.000 claims description 16
- 230000008569 process Effects 0.000 claims description 6
- 238000011084 recovery Methods 0.000 claims description 6
- 238000012360 testing method Methods 0.000 claims description 5
- 238000010586 diagram Methods 0.000 description 18
- 230000015572 biosynthetic process Effects 0.000 description 10
- 230000006870 function Effects 0.000 description 4
- 230000008859 change Effects 0.000 description 2
- 238000009795 derivation Methods 0.000 description 2
- NAWXUBYGYWOOIX-SFHVURJKSA-N (2s)-2-[[4-[2-(2,4-diaminoquinazolin-6-yl)ethyl]benzoyl]amino]-4-methylidenepentanedioic acid Chemical compound C1=CC2=NC(N)=NC(N)=C2C=C1CCC1=CC=C(C(=O)N[C@@H](CC(=C)C(O)=O)C(O)=O)C=C1 NAWXUBYGYWOOIX-SFHVURJKSA-N 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
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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
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
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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 discloses a method and a device for determining a pumping cycle of an oil-water two-phase pumping well of a water-drive thin oil reservoir, wherein the method comprises the following steps: determining the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height; and determining the pumping period of the pumping well according to the elapsed time. The invention can simply and conveniently determine a reasonable pumping period, fully recover the liquid level in the shaft and contribute to next drainage of the stratum.
Description
Technical Field
The invention relates to the technical field of petroleum logging, in particular to a method and a device for determining a pumping cycle of an oil-water two-phase pumping well of a water-drive thin oil reservoir.
Background
This section is intended to provide a background or context to the embodiments of the invention that are recited in the claims. The description herein is not admitted to be prior art by inclusion in this section.
In the pumping well, formation fluid flows into a shaft from the formation by means of the elasticity of the formation fluid, is stored in the shaft, and is pumped by pumping equipment after the crude oil level rises to a certain height. After the pumping operation is finished, the liquid level of the fluid in the shaft is lowered, the pressure is reduced, the formation fluid flows into the shaft again, after a certain amount of crude oil is stored in the shaft, the next oil fishing is carried out, and the process is repeated.
In a water-drive thin oil reservoir, the fluid in the well is oil-water two-phase, the liquid level rising speed is higher than that of a thick oil well, the oil and the water are mixed phase fluid, and the pumped fluid is also oil-water two-phase mixed fluid. In the process of storing and collecting the fluid in the shaft, the amount of the fluid entering the well is increased, the liquid level in the shaft is gradually increased, the flowing pressure of the shaft is increased, the production pressure difference is reduced, and the speed of the fluid flowing into the well is gradually reduced. If the pumping cycle is long, the bottom hole flow pressure will rise until it is balanced with the formation pressure, at which time the fluid in the formation will no longer flow into the well, and if the pumping cycle is short, the number of times of pumping increases, the pumping cost increases, and the formation will be damaged, so it is very important to determine a reasonable pumping cycle. However, there is no effective solution in the prior art that can determine a reasonable pumping period.
Disclosure of Invention
The embodiment of the invention provides a method for determining a pumping cycle of an oil-water two-phase pumping well of a water-drive thin oil reservoir, which is used for determining a reasonable pumping cycle and comprises the following steps:
determining the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height;
and determining the pumping period of the pumping well according to the elapsed time.
The embodiment of the invention also provides a device for determining the pumping cycle of the oil-water two-phase pumping well of the water-drive thin oil reservoir, which is used for determining the reasonable pumping cycle and comprises the following components:
the passage duration determining module is used for determining the passage duration of the liquid level in the shaft of the pumping well, which is recovered from the initial liquid pad height to the highest height;
and the pumping cycle determining module is used for determining the pumping cycle of the pumping well according to the elapsed time length.
The embodiment of the invention also provides computer equipment which comprises a memory, a processor and a computer program which is stored on the memory and can be operated on the processor, wherein the processor executes the computer program to realize the method for determining the pumping cycle of the water-drive thin oil reservoir oil-water two-phase pumping well.
The embodiment of the invention also provides a computer readable storage medium, which stores a computer program for executing the method for determining the oil-water two-phase pumping well pumping cycle of the water-drive thin oil reservoir.
In the embodiment of the invention, the time length of the liquid level in the shaft of the pumping well recovering from the initial liquid pad height to the highest height is determined; and determining the pumping period of the pumping well according to the elapsed time, thereby simply and conveniently determining the reasonable pumping period, fully recovering the liquid level in the shaft and facilitating the next drainage of the stratum.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts. In the drawings:
FIG. 1 is a schematic diagram of a method for determining a pumping cycle of an oil-water two-phase pumping well of a water-flooding thin oil reservoir according to an embodiment of the present invention;
FIG. 2 is a diagram illustrating an embodiment of a method for determining a pumping cycle of an oil-water two-phase pumping well in a water-flooding thin oil reservoir according to an embodiment of the present invention;
FIG. 3 is an example diagram of an oil-water two-phase pumping well of a water-drive thin oil reservoir in an embodiment of the present invention;
FIG. 4 is a schematic diagram of a device for determining a pumping cycle of an oil-water two-phase pumping well of a water-flooding thin oil reservoir according to an embodiment of the present disclosure;
FIG. 5 is a diagram illustrating an embodiment of an apparatus for determining a pumping cycle of an oil-water two-phase pumping well in a water-flooding thin oil reservoir according to an embodiment of the present invention;
fig. 6 is a diagram illustrating an embodiment of a pumping cycle determining apparatus for an oil-water two-phase pumping well of a water-flooding thin oil reservoir according to an embodiment of the present invention.
Detailed Description
In order to make the objects, technical solutions and advantages of the embodiments of the present invention more apparent, the embodiments of the present invention are further described in detail below with reference to the accompanying drawings. The exemplary embodiments and descriptions of the present invention are provided to explain the present invention, but not to limit the present invention.
Fig. 1 is a schematic diagram of a method for determining a pumping cycle of an oil-water two-phase pumping well of a water-drive thin oil reservoir in an embodiment of the present invention, as shown in fig. 1, the method includes:
and 102, determining a pumping cycle of the pumping well according to the elapsed time.
As can be seen from the flow shown in fig. 1, the embodiment of the present invention can simply and conveniently determine a reasonable pumping cycle, thereby not only fully recovering the liquid level in the wellbore, but also facilitating the next drainage of the formation.
In specific implementation, the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height is determined. In an embodiment, the pressure change in the pumping well can be tested, and the initial pressure, namely the first pressure corresponding to the liquid level in the shaft at the initial liquid cushion height, is P0The final pressure, i.e. the second pressure corresponding to the liquid level in the wellbore returning to the maximum height, is PTWhen P isTThe difference between the pressure value and the next point is less than the threshold value, for example, the difference between the pressure value and the next point is less than or equal to 0.01MPa/d, and the pressure at the point is considered to be PTThe elapsed time is the elapsed time for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height, and is T. In embodiments, the fluid level, P, in the wellbore may be monitored0Corresponding to the initial liquid cushion height h of the liquid level in the shaft0，PTCorresponding to the highest height h of the liquid level in the shaftT。
Fig. 2 is a diagram illustrating an embodiment of a method for determining a pumping cycle of an oil-water two-phase pumping well in a water-drive thin oil reservoir according to the present invention, as shown in fig. 2, in the embodiment, determining the pumping cycle of the pumping well according to an elapsed time period for a liquid level in a well bore of the pumping well to return from an initial liquid pad height to a maximum height may include:
and step 206, determining a pumping period of the pumping well according to the rising speed of the liquid level in the shaft.
In an embodiment, determining the volume of fluid in the well bore of the dip well that returns to the maximum height from the initial fluid pad height may include: determining the volume of crude oil and the volume of water, wherein the liquid level in a shaft of the pumping well is recovered to the highest height from the initial liquid pad height; and determining the fluid volume according to the crude oil volume and the water volume, the crude oil volume coefficient and the water volume coefficient.
For example, the height h may be pumped using a pumping device0To hTThe liquid is completely fished out, and the liquid level in the shaft of the ground measuring pumping well is recovered to the crude oil volume V from the initial liquid cushion height to the highest heightOThe liquid level in the shaft of the pumping well is recovered to the water volume V from the initial liquid cushion height to the highest heightW. Determining the fluid volume of the liquid level in the shaft of the pumping well, which is recovered to the highest height from the initial liquid pad height, according to the following formula, namely the downhole fluid yield:
Vdownhole production＝BOVO+BWVW；
Wherein, VDownhole productionIs the downhole fluid production; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well.
In an embodiment, determining the daily production of fluid in the pumping well according to the duration of time for which the fluid level in the pumping well shaft is restored from the initial fluid pad height to the maximum height and the fluid volume may include:
determining the daily production of the fluid in the pumping well according to the following formula:
wherein, VDownhole daily productionIs the daily production of downhole fluid; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height for the liquid level in the shaft of the pumping well; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
In an embodiment, determining the fluid production index of the pumped well according to the daily production of the downhole fluid, the first pressure and the second pressure may include:
determining the liquid production index of the pumping well according to the following formula:
wherein J is the liquid production index of the pumping well; vDownhole daily productionIs the daily production of downhole fluid; pTA second pressure; p0A first pressure; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height for the liquid level in the shaft of the pumping well; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
In an embodiment, determining a drawdown well bore reservoir constant based on the downhole fluid production, the first pressure, and the second pressure comprises:
determining a pumping well shaft reservoir constant according to the following formula:
wherein C is a well shaft storage constant of the pumping well; vDownhole productionIs the downhole fluid production; pTA second pressure; pOA first pressure; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well.
In an embodiment, determining a rate of fluid level rise in the wellbore based on the fluid production index and the wellbore reservoir constant may include: and determining the rising speed of the liquid level in the shaft according to the liquid production index, the shaft storage constant and the second pressure and the flow pressure in the liquid level recovery process in the shaft of the pumping well. For example, the rate at which the fluid level rises in the wellbore can be determined according to the following equation:
wherein, VDownhole production tDownhole fluid production at time t; j is the liquid production index of the pumping well; pTA second pressure; pwftThe flow pressure at the time t in the process of recovering the liquid level in the shaft of the pumping well; c is a well shaft storage constant of the pumping well;
the rising speed of the liquid level in the shaft is as follows:
wherein h istThe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0Is the initial fluid pad height of the fluid level in the wellbore.
The specific formula derivation process can be as follows:
fluid production index formula: vDownhole production t＝J(PT-Pwft) (1) formula of downhole fluid production and bottom hole pressure:
therefore:
the two sides of the formula (3) are integrated:
wherein b is a constant term;
when t is 0, Pwft＝P0Therefore, it is
Where ρ iso+wThe density of the mixed liquid is shown as the density,
htthe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0The initial liquid pad height of the liquid level in the shaft; rhooIs the crude oil density; rhowTo the water density；
And (3) obtaining the rising speed of the liquid level by derivation of two sides of the formula (8) with time:
in specific implementation, the pumping cycle of the pumping well can be determined according to the elapsed time of the liquid level in the shaft of the pumping well from the initial liquid pad height to the highest height. For example, the time length required for the liquid level rising speed in the shaft to reach the average speed can be determined according to the elapsed time length for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height; and determining the time length required by the liquid level rising speed in the shaft to reach the average speed as the pumping period of the pumping well.
For example, the length of time required for the liquid level rise rate in the wellbore to reach an average rate may be determined as follows:
wherein, t0The time required for the liquid level rising speed in the shaft to reach the average speed is obtained; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
For equation (9), when t is 0, the liquid level rising speed tends to be maximum:
when T is T, the liquid level rising speed tends to be minimum:
the average speed of liquid level rise is:
substituting the average speed of liquid level rise for an equation (9) to obtain the time length required by the liquid level rise speed in the shaft to reach the average speed:
because the rising speed of the liquid level in the shaft is changed in a descending rule, the time required for the speed to reach the average speed is taken as the optimal pumping period, so that the liquid level in the shaft is fully recovered, and the next drainage of the stratum is facilitated.
The equation (10) is the time length corresponding to the average speed of the liquid level rise in the shaft, so that the pumping period of the well can be determined as long as the time length of the shaft pressure of the well recovering to be close to the formation pressure is determined.
In an embodiment, the height of the oil level can be determined according to the following formula:
wherein h istThe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0Is the initial fluid pad height of the fluid level in the wellbore.
Namely, the formula (10) is replaced into the formula (8), and the height of the oil fishing liquid level can be obtained
Therefore, the pumping period of the pumping well can be simply calculated by using the time length T when the pressure in the known well bore rises to be close to the formation pressure. And calculating the liquid level height of the well during pumping by using the liquid level rise value in the time length T.
FIG. 3 is an example diagram of a water-drive thin oil reservoir oil-water two-phase pumping well, and FIG. 3 shows the height h of the liquid level in the well shaft of the pumping well from the initial liquid pad0Return to maximum height hTRespectively corresponding first pressure P0Second, secondPressure PT(ii) a Flow pressure P at time t in liquid level recovery processwftHeight h of liquid level in shafttAnd the total height H of the pumpingwell.
As described above, in an embodiment, the pumping cycle of a pumped well may be determined as follows:
(1) testing the pressure change in the pumping well, wherein the initial pressure is P0End point pressure of PTWhen P isTThe difference between the pressure value of the point and the pressure value of the next point is less than or equal to 0.01MPa/d, namely the pressure of the point is considered to be PTThe elapsed time is T;
(2) by using
Calculating the pumping period of the pumping well;
(3) after the pumping is finished, the formula in the step (2) is used for calculating again to perform the next pumping.
(4) The liquid level during pumping is
The embodiment of the invention also provides a device for determining the pumping cycle of the oil-water two-phase pumping well of the water-drive thin oil reservoir, which is described in the following embodiment. Because the principle of the device for solving the problems is similar to the method for determining the pumping cycle of the oil-water two-phase pumping well of the water-drive thin oil reservoir, the implementation of the device can refer to the implementation of the method for determining the pumping cycle of the oil-water two-phase pumping well of the water-drive thin oil reservoir, and repeated parts are not repeated.
Fig. 4 is a schematic diagram of an apparatus for determining a pumping cycle of an oil-water two-phase pumping well in a water-drive lean oil reservoir according to an embodiment of the present invention, as shown in fig. 4, the apparatus may include:
the elapsed time determination module 401 is configured to determine an elapsed time for which the liquid level in the pumping well shaft is restored from the initial liquid pad height to the highest height;
a pumping cycle determining module 402, configured to determine a pumping cycle of the pumping well according to the elapsed time length.
As shown in fig. 5, the pumping cycle determining module 402 in fig. 4 may include:
the test parameter determining unit 501 is configured to determine a fluid volume of a fluid level in a shaft of the pumping well, which is recovered from an initial fluid pad height to a highest height, a first pressure corresponding to the fluid level in the shaft at the initial fluid pad height, and a second pressure corresponding to the fluid level in the shaft at the highest height;
a daily output determination unit 502, configured to determine a daily output of the fluid in the pumped well according to the elapsed time length and the fluid volume;
a liquid production index determining unit 503, configured to determine a liquid production index of the pumping well according to the daily yield of the downhole fluid, the first pressure, and the second pressure;
a wellbore storage constant determination unit 504, configured to determine a wellbore storage constant of the pumping well according to the fluid volume, the first pressure, and the second pressure;
a liquid level rising speed determining unit 505, configured to determine a speed at which a liquid level in the wellbore rises according to the liquid production index and a wellbore storage constant;
a pumping period determining unit 506, configured to determine a pumping period of the pumping well according to a rising speed of the liquid level in the wellbore.
In an embodiment, the test parameter determining unit 501 may specifically be configured to:
determining the volume of crude oil and the volume of water, wherein the liquid level in a shaft of the pumping well is recovered to the highest height from the initial liquid pad height;
and determining the fluid volume according to the crude oil volume and the water volume, the crude oil volume coefficient and the water volume coefficient.
In one embodiment, the fluid production index determining unit 503 may be specifically configured to:
determining the liquid production index of the pumping well according to the following formula:
wherein J is the liquid production index of the pumping well; vDownhole daily productionIs the daily production of downhole fluid; pTA second pressure; p0A first pressure; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height for the liquid level in the shaft of the pumping well; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
In one embodiment, the wellbore reservoir constant determination unit 504 may be specifically configured to:
determining a pumping well shaft reservoir constant according to the following formula:
wherein C is a well shaft storage constant of the pumping well; vDownhole productionIs the downhole fluid production; pTA second pressure; pOA first pressure; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well.
In one embodiment, the liquid level rising speed determination unit 505 may specifically be configured to:
and determining the rising speed of the liquid level in the shaft according to the liquid production index, the shaft storage constant and the second pressure and the flow pressure in the liquid level recovery process in the shaft of the pumping well.
In one embodiment, the pumping cycle determination module 402 may be specifically configured to:
determining the time length required for the liquid level rising speed in the shaft to reach the average speed according to the elapsed time length;
and determining the time length required by the liquid level rising speed in the shaft to reach the average speed as the pumping period of the pumping well.
In one embodiment, the pumping cycle determination module 402 may be specifically configured to:
determining the time length required for the liquid level rising speed in the shaft to reach the average speed according to the following formula:
wherein, t0The time required for the liquid level rising speed in the shaft to reach the average speed is obtained; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
As shown in fig. 6, in an embodiment, the apparatus for determining a pumping cycle of an oil-water two-phase pumping well of the water-flooding thin-oil reservoir shown in fig. 4 may further include:
the oil bailing liquid level determining module 601 is configured to determine the height of the oil bailing liquid level according to the following formula:
wherein h istThe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0Is the initial fluid pad height of the fluid level in the wellbore. The oil-bailing liquid level determining module 601 may also be included in the device for determining the pumping cycle of the oil-water two-phase pumping well of the water-drive thin oil reservoir shown in fig. 5.
The embodiment of the invention also provides computer equipment which comprises a memory, a processor and a computer program which is stored on the memory and can be operated on the processor, wherein the processor executes the computer program to realize the method for determining the pumping cycle of the water-drive thin oil reservoir oil-water two-phase pumping well.
The embodiment of the invention also provides a computer readable storage medium, which stores a computer program for executing the method for determining the oil-water two-phase pumping well pumping cycle of the water-drive thin oil reservoir.
In summary, in the embodiments of the present invention, the elapsed time for the liquid level in the well bore of the pumping well to return from the initial liquid pad height to the highest height is determined; and determining the pumping period of the pumping well according to the elapsed time, thereby simply and conveniently determining the reasonable pumping period, fully recovering the liquid level in the shaft and facilitating the next drainage of the stratum.
As will be appreciated by one skilled in the art, embodiments of the present invention may be provided as a method, system, or computer program product. Accordingly, the present invention may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present invention may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The above-mentioned embodiments are intended to illustrate the objects, technical solutions and advantages of the present invention in further detail, and it should be understood that the above-mentioned embodiments are only exemplary embodiments of the present invention, and are not intended to limit the scope of the present invention, and any modifications, equivalent substitutions, improvements and the like made within the spirit and principle of the present invention should be included in the scope of the present invention.
Claims (19)
1. A method for determining a pumping cycle of an oil-water two-phase pumping well of a water-drive thin oil reservoir is characterized by comprising the following steps:
determining the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height;
and determining the pumping period of the pumping well according to the elapsed time.
2. The method of claim 1, wherein determining a pumping well pumping cycle based on the elapsed time period comprises:
determining the volume of fluid of the liquid level in the shaft of the pumping well, which is recovered to the highest height from the initial liquid pad height, the first pressure of the liquid level in the shaft corresponding to the initial liquid pad height, and the second pressure of the liquid level in the shaft corresponding to the highest height;
determining the daily yield of the fluid in the pumping well according to the elapsed time and the volume of the fluid;
determining a liquid production index of the pumping well according to the daily production of the underground fluid, the first pressure and the second pressure;
determining a well bore storage constant of the pumping well according to the fluid volume, the first pressure and the second pressure;
determining the rising speed of the liquid level in the shaft according to the liquid production index and the shaft storage constant;
and determining the pumping period of the pumping well according to the rising speed of the liquid level in the shaft.
3. The method of claim 2, wherein determining the volume of fluid in the dip well bore from the initial pad height to the maximum height comprises:
determining the volume of crude oil and the volume of water, wherein the liquid level in a shaft of the pumping well is recovered to the highest height from the initial liquid pad height;
and determining the fluid volume according to the crude oil volume and the water volume, the crude oil volume coefficient and the water volume coefficient.
4. The method of claim 3, wherein determining the pumped well fluid production index based on the daily production of fluid downhole, the first pressure, and the second pressure comprises:
determining the liquid production index of the pumping well according to the following formula:
wherein J is the liquid production index of the pumping well; vDownhole daily productionIs the daily production of downhole fluid; pTA second pressure; p0A first pressure; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height for the liquid level in the shaft of the pumping well; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
5. The method of claim 3, wherein determining a dip-well wellbore reservoir constant based on the fluid volume, the first pressure, and the second pressure comprises:
determining a pumping well shaft reservoir constant according to the following formula:
wherein C is a well shaft storage constant of the pumping well; vDownhole productionIs the downhole fluid production; pTA second pressure; pOA first pressure; b isOIs the volume coefficient of crude oil; vOThe volume of crude oil is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well; b isWIs the water volume coefficient; vWThe volume of water is recovered from the initial liquid pad height to the highest height of the liquid level in the shaft of the pumping well.
6. The method of claim 2, wherein determining a rate of fluid level rise in the wellbore based on the fluid production index and a wellbore reservoir constant comprises:
and determining the rising speed of the liquid level in the shaft according to the liquid production index, the shaft storage constant and the second pressure and the flow pressure in the liquid level recovery process in the shaft of the pumping well.
7. The method of claim 6, wherein determining a rate of fluid level rise in the wellbore based on the fluid production index and wellbore reservoir constant, the second pressure, and a fluid pressure during fluid level recovery in the dip well wellbore comprises:
determining the rate of rise of the fluid level in the wellbore according to the following equation:
wherein, VDownhole production tDownhole fluid production at time t; j is the liquid production index of the pumping well; pTA second pressure; pwftThe flow pressure at the time t in the process of recovering the liquid level in the shaft of the pumping well; c is a well shaft storage constant of the pumping well;
the rising speed of the liquid level in the shaft is as follows:
wherein h istThe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0Is the initial fluid pad height of the fluid level in the wellbore.
8. The method of any one of claims 1 to 7, wherein determining a pumping well pumping cycle based on the elapsed time period comprises:
determining the time length required for the liquid level rising speed in the shaft to reach the average speed according to the elapsed time length;
and determining the time length required by the liquid level rising speed in the shaft to reach the average speed as the pumping period of the pumping well.
9. The method of claim 8, wherein determining a length of time required for a rate of fluid level rise in the wellbore to reach an average rate based on the length of elapsed time comprises:
determining the time length required for the liquid level rising speed in the shaft to reach the average speed according to the following formula:
wherein, t0The time required for the liquid level rising speed in the shaft to reach the average speed is obtained; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
10. The method of claim 8, further comprising:
the height of the oil level is determined according to the following formula:
wherein h istThe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0For initial liquid cushion of liquid level in wellHeight.
11. A device for determining a pumping cycle of an oil-water two-phase pumping well of a water-drive thin oil reservoir is characterized by comprising:
the passage duration determining module is used for determining the passage duration of the liquid level in the shaft of the pumping well, which is recovered from the initial liquid pad height to the highest height;
and the pumping cycle determining module is used for determining the pumping cycle of the pumping well according to the elapsed time length.
12. The apparatus of claim 11, wherein the pumping cycle determination module comprises:
the test parameter determining unit is used for determining the volume of fluid, the liquid level of the pumping well shaft is recovered to the highest height from the initial liquid pad height, the first pressure of the liquid level of the well shaft is corresponding to the initial liquid pad height, and the second pressure of the liquid level of the well shaft is recovered to the highest height;
the daily output determining unit is used for determining the daily output of the fluid in the pumping well according to the elapsed time and the fluid volume;
the liquid production index determining unit is used for determining a liquid production index of the pumping well according to the daily yield of the underground fluid, the first pressure and the second pressure;
the shaft storage constant determining unit is used for determining a shaft storage constant of the pumping well according to the fluid volume, the first pressure and the second pressure;
the liquid level rising speed determining unit is used for determining the rising speed of the liquid level in the shaft according to the liquid production index and the shaft storage constant;
and the pumping period determining unit is used for determining the pumping period of the pumping well according to the rising speed of the liquid level in the shaft.
13. The apparatus of claim 12, wherein the test parameter determination unit is specifically configured to:
determining the volume of crude oil and the volume of water, wherein the liquid level in a shaft of the pumping well is recovered to the highest height from the initial liquid pad height;
and determining the fluid volume according to the crude oil volume and the water volume, the crude oil volume coefficient and the water volume coefficient.
14. The apparatus according to claim 12, wherein the liquid level rise rate determining unit is specifically configured to:
and determining the rising speed of the liquid level in the shaft according to the liquid production index, the shaft storage constant and the second pressure and the flow pressure in the liquid level recovery process in the shaft of the pumping well.
15. The apparatus according to any of claims 11 to 14, wherein the pumping cycle determination module is specifically configured to:
determining the time length required for the liquid level rising speed in the shaft to reach the average speed according to the elapsed time length;
and determining the time length required by the liquid level rising speed in the shaft to reach the average speed as the pumping period of the pumping well.
16. The apparatus as claimed in claim 15, wherein the pumping cycle determination module is specifically configured to:
determining the time length required for the liquid level rising speed in the shaft to reach the average speed according to the following formula:
wherein, t0The time required for the liquid level rising speed in the shaft to reach the average speed is obtained; and T is the time duration for the liquid level in the shaft of the pumping well to recover from the initial liquid pad height to the highest height.
17. The apparatus of claim 15, further comprising:
the oil fishing liquid level determining module is used for determining the height of the oil fishing liquid level according to the following formula:
wherein h istThe height of the liquid level in the shaft at the moment t; h isTThe highest height of the liquid level in the shaft; h is0Is the initial fluid pad height of the fluid level in the wellbore.
18. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, wherein the processor implements the method of any one of claims 1 to 10 when executing the computer program.
19. A computer-readable storage medium, characterized in that the computer-readable storage medium stores a computer program for executing the method of any one of claims 1 to 10.
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