CN109989744B - Method and device for calculating production pressure difference of multiple sets of reservoir bodies of carbonate rock - Google Patents
Method and device for calculating production pressure difference of multiple sets of reservoir bodies of carbonate rock Download PDFInfo
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- 238000004519 manufacturing process Methods 0.000 title claims abstract description 144
- 238000000034 method Methods 0.000 title claims abstract description 45
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 36
- 239000011435 rock Substances 0.000 title claims abstract description 29
- 238000002347 injection Methods 0.000 claims abstract description 270
- 239000007924 injection Substances 0.000 claims abstract description 270
- 239000012530 fluid Substances 0.000 claims abstract description 113
- 239000003129 oil well Substances 0.000 claims abstract description 34
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 24
- 230000001186 cumulative effect Effects 0.000 claims description 49
- 238000005259 measurement Methods 0.000 claims description 7
- 239000000126 substance Substances 0.000 claims 2
- 239000003921 oil Substances 0.000 description 12
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 12
- 230000000694 effects Effects 0.000 description 11
- 238000010586 diagram Methods 0.000 description 8
- 239000007789 gas Substances 0.000 description 8
- 239000000243 solution Substances 0.000 description 7
- 238000012360 testing method Methods 0.000 description 5
- 239000007788 liquid Substances 0.000 description 3
- 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
- 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
- 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
- 239000011148 porous material Substances 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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- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (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 plurality of sets of reservoir bodies of carbonate rocks in an oil well, wherein the method comprises the following steps: measuring the wellhead pressure before injecting the fluid; determining a first injection pressure at which a first reservoir is filled with the fluid and injection of the fluid into a second reservoir is initiated; wherein the first reservoir is a previous reservoir of the second reservoir; calculating a production pressure difference according to the wellhead pressure 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 rock multi-set reservoir oil well.
Background
In a carbonate rock multi-set reservoir oil well, when the energy of the oil well is sufficient, the self-blowing production can be carried out, and when the energy of the oil well is insufficient, the soaking and the crude oil replacement production can be carried out by means of water injection, gas injection and the like.
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 plurality of sets of reservoir bodies of carbonate rocks in an 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 multiple-set reservoir oil well, including:
measuring the wellhead pressure before injecting the fluid;
determining a first injection pressure at which a first reservoir is filled with the fluid and injection of the fluid into a second reservoir is initiated; wherein the first reservoir is a previous reservoir of the second reservoir;
calculating a production pressure difference according to the wellhead pressure 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 and said first injection 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 first injection pressure, P2Is the wellhead pressure.
Optionally, determining a first injection pressure at which to fill the first reservoir with the fluid and begin injecting the fluid into the second reservoir comprises:
measuring a cumulative injection amount of a fluid and a second injection pressure corresponding to the cumulative injection amount, when the fluid is injected into each reservoir; the second injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
determining the first injection pressure based on the accumulated injection quantity and the second injection pressure.
Optionally, said determining said first injection pressure from said accumulated injection quantity and said second injection pressure comprises:
drawing an injection curve according to the accumulated injection amount and the second injection pressure;
determining a second injection pressure at an inflection point in the injection profile as the first injection pressure.
Optionally, before the measuring the cumulative injection amount of the fluid and the second injection pressure corresponding to the cumulative injection amount, the method further comprises:
and judging whether the accumulated injection amount and the second injection pressure are in a linear relation or not, wherein the judgment result is that the accumulated injection amount and the second injection pressure are in a linear relation.
In a second aspect, an embodiment of the present invention provides a device for calculating a production pressure difference of multiple sets of reservoir oil wells in carbonate rocks, including:
the measuring module is used for measuring the wellhead pressure before the fluid is injected;
a determination module for determining a first injection pressure at which to fill a first reservoir with the fluid and begin injecting the fluid into a second reservoir; wherein the first reservoir is a previous reservoir of the second reservoir;
the calculation module is used for calculating the production pressure difference according to the wellhead pressure 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 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 first injection pressure, P2Is the wellhead pressure.
Optionally, the determining module includes:
a measurement sub-module configured to measure a cumulative injection amount of a fluid and a second injection pressure corresponding to the cumulative injection amount when the fluid is injected into each reservoir; the second injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
a determination submodule for determining the first injection pressure based on the accumulated injection quantity and the second injection pressure.
Optionally, the determining submodule is specifically configured to:
drawing an injection curve according to the accumulated injection amount and the second injection pressure;
determining a second injection pressure at an inflection point in the injection profile as the first injection pressure.
Optionally, the apparatus further comprises:
and the judging module is used for judging whether the accumulated injection amount and the second injection pressure are in a linear relation or not, and the judging result is that the accumulated injection amount and the second injection pressure are in a linear relation.
According to the method and the device for calculating the oil well production pressure difference of the multiple sets of the carbonate rocks, the wellhead pressure before the fluid is injected is measured, the fluid is determined to be filled in the first reservoir body, and the first injection pressure when the fluid is injected into the second reservoir body is started; wherein the first reservoir is a previous stage reservoir of the second reservoir; then calculating the production pressure difference according to the wellhead pressure 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 and fill fluid in first reservoir, and the first injection pressure when beginning to pour into fluid into the second reservoir, can calculate the production pressure differential fast, avoided needing to go into the well among the prior art and measure the phenomenon of bottom of the well flowing pressure, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential moreover.
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 production pressure difference of a plurality of sets of reservoir bodies of carbonate rocks according to an embodiment of the invention;
FIG. 2 is a schematic illustration of the injection of fluids into various reservoirs;
FIG. 3 is a schematic flow chart of a second embodiment of a method for calculating a production pressure difference of a plurality of sets of reservoir bodies of carbonate rocks according to an embodiment of the invention;
FIG. 4 is a schematic illustration of an injection curve plotted against a cumulative injection quantity and a second injection pressure;
FIG. 5 is a schematic diagram of a first embodiment of a device for calculating the production pressure difference of multiple sets of carbonate reservoir wells according to the present invention;
FIG. 6 is a schematic structural diagram of a second embodiment of a device for calculating the production pressure difference of multiple sets of reservoir bodies of carbonate rocks according to an embodiment of the invention;
FIG. 7 is a schematic structural diagram of a third embodiment of a device for calculating the production pressure difference of multiple sets of carbonate wells according to the embodiment of the 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) reservoir body
The reservoir may act as a pore space for the storage of oil and gas, which is not distributed in layers, but rather constitutes a combination of irregularities within and between layers.
(2) Well reserve effect
The well reserve effect refers to the change in the well flow rate (bottom hole pressure) caused by the release or accumulation of elastic energy from the fluids (oil, gas) in the wellbore system due to changes in the wellbore pressure. 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 amount of elastic expansion of the fluids in the upper part of the wellbore.
(3) 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.
(4) 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 multiple carbonate-rock-set reservoir-body oil wells is applied to the multiple carbonate-rock-set reservoir-body oil wells. The carbonate rock multi-set reservoir body oil well can realize water injection oil replacement, can carry out self-blowing production when the oil well energy is sufficient, and can carry out soaking well replacement crude oil production through 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 multiple sets of the reservoir bodies of the carbonate rock oil well, provided by the embodiment of the invention, aims to solve the technical problems of high cost and low calculation efficiency when the production pressure difference is calculated in the prior art.
In view of these circumstances, embodiments of the present invention provide a method for calculating a well production differential pressure for multiple sets of reservoirs in carbonate rock by measuring a wellhead pressure before injecting a fluid, and determining a first injection pressure at which a first reservoir is filled with the fluid and a second reservoir is started to inject the fluid; wherein the first reservoir is a previous stage reservoir of the second reservoir; then calculating the production pressure difference according to the wellhead pressure 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 and fill fluid in first reservoir, and the first injection pressure when beginning to pour into fluid into the second reservoir, can calculate the production pressure differential fast, avoided needing to go into the well among the prior art and measure the phenomenon of bottom of the well flowing pressure, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential moreover.
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 plurality of carbonate reservoir oil wells according to an embodiment of the present invention. The embodiment of the invention provides a method for calculating the production differential pressure of multiple carbonate-rock-set reservoir oil wells, which can be executed by any device for executing the method for calculating the production differential pressure of multiple carbonate-rock-set reservoir oil wells, 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 production pressure differential is greater than the critical production pressure differential, it is necessary to inject fluids into the multiple sets of reservoir wells of carbonate rock to reduce the production pressure differential. In the embodiment, the calculating device for the production pressure difference of the multiple sets of reservoir bodies of carbonate rocks needs to measure the wellhead pressure before injecting the fluid when calculating the production pressure difference, and in a possible implementation mode, the wellhead pressure can be measured by a pressure sensor, for example, 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 the embodiment of the present invention, fig. 2 is a schematic diagram of injecting fluid into each reservoir, and as shown in fig. 2, when fluid is injected into each reservoir, the fluid is generally injected into a first reservoir through a wellbore, and after the first reservoir is filled with the fluid, the fluid is injected into a second reservoir through the first reservoir, wherein the first reservoir is a previous-stage reservoir of the second reservoir, i.e., the fluid is injected into a near-well reservoir, and after the filling, the fluid is injected into a far-well reservoir through the near-well reservoir.
After measuring the wellhead pressure before injecting the fluid, a first injection pressure at which the first reservoir is filled with fluid and injection of fluid into the second reservoir is initiated is determined. In a possible implementation manner, the first injection pressure may be measured by a pressure sensor, for example, by an oil pressure gauge, or the like, and of course, the first injection pressure may also be measured by another pressure sensor, and the specific form of 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 and the first injection pressure; wherein the production differential pressure is the difference between the formation pressure and the bottom hole flow pressure.
In embodiments of the present invention, after the wellhead pressure is measured and the first injection pressure is determined, the differential production pressure may be calculated from the wellhead pressure and the first injection pressure. In this way, the operator will be able to determine from the calculated production pressure difference whether or not fluid needs to be injected into the well to ensure the rate of production.
According to the method for calculating the oil well production differential pressure of the multiple sets of the carbonate rocks, which is provided by the embodiment of the invention, the wellhead pressure before the fluid is injected is measured, the fluid is determined to be filled in the first reservoir, and the first injection pressure when the fluid is injected into the second reservoir is started; wherein the first reservoir is a previous stage reservoir of the second reservoir; then calculating the production pressure difference according to the wellhead pressure 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 and fill fluid in first reservoir, and the first injection pressure when beginning to pour into fluid into the second reservoir, can calculate the production pressure differential fast, avoided needing to go into the well among the prior art and measure the phenomenon of bottom of the well flowing pressure, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential moreover.
FIG. 3 is a schematic flow chart of a second embodiment of a method for calculating a production pressure difference of a plurality of carbonate reservoir wells according to an embodiment of the present invention. Embodiments of the present invention will be described in detail with reference to the embodiment shown in fig. 1. As shown in fig. 3, the method of this embodiment may include:
Step 301 is similar to step 101 and will not be described herein.
In the present embodiment, at the time of injecting fluid into each reservoir, a cumulative injection amount of the injected fluid, which is a total amount of fluid injected from the start of injection of the fluid to the time of measurement, and a second injection pressure after the injection of 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, and the second injection pressure may be measured by a pressure sensor, for example, an oil pressure gauge, etc., and of course, the cumulative injection amount may also be measured by another flow sensor and the second injection pressure may also 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.
In one possible implementation, before measuring a cumulative injection quantity of the fluid and a second injection pressure corresponding to the cumulative injection quantity, the method further includes: and judging whether the accumulated injection amount and the second injection pressure are in a linear relation or not, and judging that the accumulated injection amount and the second injection pressure are in a linear relation.
Specifically, since the compression process occurs during the injection of fluid into the carbonate well at the beginning of the injection, the cumulative injection amount and the second injection pressure are in a non-linear relationship, and the cumulative injection amount and the second injection pressure are in a linear relationship after the injection of fluid for a while. In the present embodiment, when measuring the cumulative injection amount of the fluid and the second injection pressure corresponding to the cumulative injection amount, the measurement is performed on the premise that the cumulative injection amount and the second injection pressure exhibit a linear relationship, and therefore, it is first necessary to determine whether or not the cumulative injection amount and the second injection pressure exhibit a linear relationship during the process of injecting the fluid into each reservoir.
In one possible implementation, an injection curve may be plotted according to the accumulated injection quantity and the second injection pressure, and whether a linear relationship exists between the accumulated injection quantity and the second injection pressure is determined according to the injection curve.
Specifically, fig. 4 is a schematic diagram of an injection curve plotted according to the cumulative injection amount and the second injection pressure, and as shown in fig. 4, the calculation apparatus of the production pressure difference of the carbonate multi-set reservoir oil well can plot the injection curve according to the cumulative injection amount and the second injection pressure corresponding to the cumulative injection amount of each stage after measuring the values of the cumulative injection amount and the second 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 quantity and the second 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 second injection pressure is shown.
In addition, as shown in fig. 4, the cumulative injection amount and the second injection pressure exhibit a non-linear relationship in the compression stage, and the cumulative injection amount and the second injection pressure exhibit a linear relationship after the fluid is injected for a certain period of time.
In an embodiment of the present invention, after the cumulative injection amount and the second injection pressure are measured, the first injection pressure will be determined from the cumulative injection amount and the second injection pressure.
In one possible implementation, determining the first injection pressure based on the cumulative injection quantity and the second injection pressure includes: drawing an injection curve according to the accumulated injection amount and the second injection pressure; the second injection pressure at the inflection point in the injection curve is determined as the first injection pressure.
Specifically, when a first reservoir is filled with fluid and injection of fluid into a second reservoir through the first reservoir is started, an inflection point will appear in an injection curve drawn in accordance with the accumulated injection amount and the second injection pressure. As shown in fig. 4, the second injection pressure at the inflection point may be determined as the first injection 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 differential pressure of the multiple sets of reservoir bodies of the carbonate rock oil well determines the first injection pressure and calculates the production differential pressure according to the first injection pressure and the wellhead pressure after measuring the wellhead pressure.
In one possible implementation, the differential production pressure is calculated from the wellhead pressure and the first injection 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, P1Is a first injection pressure, P2Is the wellhead pressure.
Specifically, the injected fluid is taken as water for example, and the process of injecting gas is similar to the process of injecting water, and is not 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 ignored, the amount of liquid supply to the remote well reservoir when the well is shut in is 0, i.e., the following relationship is satisfied:
Q 1＝J*(P-△P1-△P2–Pwf)＝0 (1)
wherein Q is1The amount of the second reservoir to the first reservoir during shut-in, P is the initial formation pressure, and Δ P1Is the production pressure differential, Δ P, of the first reservoir2Is the production pressure difference, P, of the second reservoirwfIs the current bottom hole flow pressure.
In addition, because the well storage effect is neglected, when the first reservoir is filled with fluid, the fluid supply amount of the first reservoir to the second reservoir is 0, that is, the following relation is satisfied:
Q2＝J*(Pwf′-△P1-△P2–P)＝0 (2)
wherein Q is2The amount of fluid supplied by the first reservoir to the second reservoir when the first reservoir is filled with fluid, Pwf' bottom hole flow pressure after fluid injection,. DELTA.P1Is the production pressure differential, Δ P, of the first reservoir2Is the production differential pressure of the second reservoir, P is the initial formation pressure.
In addition, due to Pwf′＝PH+P1，Pwf＝PH+P2Wherein P isHThe liquid column pressure, therefore, the following formula (3) can be obtained according to the formulas (1) and (2):
ΔP＝(P1-P2)/2 (3)
from the above, after the first injection pressure is determined and the wellhead pressure is measured, the production differential pressure can be calculated according to the formula (3). When the production pressure difference is calculated by the mode in the embodiment, the first injection pressure can be determined according to the injection curve only by the accumulated injection amount of the fluid and the corresponding second injection pressure, and the production pressure difference is calculated rapidly, so that the phenomenon that the production pressure difference needs to be calculated by monitoring the bottom hole flow pressure through the well, the calculation cost of the production pressure difference can be reduced, and the efficiency of calculating the production pressure difference can be improved.
According to the method for calculating the oil well production differential pressure of the multiple sets of the carbonate rocks, which is provided by the embodiment of the invention, the wellhead pressure before the fluid is injected is measured, the fluid is determined to be filled in the first reservoir, and the first injection pressure when the fluid is injected into the second reservoir is started; wherein the first reservoir is a previous stage reservoir of the second reservoir; then, calculating the production pressure difference according to the wellhead pressure 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 and fill fluid in first reservoir, and the first injection pressure when beginning to pour into fluid into the second reservoir, can calculate the production pressure differential fast, avoided needing to go into the well among the prior art and measure the phenomenon of bottom of the well flowing pressure, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential moreover. In addition, after the injection curve is drawn according to the accumulated injection amount and the second injection pressure, the first injection pressure can be determined by determining the injection pressure at the inflection point in the injection curve, so that the calculation mode of the first injection pressure can be simpler and more convenient.
Fig. 5 is a schematic structural diagram of a first embodiment of a device for calculating a production pressure difference of multiple sets of reservoir bodies of carbonate rocks according to an embodiment of the invention, as shown in fig. 5, the device comprises: a measurement module 11, a determination module 12 and a calculation module 13.
The measuring module 11 is used for measuring the wellhead pressure before injecting the fluid;
the determination module 12 is for determining a first injection pressure at which the first reservoir is filled with the fluid and injection of the fluid into the second reservoir is initiated; wherein the first reservoir is a previous reservoir of the second reservoir;
the calculation module 13 is used for calculating a production pressure difference according to the wellhead pressure and the first injection pressure; wherein the production differential pressure is a difference between a formation pressure and a bottom hole flow pressure.
The device for calculating the oil well production differential pressure of the multiple sets of carbonate rocks provided in the embodiment measures the wellhead pressure before the fluid is injected through the measuring module 11, determines the first injection pressure when the first reservoir is filled with the fluid and starts to inject the fluid into the second reservoir through the determining module 12; wherein the first reservoir is a previous stage reservoir of the second reservoir; then the calculation module 13 calculates the production pressure difference according to the wellhead pressure 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 and fill fluid in first reservoir, and the first injection pressure when beginning to pour into fluid into the second reservoir, can calculate the production pressure differential fast, avoided needing to go into the well among the prior art and measure the phenomenon of bottom of the well flowing pressure, not only can reduce the cost of calculating the production pressure differential from this, can improve the efficiency of calculating the production pressure differential moreover.
Optionally, the calculating module 13 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 first injection pressure, P2Is the wellhead pressure.
The device for calculating the production pressure difference of the multiple sets of reservoir bodies of carbonate rock in the embodiment can be used for executing the technical scheme of any one of the method embodiments, the implementation principle and the technical effect of the device are similar to those of the method embodiments, and the device is not repeated herein.
Fig. 6 is a schematic structural diagram of a second embodiment of the device for calculating the production pressure difference of multiple sets of reservoir bodies of carbonate rocks according to the embodiment of the invention, and on the basis of the embodiment shown in fig. 5, the determining module 12 includes: a measurement sub-module 121 and a determination sub-module 122.
The measurement sub-module 121 is configured to measure a cumulative injection amount of the fluid and a second injection pressure corresponding to the cumulative injection amount when injecting the fluid into each reservoir; the second injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
the determination submodule 122 is configured to determine the first injection pressure based on the cumulative injection quantity and the second injection pressure.
The device for calculating the production pressure difference of the multiple sets of reservoir bodies of carbonate rock in the embodiment can be used for executing the technical scheme of any one of the method embodiments, the implementation principle and the technical effect of the device are similar to those of the method embodiments, and the device is not repeated herein.
Optionally, the determining sub-module 122 is specifically configured to:
drawing an injection curve according to the accumulated injection amount and the second injection pressure;
determining a second injection pressure at an inflection point in the injection profile as the first injection pressure.
The device for calculating the production pressure difference of the multiple sets of the carbonate rock reservoir oil wells can be used for executing the technical scheme of any one of the method embodiments, the implementation principle and the technical effect of the device are similar to those of the method embodiments, and the device is not described again.
Fig. 7 is a schematic structural diagram of a third embodiment of the device for calculating the production pressure difference of multiple sets of reservoir bodies of carbonate rocks according to the embodiment of the invention, and on the basis of the embodiment shown in fig. 6, the device further comprises: a decision block 14.
The judging module 14 is configured to judge whether the cumulative injection amount and the second injection pressure are in a linear relationship, and the judgment result is that the cumulative injection amount and the second injection pressure are in a linear relationship.
The device for calculating the production pressure difference of the multiple sets of the carbonate rock reservoir oil wells can be used for executing the technical scheme of any one of the method embodiments, the implementation principle and the technical effect of the device are similar to those of the method embodiments, and the device is not described again.
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 (8)
1. A method for calculating the production pressure difference of a plurality of sets of oil wells of carbonate rocks is characterized by comprising the following steps:
measuring the wellhead pressure before injecting the fluid;
determining a first injection pressure at which the first reservoir is filled with the fluid and injection of the fluid into the second reservoir is commenced; wherein the first reservoir is a previous reservoir of the second reservoir;
calculating a production pressure difference according to the wellhead pressure 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 production differential pressure from the wellhead pressure and the first injection pressure, comprising:
according to the formula
Calculating the production pressure difference;
wherein the content of the first and second substances,
for the purpose of said production pressure difference,
for the purpose of the first injection pressure,
is the wellhead pressure.
2. The method of claim 1, wherein determining a first injection pressure at which to fill a first reservoir with the fluid and begin injecting the fluid into a second reservoir comprises:
measuring a cumulative injection amount of a fluid and a second injection pressure corresponding to the cumulative injection amount, when the fluid is injected into each reservoir; the second injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
determining the first injection pressure based on the accumulated injection quantity and the second injection pressure.
3. The method of claim 2, wherein said determining the first injection pressure based on the cumulative injection quantity and the second injection pressure comprises:
drawing an injection curve according to the accumulated injection amount and the second injection pressure;
determining a second injection pressure at an inflection point in the injection profile as the first injection pressure.
4. The method of claim 2, wherein prior to measuring the cumulative charge of fluid and the second injection pressure corresponding to the cumulative charge, the method further comprises:
and judging whether the accumulated injection amount and the second injection pressure are in a linear relation or not, wherein the judgment result is that the accumulated injection amount and the second injection pressure are in a linear relation.
5. A device for calculating the production differential pressure of a plurality of sets of reservoir bodies in carbonate rock for an oil well, comprising:
the measuring module is used for measuring the wellhead pressure before the fluid is injected;
a determination module for determining a first injection pressure at which to fill a first reservoir with the fluid and begin injecting the fluid into a second reservoir; wherein the first reservoir is a previous reservoir of the second reservoir;
the calculation module is used for calculating the production pressure difference according to the wellhead pressure 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 is specifically configured to:
according to the formula
Calculating the production pressure difference;
wherein the content of the first and second substances,
for the purpose of said production pressure difference,
for the purpose of the first injection pressure,
is the wellhead pressure.
6. The apparatus of claim 5, wherein the determining module comprises:
a measurement sub-module for measuring a cumulative injection amount of a fluid and a second injection pressure corresponding to the cumulative injection amount when the fluid is injected into each reservoir; the second injection pressure is an injection pressure after the fluid of the cumulative injection amount is injected;
a determination submodule for determining the first injection pressure based on the accumulated injection quantity and the second injection pressure.
7. The apparatus of claim 6, wherein the determination submodule is specifically configured to:
drawing an injection curve according to the accumulated injection amount and the second injection pressure;
determining a second injection pressure at an inflection point in the injection profile as the first injection pressure.
8. The apparatus of claim 6, further comprising:
and the judging module is used for judging whether the accumulated injection amount and the second injection pressure are in a linear relation or not, and the judging result is that the accumulated injection amount and the second injection pressure are in a linear relation.
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