CN110005402B - Method and device for calculating production pressure difference of carbonate oil well - Google Patents
Method and device for calculating production pressure difference of carbonate oil well Download PDFInfo
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- 238000004519 manufacturing process Methods 0.000 title claims abstract description 149
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 53
- 239000003129 oil well Substances 0.000 title claims abstract description 51
- 238000000034 method Methods 0.000 title claims abstract description 42
- 238000002347 injection Methods 0.000 claims abstract description 345
- 239000007924 injection Substances 0.000 claims abstract description 345
- 239000012530 fluid Substances 0.000 claims abstract description 93
- 230000001186 cumulative effect Effects 0.000 claims abstract description 61
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 31
- 238000005259 measurement Methods 0.000 claims description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 14
- 239000011435 rock Substances 0.000 description 12
- 230000000694 effects Effects 0.000 description 11
- 239000003921 oil Substances 0.000 description 11
- 239000007789 gas Substances 0.000 description 8
- 239000000243 solution Substances 0.000 description 7
- 238000010586 diagram Methods 0.000 description 5
- 238000012360 testing method Methods 0.000 description 5
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 description 2
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 description 2
- 238000007664 blowing Methods 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 239000010779 crude oil Substances 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 2
- 238000002791 soaking Methods 0.000 description 2
- 239000002349 well water Substances 0.000 description 2
- 238000009825 accumulation Methods 0.000 description 1
- 239000001569 carbon dioxide Substances 0.000 description 1
- 229910002092 carbon dioxide Inorganic materials 0.000 description 1
- 230000006835 compression Effects 0.000 description 1
- 230000008602 contraction Effects 0.000 description 1
- -1 e.g. Substances 0.000 description 1
- 239000011261 inert gas Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229910052757 nitrogen Inorganic materials 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 230000002441 reversible effect Effects 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
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- Mining & Mineral Resources (AREA)
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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
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Abstract
The embodiment of the invention provides a method and a device for calculating the production pressure difference of a carbonate oil well, wherein the method comprises the following steps: measuring the wellhead pressure before injecting the fluid; measuring a cumulative injection amount of a fluid and a first injection pressure corresponding to the cumulative injection amount when the fluid is injected into a carbonate well; the first injection pressure is an injection pressure after the cumulative injection amount of the fluid is injected; calculating a production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is a difference between a formation pressure and a bottom hole flow pressure. The embodiment of the invention can reduce the cost of calculating the production pressure difference.
Description
Technical Field
The embodiment of the invention relates to the technical field of oil field oil extraction engineering, in particular to a method and a device for calculating the production pressure difference of a carbonate oil well.
Background
The carbonate rock oil well can realize single-well water injection oil replacement, can carry out self-blowing production when the oil well energy is sufficient, and can carry out soaking and crude oil replacement production in modes such as water injection or gas injection when the oil well energy is insufficient.
Currently, it is common to determine whether water or gas injection into the well is required based on the production pressure differential. Because the near-well area is not obviously degassed when the formation pressure is greater than the saturation pressure, and the reservoir layer is not irreversibly plastically deformed when the average formation pressure level is higher, the reasonable production pressure difference should be lower than the critical production pressure difference, within the pressure difference range, the oil well yield is stable, and a certain oil extraction speed can be realized. Therefore, how to calculate the production pressure difference quickly and accurately is very important. In the prior art, the differential production pressure is typically calculated by subtracting the measured bottom hole flow pressure from the measured formation pressure.
However, the above method for calculating the differential production pressure needs to measure the formation pressure and the bottom-hole flowing pressure, and the bottom-hole flowing pressure needs to be monitored downhole, so that a large amount of manpower and material resources are required, and the cost for calculating the differential production pressure is high.
Disclosure of Invention
The embodiment of the invention provides a method and a device for calculating the production pressure difference of a carbonate oil well, which can reduce the cost for calculating the production pressure difference.
In a first aspect, an embodiment of the present invention provides a method for calculating a production pressure difference of a carbonate oil well, including:
measuring the wellhead pressure before injecting the fluid;
measuring a cumulative injection amount of a fluid and a first injection pressure corresponding to the cumulative injection amount when the fluid is injected into a carbonate well; the first injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
calculating a production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is a difference between a formation pressure and a bottom hole flow pressure.
Optionally, said calculating a differential production pressure from said wellhead pressure, said cumulative injection quantity, and said first injection pressure comprises:
determining whether the cumulative injection amount and the first injection pressure are in a linear relationship;
if the accumulated injection amount and the first injection pressure are in a linear relation, determining a second injection pressure when the stratum is injected with the fluid according to the accumulated injection amount and the first injection pressure;
calculating the production differential pressure from the second injection pressure and the wellhead pressure.
Optionally, said calculating said differential production pressure from said second injection pressure and said wellhead pressure comprises:
according to the formula Δ P ═ P (P)1-P2) -2, calculating said production pressure difference;
wherein Δ P is the production pressure difference, P1Is the second injection pressure, P2Is the wellhead pressure.
Optionally, the determining whether the cumulative injection amount and the first injection pressure have a linear relationship includes:
drawing an injection curve according to the accumulated injection amount and the first injection pressure;
and judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not according to the injection curve.
Optionally, said determining a second injection pressure at which the formation is injected with fluid based on said cumulative injection amount and said first injection pressure comprises:
calculating an intercept of the injection curve based on the cumulative injection quantity and the first injection pressure;
determining the intercept as the second injection pressure.
In a second aspect, an embodiment of the present invention provides a device for calculating a production pressure difference of a carbonate well, including:
the measuring module is used for measuring the wellhead pressure before the fluid is injected;
the measurement module is further used for measuring the accumulated injection amount of the fluid and a first injection pressure corresponding to the accumulated injection amount when the fluid is injected into the carbonate oil well; the first injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
the calculation module is used for calculating the production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is a difference between a formation pressure and a bottom hole flow pressure.
Optionally, the calculation module includes:
a judgment submodule for judging whether the cumulative injection amount and the first injection pressure are in a linear relationship;
the determining submodule is used for determining a second injection pressure when the stratum is injected with the fluid according to the accumulated injection quantity and the first injection pressure when the accumulated injection quantity and the first injection pressure are in a linear relation;
and the calculation submodule is used for calculating the production pressure difference according to the second injection pressure and the wellhead pressure.
Optionally, the calculation submodule is specifically configured to:
according to the formula Δ P ═ P (P)1-P2) -2, calculating said production pressure difference;
wherein Δ P is the production pressure difference, P1Is the second injection pressure, P2Is the wellhead pressure.
Optionally, the determining sub-module is specifically configured to:
drawing an injection curve according to the accumulated injection amount and the first injection pressure;
and judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not according to the injection curve.
Optionally, the determining submodule is specifically configured to:
calculating an intercept of the injection curve from the cumulative injection quantity and the first injection pressure;
determining the intercept as the second injection pressure.
According to the method and the device for calculating the production pressure difference of the carbonate rock oil well, the wellhead pressure before fluid injection is measured, when the fluid is injected into the carbonate rock oil well, the accumulated injection amount of the fluid and the first injection pressure corresponding to the accumulated injection amount are measured, the first injection pressure is the injection pressure after the fluid with the accumulated injection amount is injected, and the production pressure difference is calculated according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure. Because only need test well head pressure, the accumulative injection volume of injected fluid and first injection pressure, can calculate the production pressure differential fast, avoided needing the phenomenon of going into the well and measuring the bottom hole flowing pressure among the prior art, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential in addition.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, and it is obvious that the drawings in the following description are some embodiments of the present invention, and for those skilled in the art, other drawings can be obtained according to these drawings without creative efforts.
FIG. 1 is a schematic flow chart of a first embodiment of a method for calculating a carbonate oil well production pressure difference according to an embodiment of the present invention;
FIG. 2 is a schematic flow chart of a second embodiment of a method for calculating a production pressure difference of a carbonate well according to an embodiment of the present invention;
FIG. 3 is a schematic illustration of an injection curve plotted against a cumulative injection quantity and a first injection pressure;
FIG. 4 is a schematic structural diagram of a first embodiment of a device for calculating a production pressure difference of a carbonate well according to an embodiment of the present invention;
fig. 5 is a schematic structural diagram of a second calculation apparatus for a carbonate well production pressure difference 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 clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all, embodiments of the present invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
Before describing the embodiments of the present invention, some basic concepts will be explained:
(1) well reserve effect
The well reservoir effect refers to the change in well flow rate (bottom hole pressure) caused by the release or accumulation of elastic energy due to changes in wellbore pressure from the fluids (oil, gas) in the wellbore system. Before the oil well is opened and produced, the well bore is sealed, and the fluid in the well bore is in a high-pressure elastic contraction state. Once the well is opened for production, the fluids in the wellbore release elastic energy. Thus, the production first obtained by the wellhead does not come from the formation, but from the elastic expansion of the fluids in the upper part of the wellbore.
(2) Afterflow effect
After the surface of the well is shut in, the flow of oil from the formation into the wellbore continues, a phenomenon known as afterflow.
(3) Differential pressure of production
For water injection wells, the production differential pressure refers to the pressure value obtained by subtracting the formation pressure from the bottom hole flowing pressure, and for oil wells, the production differential pressure refers to the pressure value obtained by subtracting the bottom hole flowing pressure from the formation pressure.
The method for calculating the production pressure difference of the carbonate oil well, provided by the embodiment of the invention, is applied to the carbonate oil well. The carbonate rock oil well can realize single-well water injection oil replacement, can carry out self-blowing production when the oil well energy is sufficient, and can carry out soaking and crude oil replacement production in modes such as water injection or gas injection when the oil well energy is insufficient. At present, whether water or gas needs to be injected into an oil well is generally determined according to the production pressure difference, so how to quickly and accurately calculate the production pressure difference is very important for improving the oil production speed and realizing stable oil well yield. In the prior art, differential production pressure is typically calculated in two ways, one of which is based on the measured formation pressure minus the measured bottom hole flow pressure. The other method is to calculate the production pressure difference according to the oil well productivity formula Q ═ J ·ΔP, wherein Q is the oil well yield, J is the liquid (oil) production index, and Δ P is the production pressure difference. However, when the production pressure difference is calculated by the former method, the formation pressure and the bottom hole flowing pressure need to be measured, and the bottom hole flowing pressure needs to be monitored downhole, so that a large amount of manpower and material resources need to be consumed, and the cost for calculating the production pressure difference is high.
Therefore, the method for calculating the production pressure difference of the carbonate oil well provided by the embodiment of the invention aims to solve the technical problems of high cost and low calculation efficiency in the process of calculating the production pressure difference in the prior art.
In view of these circumstances, embodiments of the present invention provide a method for calculating a production pressure difference of a carbonate oil well, in which a wellhead pressure before injecting a fluid is measured, when the fluid is injected into the carbonate oil well, an accumulated injection amount of the fluid and a first injection pressure corresponding to the accumulated injection amount are measured, the first injection pressure being an injection pressure after the fluid of the accumulated injection amount is injected, and the production pressure difference is calculated based on the wellhead pressure, the accumulated injection amount, and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure. Because only need test well head pressure, the accumulative injection volume of injected fluid and first injection pressure, can calculate the production pressure differential fast, avoided needing the phenomenon of going into the well and measuring the bottom hole flowing pressure among the prior art, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential in addition.
The technical solution of the present invention will be described in detail below with specific examples. The following several specific embodiments may be combined with each other, and details of the same or similar concepts or processes may not be repeated in some embodiments.
Fig. 1 is a schematic flow chart of a first embodiment of a method for calculating a production pressure difference of a carbonate oil well according to an embodiment of the present invention. The embodiment of the invention provides a method for calculating the production pressure difference of a carbonate rock oil well, which can be executed by any device for executing the method for calculating the production pressure difference of the carbonate rock oil well, and the device can be realized by software and/or hardware. As shown in fig. 1, the method of this embodiment may include:
When the differential production pressure is greater than the critical differential production pressure, it is necessary to inject a fluid into the carbonate well to reduce the differential production pressure. In the embodiment, when calculating the production pressure difference, the calculating device for the carbonate oil well production pressure difference first needs to measure the wellhead pressure before injecting the fluid, and in a possible implementation manner, the wellhead pressure may be measured by a pressure sensor, for example, by an oil pressure gauge.
The fluid may be, for example, water or gas, such as an inert gas, e.g., natural gas, nitrogen, carbon dioxide, etc., but may be any other fluid capable of varying the pressure difference of production.
In an embodiment of the invention, after measuring the wellhead pressure before injecting the fluid, when injecting the fluid into the carbonate well, the cumulative injection amount of the fluid, which is the total amount of fluid injected from the beginning of injecting the fluid to the time of measurement, and the first injection pressure after injecting the fluid of the cumulative injection amount are measured. In a possible implementation manner, the cumulative injection amount of the fluid may be measured by a flow sensor, for example, a flow meter, the first injection pressure may be measured by a pressure sensor, for example, an oil pressure gauge, etc., of course, the cumulative injection amount may also be measured by another flow sensor, and the first injection pressure may be measured by another pressure sensor, and the specific form of the flow sensor and the pressure sensor is not particularly limited by the embodiment of the present invention.
103, calculating a production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure.
In an embodiment of the invention, after the wellhead pressure, the cumulative injection amount and the first injection pressure are measured, the production differential pressure can be calculated according to the wellhead pressure, the cumulative injection amount and the first injection pressure. Thus, the operator will be able to determine from the calculated production pressure differential whether or not it is necessary to inject fluid into the carbonate well to ensure the rate of production.
According to the method for calculating the production pressure difference of the carbonate rock oil well, the wellhead pressure before fluid injection is measured, when the fluid is injected into the carbonate rock oil well, the accumulated injection amount of the fluid and the first injection pressure corresponding to the accumulated injection amount are measured, the first injection pressure is the injection pressure after the fluid with the accumulated injection amount is injected, and the production pressure difference is calculated according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure. Because only need test well head pressure, the accumulative injection volume of injected fluid and first injection pressure, can calculate the production pressure differential fast, avoided needing the phenomenon of going into the well and measuring the bottom hole flowing pressure among the prior art, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential in addition.
Fig. 2 is a schematic flow chart of a second embodiment of the method for calculating the production pressure difference of the carbonate oil well according to the embodiment of the present invention. Embodiment of the present invention an embodiment of calculating a differential production pressure based on a wellhead pressure, an accumulated injection amount, and a first injection pressure will be described in detail based on the embodiment shown in fig. 1. As shown in fig. 2, the method of this embodiment may include:
Step 201-step 202 are similar to step 101-step 102, and are not described herein again.
And step 203, judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not.
In the embodiment of the invention, since the compression process exists at the beginning of the injection during the process of injecting the fluid into the carbonate oil well, the relationship between the cumulative injection amount and the first injection pressure is nonlinear, and the relationship between the cumulative injection amount and the first injection pressure is linear after the fluid is injected for a period of time. In this embodiment, when determining the second injection pressure when the formation is injected with the fluid according to the accumulated injection amount and the first injection pressure, the calculation is performed on the premise that the accumulated injection amount and the first injection pressure have a linear relationship, and therefore, it is first necessary to determine whether the accumulated injection amount and the first injection pressure have a linear relationship during the injection of the fluid.
In one possible implementation, the determining whether the cumulative injection amount and the first injection pressure have a linear relationship includes: and drawing an injection curve according to the accumulated injection quantity and the first injection pressure, and judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not according to the injection curve.
Specifically, fig. 3 is a schematic diagram of an injection curve plotted according to the cumulative injection amount and the first injection pressure, and as shown in fig. 3, the calculation apparatus of the carbonate well production pressure difference may draw the injection curve according to the cumulative injection amount and the first injection pressure corresponding to the cumulative injection amount of each stage after measuring the values of the cumulative injection amount and the first injection pressure. It will be appreciated by those skilled in the art that after the injection curve is plotted, it will be possible to determine from the injection curve whether there is a linear relationship between the cumulative injection amount and the first injection pressure, for example: whether the slopes of any two points on the injection curve are equal or not can be judged, and if so, the linear relation between the accumulated injection amount and the corresponding first injection pressure is shown.
In addition, as shown in fig. 3, the cumulative injection amount and the first injection pressure exhibit a non-linear relationship in the compression stage, and the cumulative injection amount and the first injection pressure exhibit a linear relationship after the fluid is injected for a certain period of time.
And step 204, if the accumulated injection amount and the first injection pressure are in a linear relation, determining a second injection pressure when the formation is injected with the fluid according to the accumulated injection amount and the first injection pressure.
In the embodiment of the invention, when the linear relation between the accumulated injection amount and the first injection pressure is judged, the second injection pressure when the formation is injected with the fluid is determined according to the accumulated injection amount and the first injection pressure.
In one possible implementation, determining a second injection pressure at which the formation is injected with fluid based on the cumulative injection quantity and the first injection pressure comprises: an intercept of the injection curve is calculated based on the cumulative injection quantity and the first injection pressure, and the intercept is determined as a second injection pressure.
Specifically, after the injection curve is drawn, the intercept of the injection curve can be calculated according to the accumulated injection amount and the first injection pressure. For example: assuming that the injection curve is y ═ kx + b, where y is the first injection pressure, x is the cumulative injection amount, and k is the slope of the injection curve, those skilled in the art can understand that the intercept of the injection curve can be calculated by arbitrarily taking the cumulative injection amount at two time points and the corresponding first injection pressure according to the equation y ═ kx + b.
After calculating the intercept of the injection curve, the calculated intercept is determined as the second injection pressure.
And step 205, calculating the production pressure difference according to the second injection pressure and the wellhead pressure.
In the embodiment of the invention, the wellhead pressure is the wellhead pressure before the fluid is injected, and the calculation device of the production pressure difference of the carbonate oil well can calculate the production pressure difference according to the second injection pressure and the wellhead pressure after calculating the second injection pressure and measuring the wellhead pressure.
In one possible implementation, the differential production pressure is calculated from the second injection pressure and the wellhead pressure, including according to the formula Δ P ═ P (P)1-P2) Calculating a production pressure differential, wherein Δ P is the production pressure differential, P1At the second injection pressure, P2Is the wellhead pressure.
Specifically, the following description will be given by taking the injected fluid as water, and the process of injecting gas is similar to the process of injecting water, and will not be described herein again. And (3) assuming that water injection and production are reversible, namely the production pressure difference delta P during production is equal to the production pressure difference delta P during water injection, wherein the production pressure difference delta P during production is the stratum pressure minus the bottom flowing pressure, the production pressure difference delta P during water injection is the bottom flowing pressure minus the stratum pressure, and in addition, the well storage effect and the follow current effect are ignored.
In addition, because the afterflow effect is neglected, the time-of-well production is 0, i.e., the following relation is satisfied:
Q＝J*(P-△P–Pwf)＝0 (1)
wherein Q is the production output, P is the initial formation pressure, Δ P is the production differential pressure, PwfIs the current bottom hole flow pressure.
In addition, because the well-reservoir effect is neglected, the water amount of the stratum at the beginning of water injection is 0, namely the following relational expression is satisfied:
Qinjw＝J*(Pwf′-△P–P)＝0 (2)
wherein Q isinjwIs an injection quantity of a fluid, e.g. water or gas, Pwf' is the bottom hole flow pressure after fluid injection,. DELTA.P is the production differential pressure, and P is the initial formation pressure.
From the above (1) and (2), the following formula (3) can be obtained:
Pwf′-Pwf＝2△P (3)
in addition, due to Pwf′＝PH+P1，Pwf＝PH+P2Wherein P isHIs the liquid column pressure, therefore, it can be obtained according to the formula (3)To the following equation (4):
ΔP＝(P1-P2)/2 (4)
from the above, after the second injection pressure is calculated and the wellhead pressure is measured, the production differential pressure can be calculated according to the formula (4). When the production differential pressure is calculated by the method in the embodiment, the second injection pressure can be calculated according to the slope of the injection curve only by the accumulated injection amount of the fluid and the corresponding first injection pressure, and the production differential pressure is calculated rapidly, so that the phenomenon that the production differential pressure needs to be calculated by monitoring the bottom hole flow pressure through the well can be avoided, the cost of calculating the production differential pressure can be reduced, and the efficiency of calculating the production differential pressure can be improved.
According to the method for calculating the production pressure difference of the carbonate rock oil well, the wellhead pressure before fluid injection is measured, when the fluid is injected into the carbonate rock oil well, the accumulated injection amount of the fluid and the first injection pressure corresponding to the accumulated injection amount are measured, the first injection pressure is the injection pressure after the fluid with the accumulated injection amount is injected, and the production pressure difference is calculated according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure. Because only need test well head pressure, the accumulative injection volume of injected fluid and first injection pressure, can calculate the production pressure differential fast, avoided needing the phenomenon of going into the well and measuring the bottom hole flowing pressure among the prior art, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential in addition. In addition, after the injection curve is drawn according to the accumulated injection amount and the first injection pressure, the second injection pressure may be determined by calculating an intercept of the injection curve, whereby the calculation of the second injection pressure may be made easier.
Fig. 4 is a schematic structural diagram of a first embodiment of a device for calculating a production pressure difference of a carbonate oil well according to an embodiment of the present invention, as shown in fig. 4, the device includes: a measurement module 11 and a calculation module 12.
The measuring module 11 is used for measuring the wellhead pressure before injecting the fluid;
the measurement module 11 is further configured to measure a cumulative injection amount of the fluid and a first injection pressure corresponding to the cumulative injection amount when injecting the fluid into the carbonate well; the first injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
the calculation module 12 is used for calculating a production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is a difference between a formation pressure and a bottom hole flow pressure.
In the device for calculating the production pressure difference of the carbonate rock oil well, provided in this embodiment, the measurement module 11 measures the cumulative injection amount of the fluid and a first injection pressure corresponding to the cumulative injection amount when the fluid is injected into the carbonate rock oil well by measuring the wellhead pressure before the fluid is injected, where the first injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected, and the calculation module 12 calculates the production pressure difference according to the wellhead pressure, the cumulative injection amount, and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure. Because only need test well head pressure, the accumulative injection volume of injected fluid and first injection pressure, can calculate the production pressure differential fast, avoided needing the phenomenon of going into the well and measuring the bottom hole flowing pressure among the prior art, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential in addition.
Fig. 5 is a schematic structural diagram of a second embodiment of the device for calculating the pressure difference of the carbonate oil well according to the embodiment of the present invention, and on the basis of the embodiment shown in fig. 4, the calculation module 12 includes: a judgment sub-module 121, a determination sub-module 122 and a calculation sub-module 123.
The judgment submodule 121 is configured to judge whether the cumulative injection amount and the first injection pressure are in a linear relationship;
the determination submodule 122 is configured to determine a second injection pressure at which the formation is injected with fluid based on the cumulative injection amount and the first injection pressure when the cumulative injection amount and the first injection pressure have a linear relationship therebetween;
the calculation submodule 123 is configured to calculate the production pressure difference based on the second injection pressure and the wellhead pressure.
The device for calculating the production pressure difference of the carbonate oil well provided in the embodiment can be used for executing the technical scheme of any one of the method embodiments, and the implementation principle and the technical effect of the device are similar to those of the method embodiments and are not repeated herein.
Optionally, the calculating submodule 123 is specifically configured to:
according to the formula Δ P ═ P (P)1-P2) -2, calculating said production pressure difference;
wherein Δ P is the production pressure difference, P1Is the second injection pressure, P2Is the wellhead pressure.
The device for calculating the production pressure difference of the carbonate oil well provided in the embodiment can be used for executing the technical scheme of any one of the method embodiments, and the implementation principle and the technical effect of the device are similar to those of the method embodiments and are not repeated herein.
Optionally, the determining sub-module 121 is specifically configured to:
drawing an injection curve according to the accumulated injection amount and the first injection pressure;
and judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not according to the injection curve.
The device for calculating the production pressure difference of the carbonate oil well provided in the embodiment can be used for executing the technical scheme of any one of the method embodiments, and the implementation principle and the technical effect of the device are similar to those of the method embodiments and are not repeated herein.
Optionally, the determining sub-module 122 is specifically configured to:
calculating an intercept of the injection curve from the cumulative injection quantity and the first injection pressure;
determining the intercept as the second injection pressure.
The device for calculating the production pressure difference of the carbonate oil well provided in the embodiment can be used for executing the technical scheme of any one of the method embodiments, and the implementation principle and the technical effect of the device are similar to those of the method embodiments and are not repeated herein.
Those of ordinary skill in the art will understand that: all or a portion of the steps of implementing the above-described method embodiments may be performed by hardware associated with program instructions. The program may be stored in a computer-readable storage medium. When executed, the program performs steps comprising the method embodiments described above; and the aforementioned storage medium includes: various media that can store program codes, such as ROM, RAM, magnetic or optical disks.
Finally, it should be noted that: the above embodiments are only used to illustrate the technical solution of the present invention, and not to limit the same; while the invention has been described in detail and with reference to the foregoing embodiments, it will be understood by those skilled in the art that: the technical solutions described in the foregoing embodiments may still be modified, or some or all of the technical features may be equivalently replaced; and these modifications or substitutions do not depart from the spirit of the corresponding technical solutions of the embodiments of the present invention.
Claims (4)
1. A method for calculating the production pressure difference of a carbonate oil well is characterized by comprising the following steps:
measuring the wellhead pressure before injecting the fluid;
measuring a cumulative injection amount of a fluid and a first injection pressure corresponding to the cumulative injection amount when the fluid is injected into a carbonate well; the first injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
calculating a production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure;
calculating a differential production pressure based on the wellhead pressure, the cumulative injection volume, and the first injection pressure, comprising:
determining whether the cumulative injection amount and the first injection pressure are in a linear relationship;
if the accumulated injection amount and the first injection pressure are in a linear relation, determining a second injection pressure when the stratum is injected with the fluid according to the accumulated injection amount and the first injection pressure;
calculating the production differential pressure from the second injection pressure and the wellhead pressure;
determining a second injection pressure at which the formation is injected with fluid based on the cumulative injection amount and the first injection pressure, comprising:
calculating an intercept of the injection curve from the cumulative injection quantity and the first injection pressure;
determining the intercept as the second injection pressure;
said calculating said production differential pressure from said second injection pressure and said wellhead pressure, comprising:
according to the formula Δ P ═ P (P)1-P2) -2, calculating said production pressure difference;
wherein Δ P is the production pressure difference, P1Is the second injection pressure, P2Is the wellhead pressure.
2. The method of claim 1, wherein said determining whether the cumulative injection amount and the first injection pressure are in a linear relationship comprises:
drawing an injection curve according to the accumulated injection amount and the first injection pressure;
and judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not according to the injection curve.
3. A device for calculating the differential pressure of carbonate oil well production, comprising:
the measuring module is used for measuring the wellhead pressure before the fluid is injected;
the measurement module is further used for measuring the accumulated injection amount of the fluid and a first injection pressure corresponding to the accumulated injection amount when the fluid is injected into the carbonate oil well; the first injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
the calculation module is used for calculating the production pressure difference according to the wellhead pressure, the accumulated injection amount and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure;
the calculation module comprises:
a judgment submodule for judging whether the cumulative injection amount and the first injection pressure are in a linear relationship;
the determining submodule is used for determining a second injection pressure when the stratum is injected with fluid according to the accumulated injection quantity and the first injection pressure when the accumulated injection quantity and the first injection pressure are in a linear relation;
a calculation submodule for calculating the production differential pressure from the second injection pressure and the wellhead pressure;
the determining submodule is specifically configured to:
calculating an intercept of the injection curve from the cumulative injection quantity and the first injection pressure;
determining the intercept as the second injection pressure;
the calculation submodule is specifically configured to:
according to the formula Δ P ═ P (P)1-P2) -2, calculating said production pressure difference;
wherein Δ P is the production pressure difference, P1Is the second injection pressure, P2Is the wellhead pressure.
4. The apparatus according to claim 3, wherein the determining submodule is specifically configured to:
drawing an injection curve according to the accumulated injection amount and the first injection pressure;
and judging whether the accumulated injection quantity and the first injection pressure are in a linear relation or not according to the injection curve.
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