CN108266169B - Method and device for detecting oil reservoir exploitation degree of horizontal section - Google Patents
Method and device for detecting oil reservoir exploitation degree of horizontal section Download PDFInfo
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- 238000009826 distribution Methods 0.000 claims description 50
- 238000011897 real-time detection Methods 0.000 claims description 3
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- 238000010796 Steam-assisted gravity drainage Methods 0.000 abstract description 16
- 238000005259 measurement Methods 0.000 abstract description 3
- 239000003921 oil Substances 0.000 description 116
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Abstract
The invention discloses a method and a device for detecting the oil reservoir exploitation degree of a horizontal segment. Wherein, the method comprises the following steps: determining a first temperature of a pipe wall of a production well at a plurality of preset nodes under the condition that a horizontal segment oil deposit does not serve; detecting a second temperature of the well oil reservoir of the production well at a plurality of preset nodes; comparing the first temperature with the second temperature, and determining the detection results of the horizontal segment oil deposit at a plurality of preset nodes, wherein the detection results are used for representing whether the horizontal segment oil deposit is used at the plurality of preset nodes; and determining the exploitation degree of the horizontal-segment oil reservoir according to the detection results of the horizontal-segment oil reservoir at a plurality of preset nodes. The invention solves the technical problem that the measurement result of the usage degree of the SAGD horizontal segment is inaccurate in the prior art.
Description
Technical Field
The invention relates to the field of oilfield development, in particular to a method and a device for detecting the oil reservoir exploitation degree of a horizontal section.
Background
The SAGD technology is a mature technology for developing the ultra-thick oil internationally, represents the highest level of the ultra-thick oil development, and has the ultimate recovery ratio of 50-70 percent, thereby being an effective means for developing the ultra-thick oil at present. The most applied SAGD is the double-horizontal-well SAGD at present, two horizontal wells are distributed in parallel in the forward direction, the upper horizontal well is a steam injection well, and the lower horizontal well is a production well. SAGD production is divided into two major stages, namely a starting stage and a production stage, wherein in the starting stage, high-temperature steam is injected into an upper horizontal well and a lower horizontal well (a steam injection well and a production well, which are called injection and production wells for short) at the same time for circulating preheating, hydraulic and thermal communication between the injection and production wells is established, meanwhile, a steam cavity is formed above the steam injection well due to the steam super-covering effect, and then the production stage is switched to; in the production stage, high-dryness steam is injected from the steam injection well and contacts with the cold oil area to release latent heat of vaporization to heat crude oil, the viscosity of the heated crude oil is reduced, the heated crude oil and steam condensate water flow downwards under the action of gravity and are produced from the horizontal production well, and the steam cavity is continuously expanded in the production process to occupy the space for producing the crude oil.
Because the horizontal segment length (200 ~ 800m) of SAGD horizontal well, it is big that the oil reservoir is influenced by the heterogeneity along the horizontal segment, steam is simultaneously in the pit shaft and the gravity differentiation effect in the oil reservoir for there is the difference in the horizontal segment direction steam uptake size, can cause the intercommunication degree difference between the horizontal well from top to bottom, directly influence the degree of using of horizontal segment oil reservoir, want to improve the horizontal segment and use the degree, must distinguish the horizontal segment that the steam uptake is little or not steam uptake definitely, so that take measures, improve and use the degree.
The current method for determining the usage degree of the SAGD horizontal segment mainly comprises the following three methods. Firstly, a temperature monitoring system is put into a horizontal section, and the oil exploitation condition of the horizontal section is determined according to the change of the monitored horizontal section temperature. The most common monitoring system used today is a thermocouple. The thermocouple is single-point and discontinuous monitoring, 6-10 temperature measuring points are arranged in a horizontal section, the distance is large, the fineness is not enough, and the use condition is difficult to judge only by the monitored underground temperature; although the optical fiber system can realize continuous and real-time monitoring, the service life of the optical fiber is short, the optical fiber needs to be replaced in 1-2 years generally, the cost is high, and the optical fiber system is not universal in field application. And secondly, determining the oil reservoir exploitation condition of the horizontal section of the production well by utilizing the temperature change of the SAGD observation well. Arranging observation wells along a horizontal well section is the most common mode for monitoring the development of a steam cavity of a production well, the arranged observation wells are vertical wells and are distributed at the toe end, the middle end and the heel end of the horizontal section of the SAGD production well, the distance from the production well is 10-20 m, the distance is long, and the steam cavity can be expanded to the position of the observation well after 2-3 years generally due to the fact that the expansion speed of the steam cavity is low, so that the temperature change of the observation well is caused, and the instantaneity is poor. And thirdly, four-dimensional micro-seismic monitoring is adopted, the development characteristics of the SAGD steam cavity are widely applied abroad by adopting the four-dimensional seismic monitoring, the heat distribution condition of the oil reservoir range in a large area can be reflected by the method, the method is high in cost, only the horizontal section utilization degree within a certain period of time can be measured at one time, and the instantaneity is poor.
Aiming at the problem that the measurement result of the SAGD horizontal segment utilization degree in the prior art is inaccurate, an effective solution is not provided at present.
Disclosure of Invention
The embodiment of the invention provides a method and a device for detecting the oil exploitation degree of a horizontal segment oil reservoir, which at least solve the technical problem that the measurement result of the SAGD horizontal segment exploitation degree in the prior art is inaccurate.
According to an aspect of the embodiments of the present invention, there is provided a method for detecting the exploitation degree of a horizontal segment oil reservoir, including: determining a first temperature of a pipe wall of a production well at a plurality of preset nodes under the condition that a horizontal segment oil deposit does not serve; detecting a second temperature of the well oil reservoir of the production well at a plurality of preset nodes; comparing the first temperature with the second temperature, and determining the detection results of the horizontal segment oil deposit at a plurality of preset nodes, wherein the detection results are used for representing whether the horizontal segment oil deposit is used at the plurality of preset nodes; and determining the exploitation degree of the horizontal-segment oil reservoir according to the detection results of the horizontal-segment oil reservoir at a plurality of preset nodes.
Further, acquiring the temperature distribution in the annulus of the horizontal section of the steam injection well; and determining the first temperature of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution in the annular space of the horizontal section of the steam injection well.
Further, acquiring the temperature distribution of the pipe wall of the production well according to the temperature distribution in the annulus of the horizontal section of the steam injection well; and determining a first temperature of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution of the pipe wall of the production well.
Further, a second temperature of the oil reservoir at the predetermined plurality of nodes in the production well is detected in real time.
Further, if the second temperature of the preset plurality of nodes is higher than the first temperature, determining that the oil reservoir in the horizontal segment is used; and if the second temperature is less than or equal to the second temperature, determining that the horizontal segment reservoir is not used.
According to another aspect of the embodiments of the present invention, there is also provided a device for detecting the exploitation degree of a horizontal segment oil reservoir, including: the first determining module is used for determining first temperatures of pipe walls of the production wells at a plurality of preset nodes under the condition that the horizontal-segment oil reservoirs do not use oil; the detection module is used for detecting a second temperature of oil reservoirs in the production well at a plurality of preset nodes; the comparison module is used for comparing the first temperature with the second temperature and determining the detection results of the horizontal segment oil deposit at a plurality of preset nodes, wherein the detection results are used for representing whether the horizontal segment oil deposit is used at the plurality of preset nodes or not; and the second determining module is used for determining the oil utilization degree of the horizontal segment oil deposit according to the detection results of the horizontal segment oil deposit at the preset nodes.
Further, the first determining module includes: the first obtaining submodule is used for obtaining the temperature distribution in the annulus of the horizontal section of the steam injection well; and the first determining submodule is used for determining the first temperature of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution in the horizontal section annular space of the steam injection well.
Further, the first determination submodule includes: the acquiring unit is used for acquiring the temperature distribution of the pipe wall of the production well according to the temperature distribution in the annular space of the horizontal section of the steam injection well; the determining unit is used for determining first temperatures of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution of the pipe wall of the production well.
Further, the detection module includes: and the real-time detection sub-module is used for detecting second temperatures of oil reservoirs at a plurality of preset nodes in the production well in real time.
Further, the alignment module comprises: the first determining module is used for determining that the oil reservoir in the horizontal segment is used if the second temperature of the preset nodes is higher than the first temperature; and the second determination module is used for determining that the horizontal segment oil reservoir is not used if the second temperature is less than or equal to the second temperature.
In the embodiment of the invention, under the condition that the horizontal oil deposit does not use, the first temperature of the pipe wall of the production well at a plurality of preset nodes is determined, the second temperature of the oil deposit in the production well at the plurality of preset nodes is detected, the first temperature is compared with the second temperature to determine the detection results of the horizontal oil deposit at the plurality of preset nodes, and the consumption degree of the horizontal oil deposit is determined according to the detection results of the horizontal oil deposit at the plurality of preset nodes. Above-mentioned scheme is through confirming the condition of using of the horizontal segment oil reservoir at a plurality of predetermined nodes respectively, confirm the degree of using of whole horizontal segment oil reservoir, it is further, confirm the extreme temperature of the oil reservoir in the producing well under the condition that the horizontal segment oil reservoir does not use, and compare through the temperature and the extreme temperature of the oil reservoir in the producing well of actual detection, thereby confirm the condition of using of the horizontal segment oil reservoir at a plurality of predetermined nodes, this scheme is ageing strong, need not special equipment, and is with low costs, and can guarantee the accuracy of detection, thereby the inaccurate technical problem of measuring result of SAGD horizontal segment degree of using among the prior art has been solved.
Drawings
The accompanying drawings, which are included to provide a further understanding of the invention and are incorporated in and constitute a part of this application, illustrate embodiment(s) of the invention and together with the description serve to explain the invention without limiting the invention. In the drawings:
FIG. 1 is a flow chart of a method for detecting a level segment reservoir production level according to an embodiment of the present invention; and
FIG. 2 is a schematic diagram of a horizontal segment reservoir production level detection apparatus according to an embodiment of the present invention.
Detailed Description
In order to make the technical solutions of the present invention better understood, 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 only a part of the embodiments of the present invention, 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 invention.
It should be noted that the terms "first," "second," and the like in the description and claims of the present invention and in the drawings described above are used for distinguishing between similar elements and not necessarily for describing a particular sequential or chronological order. It is to be understood that the data so used is interchangeable under appropriate circumstances such that the embodiments of the invention described herein are capable of operation in sequences other than those illustrated or described herein. Furthermore, the terms "comprises," "comprising," and "having," and any variations thereof, are intended to cover a non-exclusive inclusion, such that a process, method, system, article, or apparatus that comprises a list of steps or elements is not necessarily limited to those steps or elements expressly listed, but may include other steps or elements not expressly listed or inherent to such process, method, article, or apparatus.
Example 1
In accordance with an embodiment of the present invention, there is provided an embodiment of a method for detecting a level of oil production, it should be noted that the steps illustrated in the flowchart of the accompanying drawings may be implemented in a computer system such as a set of computer executable instructions and that, although a logical order is illustrated in the flowchart, in some cases the steps illustrated or described may be executed in an order different than that illustrated herein.
Fig. 1 is a flowchart of a method for detecting a horizontal segment reservoir production extent according to an embodiment of the present invention, as shown in fig. 1, the method includes the following steps:
step S102, determining a first temperature of the pipe wall of the production well at a plurality of preset nodes under the condition that the horizontal segment oil deposit does not use.
Specifically, the preset nodes may be sampling nodes arranged for detecting the horizontal segment oil deposit, and in an alternative embodiment, the steam injection well and the production well may determine nodes corresponding to the preset nodes in the horizontal segment. For example, typically a production well horizontal interval is 500m to 1000m, and in an alternative embodiment, a node may be provided every 5m to determine the first temperature.
Here, since the first temperature is obtained when the horizontal reservoir is not used, the first temperature is a limit temperature, that is, a maximum temperature that can be reached when the horizontal reservoir is not used.
Step S104, detecting a second temperature of the oil reservoir in the production well at a plurality of preset nodes.
Specifically, in the sagd (steam Assisted Gravity drainage) oil recovery technology, the oil reservoir in the well of the production well is a mixture of crude oil and steam condensate heated by high-dryness steam, so that the oil reservoir in the well of the production well at the second temperature is also a mixture of crude oil and steam condensate heated by high-dryness steam.
And S106, comparing the first temperature with the second temperature, and determining the detection results of the horizontal segment oil deposit at a plurality of preset nodes, wherein the detection results are used for representing whether the horizontal segment oil deposit is used at the plurality of preset nodes or not.
It should be noted here that if the steam injection well and the production well communicate with each other at a node, heat is transferred by convection between the two wells at the node, and the two well pipe walls at the node have the same temperature; if the steam injection well and the production well are not communicated at a certain node, the corresponding well bores of the two wells at the node conduct heat and transfer heat, and the temperature of the production well corresponding to the node is lower than the wall temperature of the steam injection well; the steam injection well and the production well are communicated at a certain node, the oil deposit at the communicated node can be used, if the oil is hidden in the whole horizontal section and is not used, the communicated node is not arranged between the steam injection well and the production well, the heat conduction is only carried out, and according to the heat conduction theory, the temperature at the pipe wall of the production well is the limit temperature which is not used by the oil deposit at the horizontal section of the production well. Therefore, whether the preset nodes are used or not can be determined by comparing the first temperature with the second temperature.
And S108, determining the oil utilization degree of the horizontal segment oil reservoir according to the detection results of the horizontal segment oil reservoir at a plurality of preset nodes.
In an alternative embodiment, if 200 nodes are preset in the horizontal segment oil reservoir to be measured, if the detection results of 140 nodes are active and the detection results of 60 nodes are inactive, the utilization rate of the horizontal segment oil reservoir is 70%.
Therefore, in the above embodiments of the present application, it is determined that, under the condition that the horizontal oil reservoir does not use oil, the first temperature of the pipe wall of the production well at the preset plurality of nodes is detected, the second temperature of the oil reservoir in the production well at the preset plurality of nodes is detected, the first temperature is compared with the second temperature to determine the detection results of the horizontal oil reservoir at the preset plurality of nodes, and the consumption degree of the horizontal oil reservoir is determined according to the detection results of the horizontal oil reservoir at the preset plurality of nodes. Above-mentioned scheme is through confirming the condition of using of the horizontal segment oil reservoir at a plurality of predetermined nodes respectively, confirm the degree of using of whole horizontal segment oil reservoir, it is further, confirm the extreme temperature of the oil reservoir in the producing well under the condition that the horizontal segment oil reservoir does not use, and compare through the temperature and the extreme temperature of the oil reservoir in the producing well of actual detection, thereby confirm the condition of using of the horizontal segment oil reservoir at a plurality of predetermined nodes, this scheme is ageing strong, need not special equipment, and is with low costs, and can guarantee the accuracy of detection, thereby the inaccurate technical problem of measuring result of SAGD horizontal segment degree of using among the prior art has been solved.
Optionally, according to the above embodiment of the present application, in step S102, determining a first temperature of a pipe wall of the production well at a plurality of preset nodes under the condition that the horizontal segment reservoir is not used, includes:
and S1021, acquiring the temperature distribution in the annulus of the horizontal section of the steam injection well.
Specifically, the temperature distribution in the horizontal section annulus of the steam injection well is used for representing the temperature at each preset node in the horizontal section annulus of the steam injection well.
In an alternative embodiment, the temperature distribution in the annulus of the horizontal section of the steam injection well can be obtained as follows. According to the law of conservation of momentum, a control equation of steam pressure drop gradient in a pipeline at the horizontal section of the steam injection well can be established, and the total pressure gradient consists of gravity gradient, friction gradient and acceleration gradient, namely:
-dp＝(pf+pa+pg)dz (1)
wherein: frictional resistance loss per unit length of Pf; pa acceleration pressure drop gradient loss; pg pressure loss per unit length due to gravity.
① frictional drag loss per unit length:
fm-coefficient of friction resistance of wet steam (i.e., high quality steam injected by the steam injection well) fluid; ρ m- -density of wet steam fluid, kg/m;
vm- -average velocity of the wet vapor stream, m/s; d-pipeline equivalent diameter, m;
② pressure loss due to gravity per unit length:
pg＝ρmgsinθ (3)
theta-inclination of the well, rad.
③ loss of acceleration-drop gradient:
a- -cross-sectional flow area, m 2; g- -mass flow of wet steam fluid, kg/s;
therefore, the pressure loss in the line can be expressed as:
while
p＝ρRT (7)
Obtaining:
therefore:
substituting to obtain:
finishing to obtain:
and the density of the wet steam can be represented by the comprehensive dryness of the liquid water and the saturated water steam inside:
ρm＝(1-x)ρl+xρg(13)
wherein: ρ l- -density of water, kg/m 3; ρ g- -density of saturated water vapor, kg/m 3; x-dryness of steam.
The density of water generally varies little with pressure, mainly the density of water vapor varies greatly with pressure. The relationship between the density and the pressure of the saturated water vapor can be obtained by a preset regression equation of the density, the pressure and the temperature of the saturated water vapor, and can be expressed as: rhog(ii), (f), (p), (14), specifically, as shown in table oneThe table is a schematic of a regression equation of saturated water vapor density versus pressure.
Watch 1
Thereby obtaining:
ρm＝(1-x)ρl+xf(p) (15)
substituting the overall expression yields:
in actual calculation, the density distribution of each segment can be calculated first, and then the pressure distribution can be calculated:
ρm＝(1-x)ρl+xρg(17)
the initial injection steam pressure of the steam injection well is P0, the steam injection temperature is T0, and the temperature distribution Tii in the annular space of the horizontal section of the steam injection well can be obtained according to the calculated pressure Pi of the horizontal section of the steam injection well.
And S1023, determining the first temperature of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution in the annular space of the horizontal section of the steam injection well.
Specifically, the distance between the steam injection well and the production well is usually 3m to 8m, so that the first temperature of the wall of the production well at a plurality of preset nodes can be determined after the temperature distribution in the annulus of the horizontal section of the steam injection well is obtained through the heat conduction theory.
According to the method, the first temperature of the pipe wall of the production well at the preset nodes is determined through the heat conduction theory according to the temperature distribution in the annular space of the horizontal section of the steam injection well.
Optionally, according to the foregoing embodiment of the present application, in step S1023, determining a first temperature of a tubular wall of the production well at a plurality of preset nodes according to a temperature distribution in an annulus of a horizontal segment of the steam injection well, including:
and S1025, acquiring the temperature distribution of the pipe wall of the production well according to the temperature distribution in the annulus of the horizontal section of the steam injection well.
It should be noted here that, since the steam injection well and the production well are not communicated when the oil reservoir is not used passively, only heat conduction is performed between the steam injection well and the production well, and therefore the temperature distribution of the pipe wall of the production well can be obtained through the existing heat conduction theory according to the temperature distribution in the annular space of the horizontal section of the steam injection well.
In an optional embodiment, the density of wet steam in the horizontal section of the steam injection well is obtained according to the relation between the steam pressure gradient in the horizontal section of the steam injection well and the gravity gradient, the friction gradient and the acceleration gradient of the steam; determining pressure distribution in a shaft of the steam injection well according to the density of the wet steam and the relation between the preset saturated steam density and the pressure; and determining the temperature distribution in the annulus of the horizontal section of the steam injection well according to the pressure distribution in the shaft of the steam injection well. For example, the temperature profile of the wall of the production well may be determined by:
in the steam injection process of the steam injection well, the horizontal well shaft conducts heat to an oil layer by means of heat conduction to dissipate heat, the temperature of the oil layer rises, and for one section, a heat transfer equation can be written:
the temperature distribution in the oil layer during heat removal can be determined by the following equation:
based on equations (19) and (20), the heat dissipation heat flow density can be obtained as:
wherein:
tii-the temperature in the annulus at the horizontal section of the steam injection well, DEG C; ri-i m reservoirs, m, below the steam injection well;
tr-reservoir temperature at i m below the steam injection well, deg.C; λ e-oil layer thermal conductivity, W/(m.K);
a-oil layer thermal diffusivity, m 2/s;
λ -time of 1 day, s; t-days of heating, d.
Wherein:
the series expansion can be expressed as:
when the steam injection temperature of the steam injection well is constant after the steam injection time is longer (gamma/t is less than 0.01):
according to the annular space temperature Tii in the horizontal section pipe of the steam injection well obtained in the step S1021, the heat flow density of the horizontal section heat radiation is obtained as follows:
the temperature distribution in the reservoir can thus be obtained, i.e. the temperature distribution at the wall of the production well is:
since the oil layer outside the horizontal section of the horizontal well exists in a mixed state of rock, oil, water, and the like, the thermal conductivity λ e of the oil layer can be calculated by the following formula:
wherein a, b, c, d and e are coefficients, Sw is the water saturation (decimal), So is the oil saturation (decimal),
the oil layer porosity (decimal) and T is the temperature (. degree. C.). A set of coefficient values that can be obtained by multiple regression: 4.318, 4.883, 0.474, 0.987 and 0.0024.
Step S1027, determining a first temperature of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution of the pipe wall of the production well.
The temperature distribution of the pipe wall of the production well can determine the temperature of the pipe wall of the production well at different nodes, so that the first temperature of the pipe wall of the production well at a plurality of preset nodes can be directly determined after the temperature distribution of the pipe wall of the production well is obtained.
Optionally, according to the above embodiment of the present application, in step S104, detecting a second temperature of the horizontal section of the production well at a plurality of preset nodes includes: and detecting a second temperature of oil hidden in the production well at a plurality of preset nodes in real time.
Specifically, the second temperature of the oil reservoir at the preset nodes in the production well can be measured by a thermocouple or an optical fiber testing system which is arranged below the horizontal section of the production well.
Specifically, according to the scheme, the second temperatures of the oil reservoirs in the production well at the preset nodes are detected in real time, so that the real-time property of the oil reservoir exploitation degree of the horizontal section is detected, and the detection accuracy is further improved.
Optionally, according to the above embodiment of the present application, in step S106, comparing the first temperature with the second temperature, and determining the detection results of the horizontal segment oil reservoir at the preset multiple nodes, includes:
in step S1061, if the second temperature of the preset plurality of nodes is greater than the first temperature, it is determined that the horizontal segment oil reservoir is used.
In step S1063, if the second temperature is less than or equal to the second temperature, it is determined that the horizontal segment oil reservoir is not used.
In view of the above, the method of the present application compares the second temperature with the corresponding first temperature, that is, the limit temperature, to determine whether the oil reservoir is used in the horizontal segment at the preset node.
Example 2
According to an embodiment of the present invention, an embodiment of a device for detecting the mobility of a horizontal reservoir is provided, and fig. 2 is a schematic diagram of the device for detecting the mobility of a horizontal reservoir according to the embodiment of the present invention, as shown in fig. 2, the device includes:
the first determining module 20 is configured to determine a first temperature of a wall of a production well at a plurality of predetermined nodes when a horizontal segment of the reservoir is not being used.
A detection module 22 for detecting a second temperature of the well oil reservoir of the production well at a plurality of predetermined nodes.
And a comparison module 24, configured to compare the first temperature with the second temperature, and determine a detection result of the horizontal segment oil reservoir at a plurality of preset nodes, where the detection result is used to represent whether the horizontal segment oil reservoir is used at the plurality of preset nodes.
It should be noted here that if the steam injection well and the production well communicate with each other at a node, heat is transferred by convection between the two wells at the node, and the two well pipe walls at the node have the same temperature; if the steam injection well and the production well are not communicated at a certain node, the corresponding well bores of the two wells at the node conduct heat and transfer heat, and the temperature of the production well corresponding to the node is lower than the wall temperature of the steam injection well; the steam injection well and the production well are communicated at a certain node, the oil deposit at the communicated node can be used, if the oil is hidden in the whole horizontal section and is not used, the communicated node is not arranged between the steam injection well and the production well, the heat conduction is only carried out, and according to the heat conduction theory, the temperature at the pipe wall of the production well is the limit temperature which is not used by the oil deposit at the horizontal section of the production well. Therefore, whether the preset nodes are used or not can be determined by comparing the first temperature with the second temperature.
And the second determining module 26 is configured to determine the mobility degree of the horizontal segment oil reservoir according to the detection results of the horizontal segment oil reservoir at the preset nodes.
Therefore, in the above embodiment of the application, it is determined by the first determining module that the first temperature of the pipe wall of the production well at the preset plurality of nodes is not used under the condition that the horizontal segment oil deposit is not used, the second temperature of the oil deposit in the production well at the preset plurality of nodes is detected by the detecting module, the first temperature and the second temperature are compared by the comparing module, the detection result of the horizontal segment oil deposit at the preset plurality of nodes is determined by the second determining module, and the consumption degree of the horizontal segment oil deposit is determined according to the detection result of the horizontal segment oil deposit at the preset plurality of nodes. Above-mentioned scheme is through confirming the condition of using of the horizontal segment oil reservoir at a plurality of predetermined nodes respectively, confirm the degree of using of whole horizontal segment oil reservoir, it is further, confirm the extreme temperature of the oil reservoir in the producing well under the condition that the horizontal segment oil reservoir does not use, and compare through the temperature and the extreme temperature of the oil reservoir in the producing well of actual detection, thereby confirm the condition of using of the horizontal segment oil reservoir at a plurality of predetermined nodes, this scheme is ageing strong, need not special equipment, and is with low costs, and can guarantee the accuracy of detection, thereby the inaccurate technical problem of measuring result of SAGD horizontal segment degree of using among the prior art has been solved.
Optionally, according to the foregoing embodiment of the present application, the first determining module includes:
and the first obtaining submodule is used for obtaining the temperature distribution in the annular space of the horizontal section of the steam injection well.
And the first determining submodule is used for determining the first temperature of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution in the horizontal section annular space of the steam injection well.
Optionally, according to the above embodiment of the present application, the first determining sub-module includes:
and the acquisition unit is used for acquiring the temperature distribution of the pipe wall of the production well according to the temperature distribution in the annular space of the horizontal section of the steam injection well.
The determining unit is used for determining first temperatures of the pipe wall of the production well at a plurality of preset nodes according to the temperature distribution of the pipe wall of the production well.
Optionally, according to the above embodiment of the present application, the detection module includes:
and the real-time detection sub-module is used for detecting second temperatures of oil reservoirs at a plurality of preset nodes in the production well in real time.
Optionally, according to the embodiment of the present application, the comparing module includes:
and the first determining module is used for determining that the horizontal segment oil reservoir is used if the second temperature of the preset nodes is greater than the first temperature.
And the second determination module is used for determining that the horizontal segment oil reservoir is not used if the second temperature is less than or equal to the second temperature.
The above-mentioned serial numbers of the embodiments of the present invention are merely for description and do not represent the merits of the embodiments.
In the above embodiments of the present invention, the descriptions of the respective embodiments have respective emphasis, and for parts that are not described in detail in a certain embodiment, reference may be made to related descriptions of other embodiments.
In the embodiments provided in the present application, it should be understood that the disclosed technology can be implemented in other ways. The above-described embodiments of the apparatus are merely illustrative, and for example, the division of the units may be a logical division, and in actual implementation, there may be another division, for example, multiple 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, units or modules, and may be in an electrical or other form.
The units described as separate parts may or may not be physically separate, and parts displayed as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of units. Some or all of the units can be selected according to actual needs to achieve the purpose of the solution of the embodiment.
In addition, functional units in the embodiments of the present invention may be integrated into one processing unit, or each unit may exist alone physically, or two or more units are integrated into one unit. The integrated unit can be realized in a form of hardware, and can also be realized in a form of a software functional unit.
The integrated unit, if implemented in the form of a software functional unit and sold or used as a stand-alone product, may be stored in a computer readable storage medium. Based on such understanding, the technical solution of the present invention may be embodied in the form of a software product, which is stored in a storage medium and includes instructions for causing a computer device (which may be a personal computer, a server, or a network device) to execute all or part of the steps of the method according to the embodiments of the present invention. And the aforementioned storage medium includes: a U-disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a removable hard disk, a magnetic or optical disk, and other various media capable of storing program codes.
The foregoing is only a preferred embodiment of the present invention, and it should be noted that, for those skilled in the art, various modifications and decorations can be made without departing from the principle of the present invention, and these modifications and decorations should also be regarded as the protection scope of the present invention.
Claims (8)
1. A method for detecting the exploitation degree of a horizontal-segment oil reservoir is characterized by comprising the following steps:
determining a first temperature of a pipe wall of a production well at a plurality of preset nodes under the condition that the horizontal segment oil deposit does not serve;
detecting a second temperature of the oil reservoir in the production well at a plurality of preset nodes, wherein the plurality of preset nodes are sampling nodes arranged for detecting a horizontal segment oil reservoir;
comparing the first temperature with the second temperature, and determining a detection result of the oil in the horizontal segment hidden at the preset nodes, wherein the detection result is used for representing whether the oil in the horizontal segment is hidden at the preset nodes or not;
determining the oil utilization degree of the horizontal segment oil deposit according to the detection results of the horizontal segment oil deposit at the preset nodes;
determining a first temperature of a wall of a production well at a plurality of predetermined nodes without mobilization of the horizontal segment reservoir, comprising:
acquiring the temperature distribution in the annulus of the horizontal section of the steam injection well;
and determining a first temperature of the pipe wall of the production well at the preset plurality of nodes according to the temperature distribution in the horizontal section annulus of the steam injection well.
2. The method of claim 1, wherein determining a first temperature of a tubular wall of the production well at the predetermined plurality of nodes from a temperature distribution within a horizontal annulus of the steam injection well comprises:
acquiring the temperature distribution of the pipe wall of the production well according to the temperature distribution in the annulus of the horizontal section of the steam injection well;
and determining a first temperature of the pipe wall of the production well at the preset plurality of nodes according to the temperature distribution of the pipe wall of the production well.
3. The method of claim 1, wherein detecting a second temperature of the well oil reservoir of the production well at the predetermined plurality of nodes comprises:
and detecting a second temperature of the well oil reservoir of the production well at the preset nodes in real time.
4. The method according to any one of claims 1 to 3, wherein comparing the first temperature with the second temperature to determine the detection result of the oil sump at the predetermined plurality of nodes comprises:
if the second temperature of the preset nodes is higher than the first temperature, determining that the oil reservoir in the horizontal segment is used;
and if the second temperature is less than or equal to the second temperature, determining that the horizontal segment reservoir is not used.
5. A detection device for the exploitation degree of a horizontal-segment oil reservoir is characterized by comprising:
the first determining module is used for determining a first temperature of the pipe wall of the production well at a plurality of preset nodes under the condition that the horizontal segment oil deposit does not serve;
the detection module is used for detecting second temperatures of oil reservoirs in the production well at a plurality of preset nodes, wherein the plurality of preset nodes are sampling nodes arranged for detecting a horizontal segment oil reservoir;
the comparison module is used for comparing the first temperature with the second temperature and determining the detection result of the oil in the horizontal segment hidden at the preset nodes, wherein the detection result is used for representing whether the oil in the horizontal segment is hidden at the preset nodes or not;
the second determining module is used for determining the oil utilization degree of the horizontal segment oil deposit according to the detection results of the horizontal segment oil deposit at the preset nodes;
the first determining module includes:
the first obtaining submodule is used for obtaining the temperature distribution in the annulus of the horizontal section of the steam injection well;
and the first determining submodule is used for determining the first temperature of the pipe wall of the production well at the preset nodes according to the temperature distribution in the horizontal section annulus of the steam injection well.
6. The apparatus of claim 5, wherein the first determination submodule comprises:
the acquisition unit is used for acquiring the temperature distribution of the pipe wall of the production well according to the temperature distribution in the annular space of the horizontal section of the steam injection well;
the determining unit is used for determining a first temperature of the pipe wall of the production well at the preset nodes according to the temperature distribution of the pipe wall of the production well.
7. The apparatus of claim 5, wherein the detection module comprises:
and the real-time detection submodule is used for detecting a second temperature of the oil reservoir in the production well at the preset nodes in real time.
8. The apparatus of any one of claims 5 to 7, wherein the alignment module comprises:
the first determining module is used for determining that the horizontal segment oil reservoir is used if the second temperature of the preset nodes is higher than the first temperature;
and the second determination module is used for determining that the horizontal segment oil deposit does not draw if the second temperature is less than or equal to the second temperature.
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