CN107178364B - Method and device for determining connectivity between oil reservoir wells - Google Patents
Method and device for determining connectivity between oil reservoir wells Download PDFInfo
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- CN107178364B CN107178364B CN201710512800.5A CN201710512800A CN107178364B CN 107178364 B CN107178364 B CN 107178364B CN 201710512800 A CN201710512800 A CN 201710512800A CN 107178364 B CN107178364 B CN 107178364B
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Abstract
The invention provides a method and a device for determining the communication between oil reservoir wells, wherein the method comprises the following steps: establishing a geological stratification of a first reservoir to be tested and a second reservoir to be tested; measuring point data of positions of measuring points in the first reservoir to be measured and the second reservoir to be measured are obtained respectively; determining the residual pressure at the position of the measuring point according to the measuring point data and the pressure of the pressure measuring reference surface of the oil reservoir to be measured; and determining the inter-well connectivity of the first oil reservoir to be detected and the second oil reservoir to be detected according to the relation between the residual pressure and the altitude depth of the first oil reservoir to be detected and the second oil reservoir to be detected. In the embodiment of the invention, the residual pressure which can finely depict the change condition of the pressure in the oil reservoir to be detected along with the altitude depth is used for judging the communication among the oil reservoir wells, so that the judgment precision of the communication among the oil reservoir wells is improved, and the method has important effects on guiding oil exploration, reducing exploration cost and improving exploration efficiency.
Description
Technical Field
The invention relates to the technical field of geological exploration, in particular to a method and a device for determining connectivity between oil reservoir wells.
Background
The determination of the connectivity between wells of the oil reservoir is the basis for the formulation of reservoir development schemes. In the prior art, the determination method of the reservoir inter-well connectivity is various, wherein the inter-well interference test is one of the common methods. Since fluid flow in the same pressure system is continuous, interwell intervention testing may refer to the study of formation parameters between an intervention well and an observation well by receiving intervention pressure responses from a high precision pressure gauge in another observation well or observation wells via an intervention well change regime (changes in production pressure differentials, changing nozzles, shutting in wells, etc.).
That is, the bottom hole pressure read by a high-precision pressure gauge in the well is observed to directly determine whether each well is in the same pressure system or not and whether reservoir wells are communicated or not. However, for a multi-oil-water system reservoir containing a plurality of thin sections, the pressure change characteristics of each thin section in the reservoir cannot be accurately reflected only by observing a bottom hole flow pressure read by a high-precision pressure gauge in a well, and therefore, the misjudgment of the longitudinal connectivity of a single-well oil layer and the connectivity between each reservoir often occurs.
Disclosure of Invention
The invention provides a method and a device for determining the connectivity between oil reservoirs, which are used for achieving the purpose of accurately judging the connectivity between the oil reservoirs.
The embodiment of the invention provides a method for determining the connectivity between oil reservoir wells, which comprises the following steps: dividing a first reservoir to be tested into at least one first layer section; acquiring first measuring point data at the position of each first measuring point in the first layer section, wherein the first measuring point data comprise: a first elevation depth and a first measured formation pressure of the first measurement point; determining a first residual pressure at the position of the first measuring point according to the first actually-measured formation pressure and the determined first pressure measuring reference surface pressure of the first oil reservoir to be measured; dividing a second reservoir to be detected into at least one second interval corresponding to the first interval based on the interval division result of the first reservoir to be detected; acquiring second measuring point data at the position of each second measuring point in the second layer section, wherein the second measuring point data comprise: a second elevation depth and a second measured formation pressure of the second measurement point; determining a second residual pressure at the position of the second measuring point according to the second actually-measured formation pressure and the determined second pressure measuring reference surface pressure of the second oil reservoir to be measured; and determining the inter-well connectivity of the first oil reservoir to be tested and the second oil reservoir to be tested according to the first residual pressure, the first altitude depth, the second residual pressure and the second altitude depth.
In one embodiment, the first station data may further include, but is not limited to, at least one of: the first fluidity of the first measuring point and the first water density under the stratum state, and the data of the second measuring point further comprises at least one of the following data: and the second fluidity of the second measuring point and the second water density under the stratum state.
In one embodiment, prior to determining the interwell connectivity of the first reservoir under test and the second reservoir under test, the method may further comprise: removing first measuring points of which the first flow rate is smaller than a first preset threshold value in the first measuring point data; and eliminating second measuring points of which the second fluidity is smaller than a second preset threshold value in the second measuring point data.
In one embodiment, determining a first residual pressure at the location of the first measurement point may comprise: calculating a first hydrostatic pressure at the position of the first measuring point according to the first water density and the first altitude depth; calculating a first residual pressure at the position of the first measuring point by using the first actually-measured formation pressure, the first hydrostatic pressure and the first pressure measuring reference surface pressure; accordingly, determining a second residual pressure at the location of the second measurement point may comprise: calculating a second hydrostatic pressure at the position of the second measuring point according to the second water density and the second altitude depth; and calculating second residual pressure at the position of the second measuring point by using the second measured formation pressure, the second hydrostatic pressure and the second pressure measuring reference surface pressure.
In one embodiment, after determining the interwell connectivity of the first reservoir under test and the second reservoir under test, the method may further comprise: determining the connectivity of the first measuring point in the first interval in the longitudinal direction according to the fitting condition of the first residual pressure and the first altitude depth; and determining the connectivity of the second measuring point in the second interval in the longitudinal direction according to the fitting condition of the second residual pressure and the second altitude depth.
In one embodiment, determining the interwell connectivity of the first reservoir under test and the second reservoir under test may include: and determining connectivity between the first reservoir to be tested and the second reservoir to be tested by combining the combined fitting conditions of the first residual pressure and the second residual pressure and the first altitude depth and the second altitude depth.
In one embodiment, the first pressure measurement reference surface pressure of the first reservoir to be measured may be determined as follows: calculating to obtain a first preset residual pressure of the first oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the first altitude depth and the first actually-measured formation pressure; according to the first preset residual pressure and the first altitude depth, fitting to obtain a first relation that the first residual pressure in the first interval changes along with the first altitude depth; when the first relation in the first relation is selected as a constant expression, the constant value of the constant expression is used as a first pressure measurement reference surface pressure of the first oil reservoir to be measured; correspondingly, the second pressure measurement reference surface pressure of the second reservoir to be measured can be determined as follows: calculating to obtain a second preset residual pressure of the second oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the second altitude depth and the second actually-measured formation pressure; according to the second preset residual pressure and the second altitude depth, fitting to obtain a second relation of the second residual pressure in the second interval changing along with the second altitude depth; and when the second relation in the second relation is selected as a constant expression, the constant value of the constant expression is used as the second pressure measurement reference surface pressure of the second oil reservoir to be measured.
The embodiment of the invention also provides a device for determining the connectivity between oil reservoir wells, which can comprise: the first interval dividing module can be used for dividing a first oil reservoir to be detected into at least one first interval; the first data acquiring module may be configured to acquire first measurement point data at positions of first measurement points in the first interval, where the first measurement point data may include: a first elevation depth and a first measured formation pressure of the first measurement point; the first pressure determining module can be used for determining first residual pressure at the position of the first measuring point according to the first actually-measured formation pressure and the determined first pressure measuring reference surface pressure of the first oil reservoir to be measured; the second interval dividing module may be configured to divide a second reservoir to be tested into at least one second interval corresponding to the first interval based on an interval dividing result of the first reservoir to be tested; the second data acquiring module may be configured to acquire second measurement point data at positions of second measurement points in the second interval, where the second measurement point data may include: a second elevation depth and a second measured formation pressure of the second measurement point; the second pressure determining module may be configured to determine a second residual pressure at the position of the second measuring point according to the second actually-measured formation pressure and the determined second pressure measurement reference surface pressure of the second oil reservoir to be measured; and the connectivity determining module can be used for determining the inter-well connectivity of the first oil reservoir to be detected and the second oil reservoir to be detected according to the first residual pressure, the first altitude depth, the second residual pressure and the second altitude depth.
In one embodiment, the first station data may further include, but is not limited to, at least one of: the first fluidity of the first measuring point and the first water density under the stratum state, and the second measuring point data can also comprise but is not limited to at least one of the following: and the second fluidity of the second measuring point and the second water density under the stratum state.
In one embodiment, the apparatus may further include: the first measuring point removing unit can be used for removing a first measuring point of which the first fluidity is smaller than a first preset threshold value in the first measuring point data before determining the connectivity of the first oil reservoir to be measured and the second oil reservoir to be measured; the first measuring point rejecting unit can be used for rejecting second measuring points of which the second fluidity is smaller than a second preset threshold value in the second measuring point data.
In the embodiment of the invention, the residual pressure of each measuring point in different intervals is calculated and determined by utilizing the actually measured formation pressure data of each measuring point, and the residual pressure capable of finely depicting the change condition of the pressure in the oil reservoir to be measured along with the altitude depth is utilized to judge the connectivity between wells of the oil reservoir, so that the defect that the pressure change characteristics of each thin interval in the oil reservoir cannot be accurately reflected due to the fact that only one pressure value is read for the section to be measured in the existing interference test technology is overcome, the judgment precision of the connectivity between wells of the oil reservoir is improved, and the method has important effects on guiding oil exploration, reducing exploration cost and improving exploration efficiency.
Drawings
In order to more clearly illustrate the embodiments of the present application 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, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort.
FIG. 1 is a flow chart of a method for determining reservoir interwell connectivity provided herein;
FIG. 2 is a schematic representation of the residual pressure in interval 2 of wells A and B as a function of elevation depth as provided herein;
FIG. 3 is a schematic representation of the residual pressure in interval 3 of wells A and B as a function of altitude depth as provided herein;
FIG. 4 is a schematic representation of the residual pressure in interval 1 of the A-well and B-well provided herein as a function of elevation depth;
FIG. 5 is a schematic diagram of measured formation pressure in interval 1 of wells A and B as a function of elevation depth provided by the present application;
fig. 6 is a block diagram of a device for determining the connectivity between wells of a reservoir according to the present application.
Detailed Description
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. 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 application.
It should be noted that, in the description of the present application, the terms "first", "second", and the like are used for descriptive purposes only and to distinguish similar objects, such as: the first reservoir to be tested and the second reservoir to be tested only represent two different reservoirs, the first interval and the second interval only represent two different intervals, no sequence exists between the first interval and the second interval, and relative importance can not be understood as indication or hint. In addition, in the description of the present application, "a plurality" means two or more unless otherwise specified.
Considering the defect that the connectivity of an oil well is easily misjudged when the connectivity of the oil well is directly determined only by observing one bottom hole flowing pressure read by a high-precision pressure gauge in the oil well when the connectivity of the oil well is determined by interference tests in the prior art, the inventor provides a method for determining the residual pressure of each measuring point in each interval by using the actually measured formation pressure under the constraint of a layered lattice and then determining the connectivity of the oil reservoir between wells according to the residual pressure. Based on the above, a method for determining the connectivity between wells of a reservoir is provided, as shown in fig. 1, which may include the following steps:
s101: the first reservoir to be tested is divided into at least one first interval.
The first reservoir to be measured can be geologically layered according to existing data (logging data, core characteristic data, seismic profile reflection characteristics, geological knowledge and the like), and is divided into at least one first interval. The first reservoir to be tested may be an oil well. For example: when the first oil reservoir to be detected is a thin sandstone multi-oil-water system, 3 sandstone layer groups exist in the system according to the existing data, the 3 sandstone layer groups are separated by mudstone layers with the thickness of about 30m, namely, the 3 sandstone layers can be divided into three first intervals.
S102: acquiring first measuring point data at the position of each first measuring point in the first layer section, wherein the first measuring point data comprise: a first elevation depth and a first measured formation pressure of the first measurement station.
After dividing the first reservoir to be measured into a plurality of first layer segments, a plurality of first measuring points can be selected from the first layer segments, and first measuring point data at positions of the first measuring points in the plurality of first measuring points can be obtained.
In this embodiment, the first measurement point data may include: a first elevation depth of the first measurement point; but also includes, but is not limited to, at least one of: the first mobility, a first crude oil density at a formation condition, and a first water density at the formation condition.
S103: and determining a first residual pressure at the position of the first measuring point according to the first actually-measured formation pressure and the determined first pressure measuring reference surface pressure of the first oil reservoir to be measured.
And determining a first residual pressure at the position of the first measuring point according to the first actually-measured formation pressure and the determined first pressure measuring reference surface pressure of the first oil reservoir to be measured in the step S102.
In this application, the first residual pressure may be indicative of a fluid in the reservoir having a uniform head or fluid potential. The residual pressure may be defined as the difference of the measured formation pressure minus the hydrostatic pressure at the corresponding elevation depth and the manometric reference surface pressure. According to the definition of the residual pressure, the following steps are carried out: the residual pressure is determined after the hydrostatic pressure which cannot reflect the change condition of the formation pressure is removed on the basis of the measured actually-measured formation pressure, so that compared with a method for judging the connectivity among wells of the oil reservoir by directly adopting pressure in the prior art, the method for judging the connectivity among wells of the oil reservoir by adopting the residual pressure can better research the condition that the hydraulic pressure in the oil reservoir is suddenly changed, and certainly, the connectivity among wells of the oil reservoir can be more accurately judged.
Because of the difference of oil and water density, residual pressure can be generated in the oil reservoir. If the trap contains oil and a certain measuring point (such as point A) is located in the oil layer, the pressure P of point A is under the influence of buoyancy due to the difference of specific gravity of oil and waterAoWill be greater than the formation pressure when the trap is totally water. At this time, the remaining pressure at the position of the point a can be expressed as:
ΔP＝PAo-Gpohg-Pbase of (1)
In the above formula, Gpo＝0.1450377ρwfg；
In the above formula, Δ P is the residual pressure in psi; pAoMeasured formation pressure at point a in psi; h isgThe height A is higher than the distance between the pressure measuring reference surfaces, and the unit is m; rhowfIs the water density in g/cm in the formation state3；PBase ofThe pressure is the pressure of a pressure measuring reference surface; gpoHydrostatic pressure gradient in psi/m; 0.1450377 is the unit conversion coefficient between the PSI unit system and the MPA unit system.
In one embodiment of the present application, the first pressure measurement reference surface pressure of the first reservoir to be measured may be determined as follows: calculating to obtain a first preset residual pressure of the first oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the first altitude depth and the first actually-measured formation pressure; according to the first preset residual pressure and the first altitude depth, fitting to obtain a first relation that the first residual pressure in the first interval changes along with the first altitude depth; and when the first relation in the first relation is selected as a constant expression, the constant value of the constant expression is used as the first pressure measurement reference surface pressure of the first oil reservoir to be measured.
Since in the pure water layer, ρwf＝1g/cm3，g＝9.78m/s2Then can be according to Gpo＝0.1450377ρwfg, determining the hydrostatic pressure gradient in the pure water layer, wherein the hydrostatic pressure gradient is a constant: 1.418 psi/m.
At least one hydrostatic pressure gradient may be set based on the hydrostatic pressure gradient in the pure water layer, the difference between the preset at least one hydrostatic pressure gradient and the hydrostatic pressure gradient in the water layer being within a predetermined threshold range. Since the residual pressure in the water layer is equal to 0, it can be known from equation (1): in the aqueous layer, PAo-Gpohg＝PBase of. Therefore, after the preset at least one hydrostatic pressure gradient is obtained, a first preset residual pressure may be calculated according to the first elevation depth and the first measured formation pressure by using the above equation (1), and then a first relationship that the first residual pressure in the first interval changes with the first elevation depth may be obtained by fitting according to the first preset residual pressure and the first elevation depth. Repeating the above steps according to at least one hydrostatic pressure gradient to determine at least one first relationship; selecting the first relation as a constant expression in the first relation, namely: and when the first residual pressure is a constant value, the constant value can be used as the first pressure measuring reference surface pressure of the first oil reservoir to be measured.
In another embodiment of the present application, when obtaining the first relationship of the first residual pressure in the first interval with the change of the first altitude depth, a schematic of the change of the first residual pressure with the first altitude depth may also be plotted, and the stability of the first residual pressure in the plotted schematic may be observed. When the first residual pressure swings with equal amplitude around a certain fixed value along with the preset at least one hydrostatic pressure gradient in the drawn schematic diagram, that is, when a residual pressure regression line is a vertical line, the corresponding first residual pressure can be used as the first pressure measurement reference surface pressure of the first oil reservoir to be measured.
For example: for an N-well, the relationship between residual pressure and elevation depth can be fitted as a left-biased straight line when the preset hydrostatic pressure gradient is 1.418psi/m, with the residual pressure decreasing gradually as the elevation depth increases. If the preset hydrostatic pressure gradient is 1.424psi/m, the relationship between the residual pressure and the altitude depth can be fitted to a right-biased straight line, that is, the residual pressure gradually increases with the increase of the altitude depth. Although the two conditions do not meet the judgment requirement of the pressure measuring reference surface pressure, namely, the residual pressure determined by adopting the preset hydrostatic pressure gradient is inaccurate. But it can be preliminarily determined that the hydrostatic pressure gradient of the N-well is between 1.418psi/m and 1.424 psi/m.
After the pressure of the first pressure measuring reference surface is determined in the above manner, according to a formula (1), a first hydrostatic pressure at the position of the first measuring point is calculated according to the first water density and the first altitude depth; and then calculating the first residual pressure at the position of the first measuring point by using the first actually-measured formation pressure, the first hydrostatic pressure and the first pressure measuring reference surface pressure.
S104: and dividing a second reservoir to be detected into at least one second interval corresponding to the first interval based on the interval division result of the first reservoir to be detected.
And dividing the second reservoir to be tested into at least one second interval in the same manner as in the step S101. It is noted, however, that the first interval and the second interval are both located in the same interval. For example: and dividing the first reservoir to be tested into a layer 1, a layer 2 and a layer 3, and dividing the second reservoir to be tested into a section 1, a section 2 and a section 3. Specifically, layer 1 and section 1 are located in the same layer segment, layer 2 and section 2 are located in the same layer segment, and layer 3 and section 3 are located in the same layer segment. By adopting the interval division mode, the same interval is adopted when the interwell connectivity judgment is carried out on the intervals of two or more oil reservoirs to be detected. Meanwhile, as can be seen from the above description: the target for the inter-well connectivity determination may be 2 wells, 3 wells, or 3 or more wells.
S105: acquiring second measuring point data at the position of each second measuring point in the second layer section, wherein the second measuring point data comprise: a second elevation depth and a second measured formation pressure of the second measurement point.
The second measuring point data of the positions of the second measuring points in the second interval can be obtained in the same way as in the step S102.
S106: and determining second residual pressure at the position of the second measuring point according to the second actually-measured formation pressure and the determined second pressure measuring reference surface pressure of the second oil reservoir to be measured.
Similarly, after the second measuring point data is obtained, a second residual pressure at the position of the second measuring point can be determined according to the second measuring point data and the determined second pressure measurement reference surface pressure of the second oil reservoir to be measured in the same manner as in S103.
S107: and determining the connectivity of the first oil reservoir to be tested and the second oil reservoir to be tested according to the first residual pressure, the first altitude depth, the second residual pressure and the second altitude depth.
In this embodiment, the first measuring point with the first flow rate smaller than the first preset threshold in the first measuring point data in S102 may be eliminated; eliminating second measuring points of which the second fluidity is smaller than a second preset threshold in the second measuring point data in the S102; after the first measuring point and the second measuring point which are removed and have large residual pressure changes are removed, determining connectivity of the first oil reservoir to be detected and the second oil reservoir to be detected according to the first residual pressure, the first altitude depth, the second residual pressure and the second altitude depth which correspond to the measuring point values of the first measuring point and the second measuring point which are removed.
The connectivity of the first reservoir to be tested and the second reservoir to be tested can refer to the connectivity of each first measuring point in each first interval in the first reservoir to be tested in the longitudinal direction, the connectivity of each second measuring point in each second interval in the second reservoir to be tested in the longitudinal direction, and the connectivity between each first interval in the first reservoir to be tested and each second interval in the second reservoir to be tested.
In one embodiment of the present application, connectivity of the first reservoir under test and the second reservoir under test may be determined as follows:
s7-1: and determining the connectivity of the first measuring point in the first interval in the longitudinal direction according to the fitting condition of the first residual pressure and the first altitude depth.
According to the fitting condition of the first residual pressure and the first altitude depth, if the first residual pressure and the first altitude depth can be fitted to form a straight line, the first measuring points in the first interval are communicated in the longitudinal direction. For example, there are 4 first measurement points in layer 1 of the first reservoir to be measured, and if the residual pressure and the corresponding altitude depth at the positions of the 4 first measurement points can be fitted to a straight line, the 4 first measurement points in layer 1 are longitudinally communicated.
S7-2: and determining the connectivity of the second measuring point in the second interval in the longitudinal direction according to the fitting condition of the second residual pressure and the second altitude depth.
According to the fitting condition of the second residual pressure and the second altitude depth, if the second residual pressure and the second altitude depth can be fitted to form a straight line, the second measuring points in the first interval are longitudinally communicated.
S7-3: and determining connectivity between the first reservoir to be tested and the second reservoir to be tested by combining the fitting condition of the first residual pressure and the first altitude depth and the fitting condition of the second residual pressure and the second altitude depth.
And combining the fitting condition of the first residual pressure and the first altitude depth and the fitting condition of the second residual pressure and the second altitude depth, and if the two fitting results can be fitted into a straight line within an error allowable range, determining that the measuring points on the corresponding positions in the first reservoir to be measured and the second reservoir to be measured are communicated.
According to the method and the device, under the constraint of geological stratification, the residual pressure of each measuring point in each layered interval is calculated by utilizing the actually measured stratum pressure, the residual pressure which can represent the pressure in each interval along with the change of the altitude depth more accurately is utilized, and the connectivity of the oil reservoir to be measured is determined according to the relation between the residual pressure and the altitude depth. By adopting the method, the connectivity of the oil reservoir to be detected can be more accurately judged, and further, the method plays an important role in guiding oil exploration, reducing exploration cost and improving exploration efficiency.
The method for determining the connectivity between wells of a reservoir is described in detail with reference to a specific example, but it should be noted that the specific example is only for better illustrating the present invention and should not be construed as limiting the present invention.
In this example, the inter-well connectivity of two thin sandstone wells in a certain field is determined finely. The oil field exploration degree is lower, only 1 hole of each drilling well at the high part and the structural waist is respectively an A well and a B well, wherein the A well is the first oil deposit to be detected, the B well is the second oil deposit to be detected, the two wells are both straight wells, and the well mouth distance is 300 m. The reservoir is medium and new river facies sandstone, the sand layer is generally thin, the longitudinal multi-layer section development is realized, 2 to 3 sand layers are usually developed, the sand layers are separated by a mudstone layer with the thickness of 10 to 30m, each sand layer has actually-measured formation pressure data, the porosity is 22 to 27 percent, and the permeability is 300mD to 800 mD.
In this example, well a and well B each performed interference tests in 3 intervals to confirm connectivity of well B to well a thin reservoir. Interference test data show that the front 3 intervals of the well A and the well B are respectively communicated between the two wells, and when the interference test is carried out on the well B, the pressure of the 2 nd interval of the well A is reduced by more than 8Psi in 48 hours; the pressure in interval 3 dropped by 6Psi, even though the pressure dropped the least in interval 1, the pressure dropped by more than 1Psi over 24 hours.
Based on existing seismic geology and well logging data, well a and well B are divided into 3 intervals, namely, layer 1, layer 2 and layer 3. In 3 intervals, the A well has 13 actually measured formation pressure data, the B well has 11 actually measured formation pressure data, namely, the A well has 13 first measuring points in 3 intervals, and the first measuring point data and the first residual pressure of the 13 measuring points are shown in the table 1; the B well has 11 second measuring points in 3 intervals, and the second measuring point data and the second residual pressure of the 11 second measuring points are shown in the table 1.
TABLE 1 survey point data for three intervals of well A and well B
According to the research data of the area and the oil field, the method for calculating the pressure measuring reference surface in the step S103 is known as follows: the pressure of the pressure measuring reference surfaces of the well A and the well B are 855Psi, and the water density in the stratum state is 0.983g/cm3From equation (1), the residual pressure at each measurement point can be found, as shown in table 1.
In table 2, 2 effective first measuring points exist in the 2 nd interval of the well a, 3 effective second measuring points exist in the 2 nd interval of the well B, and the fitting relation of the 2 nd interval is obtained by fitting according to the relation between the residual pressure and the altitude depth of the 5 measuring points of the two wells: y-3.7391 x +612.26, goodness of fit R20.9996, as shown in the schematic diagram of the change in pressure remaining in interval 2 of wells a and B with altitude depth in fig. 2. Therefore, the following steps are carried out: there is a clear linear relationship between the altitude depth and the residual pressure between these 5 measurement points, which can be fitted to a straight line, so that these two wells are interconnected in this interval (interval 2), which is also consistent with the results of the interference test.
For the 3 rd interval, as shown in the schematic diagram of the variation of the residual pressure of the 3 rd interval of the a well and the B well along with the altitude depth in fig. 3, the a well and the B well have 5 pressure measuring points and 4 pressure measuring points respectively, although the slope of the line regressing the residual pressure along with the altitude depth between the two wells is slightly different (the a well: y is-2.9131 x +667.46, R well20.9878, well B: -3.0953x +689.73, R20.9372) but still within the tolerance of the error. Residual pressure of 11 pressure measuring points of two wells is utilizedAnd (3) carrying out regression on the force and the altitude, and fitting to obtain the value of-3.6893 x +698, R within an error allowable range20.9958, it can be known that: the interval 3 was interconnected between the two wells and the residual pressure fit was consistent with the interference test.
For the layer 1, the A well has 6 pressure measuring points, the B well has 5 pressure measuring points, as shown in the schematic diagram of the change of the residual pressure of the layer 1 of the A well and the B well along with the altitude depth in fig. 4, wherein the residual pressure of the first 3 measuring points in the A well and the B well has a good linear relation along with the altitude depth (the A well: y-3.6247 x +414.9, R well: y-3.6247 x + 414.9)20.9975, B well: -5.8279x +402.4, R20.9997), the fluidity at 416.42m in the B well is only 13mD/cp, and compared with other measuring points, the fluidity is obviously lower, so that the B well is removed. The fluidity of 420.73m in the well A is only 17mD/cp, which is probably caused by overpressure due to small physical properties, so that the well A is removed; the residual pressure at the measuring point 412.92m is greatly different from the changes of other measuring points, probably because the measuring point is separated from the upper sand layer by mudstone of nearly 30m, so the point can be regarded as belonging to a separate oil layer and not belonging to the same pressure system with the upper oil layer. Therefore, the 4 points in front of the well A and the 3 points in front of the well B belong to two pressure systems, and the two pressure systems are not communicated with each other. According to the B well interference test, the following results are obtained: the pressure dropped by more than 1Psi over 24 hours in the a well, indicating that there was some communication between the two wells. Fitting the measuring points at 410.01m of the well B with the residual pressure and the altitude depth of the first 4 measuring points of the well A can obtain: -3.6247x +414.9, R20.9975, so these several stations are in the same pressure system.
When the existing fitting mode of the actually measured formation pressure along with the altitude depth is adopted, for the 1 st interval, as shown in a schematic diagram of the actually measured formation pressure along with the altitude depth of the 1 st interval of the a well and the B well in fig. 5, except for the measuring points at 420.73m in the a well, the relation between the actually measured pressure and the altitude depth of the first 5 measuring points is as follows: y-3.6893 x +698, wherein R is2When the ratio is 0.9997, it is found that: the 5 measuring points of the A well are in the same pressure system. Similarly, for well B, the measured pressure at 5 stations versus altitude depth is: 0.7708x +698-690.76, R20.9994, i.e. B wellThese 5 stations are in the same pressure system. Comparing well A and well B shows that: the measuring point of 416.42m of the well B falls on the regression line of the well A, possibly belonging to the same fluid system with the well A, and 5 sand layers in the longitudinal direction of the well A are communicated with each other, so that the fact that the well A is communicated with the 1 st layer of the well B can be inferred. Comparing fig. 4 and 5, it can be seen that: the existing method for determining connectivity by using the measured altitude depth cannot achieve the purpose of fine analysis, and the longitudinal connectivity in the 1 st interval of the A well and the 1 st interval of the B well and the longitudinal connectivity between the 1 st intervals of the A well and the B well are exaggerated.
Based on the same inventive concept, the embodiment of the invention also provides a device for determining the connectivity between wells of an oil reservoir, as described in the following embodiments. Because the principle of solving the problems of the determining device for the inter-well connectivity of the oil reservoir is similar to the determining method for the inter-well connectivity of the oil reservoir, the implementation of the determining device for the inter-well connectivity of the oil reservoir can refer to the implementation of the determining method for the inter-well connectivity of the oil reservoir, and repeated parts are not repeated. As used hereinafter, the term "unit" or "module" may be a combination of software and/or hardware that implements a predetermined function. Although the means described in the embodiments below are preferably implemented in software, an implementation in hardware, or a combination of software and hardware is also possible and contemplated. Fig. 6 is a block diagram of a structure of a device for determining connectivity between wells of a reservoir according to an embodiment of the present invention, as shown in fig. 6, which may include: a first layer segment dividing module 601, a first data obtaining module 602, a first pressure determining module 603, a second layer segment dividing module 604, a second data obtaining module 605, a second pressure determining module 606, and a connectivity determining module 607.
The first interval dividing module 601 may be configured to divide a first reservoir to be tested into at least one first interval;
a first data obtaining module 602, configured to obtain first measurement point data at a position of each first measurement point in the first interval, where the first measurement point data includes: a first elevation depth and a first measured formation pressure of the first measurement point;
the first pressure determining module 603 may be configured to determine a first residual pressure at a position where the first measurement point is located according to the first actually-measured formation pressure and the determined first pressure measurement reference surface pressure of the first oil reservoir to be measured;
a second interval dividing module 604, configured to divide a second reservoir to be tested into at least one second interval corresponding to the first interval based on an interval dividing result of the first reservoir to be tested;
a second data obtaining module 605, configured to obtain second measurement point data at positions of second measurement points in the second interval, where the second measurement point data includes: a second elevation depth and a second measured formation pressure of the second measurement point;
the second pressure determining module 606 may be configured to determine a second residual pressure at the position of the second measurement point according to the second measured formation pressure and the determined second pressure measurement reference surface pressure of the second oil reservoir to be measured;
a connectivity determining module 607, configured to determine the inter-well connectivity of the first oil reservoir to be tested and the second oil reservoir to be tested according to the first residual pressure, the first altitude depth, the second residual pressure, and the second altitude depth.
In one embodiment, the first station data may further include, but is not limited to, at least one of: the first fluidity of the first measuring point and the first water density under the stratum state, and the data of the second measuring point further comprises at least one of the following data: and the second fluidity of the second measuring point and the second water density under the stratum state.
In one embodiment, the apparatus may further include: the first measuring point removing unit can be used for removing a first measuring point of which the first fluidity is smaller than a first preset threshold value in the first measuring point data before determining the connectivity of the first oil reservoir to be measured and the second oil reservoir to be measured; the first measuring point rejecting unit can be used for rejecting second measuring points of which the second fluidity is smaller than a second preset threshold value in the second measuring point data.
In one embodiment, the first pressure determination module may include: the first hydrostatic pressure calculation unit may be configured to calculate a first hydrostatic pressure at a position where the first measurement point is located according to the first water density and the first altitude depth; the first residual pressure calculation unit may be configured to calculate a first residual pressure at a position where the first measurement point is located, using the first actually-measured formation pressure, the first hydrostatic pressure, and the first pressure measurement reference surface pressure; accordingly, the second pressure determination module may include: the second hydrostatic pressure calculating unit may be configured to calculate, according to the second water density and the second altitude depth, a second hydrostatic pressure at a position where the second measurement point is located; the second residual pressure calculation unit may be configured to calculate a second residual pressure at the position of the second measurement point by using the second measured formation pressure, the second hydrostatic pressure, and the second pressure measurement reference surface pressure.
In one embodiment, the apparatus may further include: the first measuring point connectivity determining module can be used for determining the connectivity of the first measuring point in the first interval in the longitudinal direction according to the fitting condition of the first residual pressure and the first altitude depth after determining the inter-well connectivity of the first reservoir to be measured and the second reservoir to be measured; and the second measuring point connectivity determining module can be used for determining the connectivity of the second measuring point in the second interval in the longitudinal direction according to the fitting condition of the second residual pressure and the second altitude depth.
In one embodiment, the connectivity determination module may be configured to determine connectivity between the first reservoir under test and the second reservoir under test by combining joint fitting conditions between the first residual pressure and the second residual pressure and the first altitude depth and the second altitude depth.
In an embodiment, the first pressure determining module may be specifically configured to determine the first pressure measurement reference surface pressure of the first reservoir to be tested according to the following manner: calculating to obtain a first preset residual pressure of the first oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the first altitude depth and the first actually-measured formation pressure; according to the first preset residual pressure and the first altitude depth, fitting to obtain a first relation that the first residual pressure in the first interval changes along with the first altitude depth; when the first relation in the first relation is selected as a constant expression, the constant value of the constant expression is used as a first pressure measurement reference surface pressure of the first oil reservoir to be measured; correspondingly, determining the second pressure measurement reference surface pressure of the second oil reservoir to be measured according to the following modes: calculating to obtain a second preset residual pressure of the second oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the second altitude depth and the second actually-measured formation pressure; according to the second preset residual pressure and the second altitude depth, fitting to obtain a second relation of the second residual pressure in the second interval changing along with the second altitude depth; and when the second relation in the second relation is selected as a constant expression, the constant value of the constant expression is used as the second pressure measurement reference surface pressure of the second oil reservoir to be measured.
Although the present application has been described with reference to the determination of the residual pressure, the determination of the pressure reference surface, and the like, the present application is not limited to the case where it is necessary to describe the embodiments of the present application. Certain industry standards, or implementations modified slightly from those described using custom modes or examples, may also achieve the same, equivalent, or similar, or other, contemplated implementations of the above-described examples. Examples of data acquisition using such modified or modified data determination methods may still fall within the scope of alternative embodiments of the present application.
Although the present application provides method steps as described in an embodiment or flowchart, more or fewer steps may be included based on conventional or non-inventive means. The order of steps recited in the embodiments is merely one manner of performing the steps in a multitude of orders and does not represent the only order of execution. When an actual apparatus or end product executes, it may execute sequentially or in parallel (e.g., parallel processors or multi-threaded environments, or even distributed data processing environments) according to the method shown in the embodiment or the figures. The terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, the presence of additional identical or equivalent elements in a process, method, article, or apparatus that comprises the recited elements is not excluded.
The units, devices, modules, etc. set forth in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions. For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, in implementing the present application, the functions of each module may be implemented in one or more software and/or hardware, or a module implementing the same function may be implemented by a combination of a plurality of sub-modules or sub-units, and the like. The above-described embodiments of the apparatus are merely illustrative, and for example, the division of the units is only one logical division, and other divisions may be realized in practice, for example, a plurality of units or components may be combined or integrated into another system, or some features may be omitted, or not executed. In addition, the shown or discussed mutual coupling or direct coupling or communication connection may be an indirect coupling or communication connection through some interfaces, devices or units, and may be in an electrical, mechanical or other form.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may therefore be considered as a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, classes, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
From the above description of the embodiments, it is clear to those skilled in the art that the present application can be implemented by software plus necessary general hardware platform. Based on such understanding, the technical solutions of the present application may be embodied in the form of a software product, which may be stored in a storage medium, such as a ROM/RAM, a magnetic disk, an optical disk, or the like, and includes several instructions for enabling a computer device (which may be a personal computer, a mobile terminal, a server, or a network device) to execute the method according to the embodiments or some parts of the embodiments of the present application.
The embodiments in the present specification are described in a progressive manner, and the same or similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the spirit of the application.
Claims (10)
1. A method for determining the connectivity between wells of a reservoir, comprising:
dividing a first reservoir to be tested into at least one first layer section;
acquiring first measuring point data at the position of each first measuring point in the first layer section, wherein the first measuring point data comprise: a first elevation depth and a first measured formation pressure of the first measurement point;
determining a first residual pressure at the position of the first measuring point according to the first actually-measured formation pressure and the determined first pressure measuring reference surface pressure of the first oil reservoir to be measured;
dividing a second reservoir to be detected into at least one second interval corresponding to the first interval based on the interval division result of the first reservoir to be detected;
acquiring second measuring point data at the position of each second measuring point in the second layer section, wherein the second measuring point data comprise: a second elevation depth and a second measured formation pressure of the second measurement point;
determining a second residual pressure at the position of the second measuring point according to the second actually-measured formation pressure and the determined second pressure measuring reference surface pressure of the second oil reservoir to be measured;
and determining the inter-well connectivity of the first oil reservoir to be tested and the second oil reservoir to be tested according to the first residual pressure, the first altitude depth, the second residual pressure and the second altitude depth.
2. The method of claim 1, wherein the first station data further comprises at least one of: the first fluidity of the first measuring point and the first water density under the stratum state, and the data of the second measuring point further comprises at least one of the following data: and the second fluidity of the second measuring point and the second water density under the stratum state.
3. The method of claim 2, wherein prior to determining the interwell connectivity of the first reservoir under test and the second reservoir under test, the method further comprises:
removing first measuring points of which the first flow rate is smaller than a first preset threshold value in the first measuring point data;
and eliminating second measuring points of which the second fluidity is smaller than a second preset threshold value in the second measuring point data.
4. The method of claim 2, wherein determining a first residual pressure at the location of the first measurement point comprises:
calculating a first hydrostatic pressure at the position of the first measuring point according to the first water density and the first altitude depth;
calculating a first residual pressure at the position of the first measuring point by using the first actually-measured formation pressure, the first hydrostatic pressure and the first pressure measuring reference surface pressure;
accordingly, determining a second residual pressure at the location of the second measurement point comprises:
calculating a second hydrostatic pressure at the position of the second measuring point according to the second water density and the second altitude depth;
and calculating second residual pressure at the position of the second measuring point by using the second measured formation pressure, the second hydrostatic pressure and the second pressure measuring reference surface pressure.
5. The method of claim 1, wherein after determining the inter-well connectivity of the first reservoir under test and the second reservoir under test, the method further comprises:
determining the connectivity of the first measuring point in the first interval in the longitudinal direction according to the fitting condition of the first residual pressure and the first altitude depth;
and determining the connectivity of the second measuring point in the second interval in the longitudinal direction according to the fitting condition of the second residual pressure and the second altitude depth.
6. The method of claim 5, wherein determining the cross-well connectivity of the first reservoir under test and the second reservoir under test comprises:
and determining connectivity between the first reservoir to be tested and the second reservoir to be tested by combining the combined fitting conditions of the first residual pressure and the second residual pressure and the first altitude depth and the second altitude depth.
7. The method of claim 1, wherein the first manometric reference surface pressure of the first reservoir under test is determined by:
calculating to obtain a first preset residual pressure of the first oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the first altitude depth and the first actually-measured formation pressure;
according to the first preset residual pressure and the first altitude depth, fitting to obtain a first relation that the first residual pressure in the first interval changes along with the first altitude depth;
when the first relation in the first relation is selected as a constant expression, the constant value of the constant expression is used as a first pressure measurement reference surface pressure of the first oil reservoir to be measured;
correspondingly, determining the second pressure measurement reference surface pressure of the second oil reservoir to be measured according to the following modes:
calculating to obtain a second preset residual pressure of the second oil reservoir to be detected according to at least one preset hydrostatic pressure gradient, the second altitude depth and the second actually-measured formation pressure;
according to the second preset residual pressure and the second altitude depth, fitting to obtain a second relation of the second residual pressure in the second interval changing along with the second altitude depth;
and when the second relation in the second relation is selected as a constant expression, the constant value of the constant expression is used as the second pressure measurement reference surface pressure of the second oil reservoir to be measured.
8. An apparatus for determining connectivity between wells of a reservoir, comprising:
the first layer section dividing module is used for dividing a first oil reservoir to be detected into at least one first layer section;
a first data obtaining module, configured to obtain first measurement point data at a position where each first measurement point in the first interval is located, where the first measurement point data includes: a first elevation depth and a first measured formation pressure of the first measurement point;
the first pressure determining module is used for determining first residual pressure at the position of the first measuring point according to the first actually-measured formation pressure and the determined first pressure measuring reference surface pressure of the first oil reservoir to be measured;
the second interval dividing module is used for dividing a second oil reservoir to be detected into at least one second interval corresponding to the first interval based on the interval dividing result of the first oil reservoir to be detected;
a second data obtaining module, configured to obtain second measurement point data at a position where each second measurement point in the second interval is located, where the second measurement point data includes: a second elevation depth and a second measured formation pressure of the second measurement point;
the second pressure determining module is used for determining second residual pressure at the position of the second measuring point according to the second actually-measured formation pressure and the determined second pressure measuring reference surface pressure of the second oil reservoir to be measured;
and the connectivity determining module is used for determining the inter-well connectivity of the first oil reservoir to be detected and the second oil reservoir to be detected according to the first residual pressure, the first altitude depth, the second residual pressure and the second altitude depth.
9. The apparatus of claim 8, wherein the first station data further comprises at least one of: the first fluidity of the first measuring point and the first water density under the stratum state, and the data of the second measuring point further comprises at least one of the following data: and the second fluidity of the second measuring point and the second water density under the stratum state.
10. The apparatus of claim 9, further comprising:
the first measuring point removing unit is used for removing a first measuring point of which the first fluidity is smaller than a first preset threshold value in the first measuring point data before determining the connectivity of the first oil reservoir to be measured and the second oil reservoir to be measured;
and the first measuring point eliminating unit is used for eliminating the second measuring points of which the second fluidity is smaller than a second preset threshold value in the second measuring point data.
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