CN115471351A - Method and device for quantitatively determining water coming from deep-layer dissolved-fluid reservoir - Google Patents

Abstract

The invention provides a method for quantitatively determining the water coming from a deep-layer dissolved-fluid reservoir, which comprises the following steps: an incoming water direction determining step: analyzing to obtain an incoming water direction result according to a static connectivity analysis result of a well group to be analyzed; a communication degree calculating step: determining a bottom water position and an oil well perforation position, setting initial values of conductivity and communication volume, and calculating to obtain communication degree results of the well group to be analyzed at different production moments through production history fitting; calculating the water inflow amount: and calculating the inflow water quantity by combining the inflow water quantity calculation model based on the communication degree result obtained through the normalization processing. The invention utilizes the production dynamic data of the injection and production well group, calculates the communication degree quantitatively through fine history fitting, calculates the inflow water distribution through normalization communication degree, provides the well group treatment direction, forms the inflow water treatment and adjustment scheme of the injection and production well group, and realizes the differentiated and quantitative inflow water treatment of the injection and production well group of the solution-cut oil reservoir.

Description

Method and device for quantitatively determining water coming from deep-layer dissolved-fluid reservoir

Technical Field

The invention relates to the technical field of carbonate rock solution reservoir development, in particular to a method and a device for quantitatively determining the water coming from a deep solution reservoir.

Background

The fracture and the bottom water increase the complexity of water injection development of the solution reservoir, and greatly influence the effect of water injection development of the deep solution reservoir. In the middle and later stages of the development of the solution-breaking oil reservoir, in order to keep the formation energy, part of oil wells with poor development effect and high water content need to be re-injected, so that the situation that water injection points to the oil wells along a few transverse cracks is generated.

Because the physical properties of the deep dissolved-water-cut reservoir are complex and the heterogeneity is strong, the general water injection not only can not obtain high yield, but also can aggravate the injection-production contradiction, seriously influences the yield and the stable production capacity of the oil well, ensures the differentiated balanced water injection of each interval and each well, and is a key problem of the water injection design of the deep dissolved-water-cut reservoir. In addition, as the solution reservoir development progresses, bottom water and injected water preferentially flow along certain channels, displacing the crude oil around the channels. After the oil well encounters water, the crude oil in the channel is replaced by formation water or injected water with smaller flow resistance, the channel is called a water flow channel, then the crude oil communicated with the water flow channel is difficult to drive continuously, residual oil shielded by a high flow guide channel is formed, the subsequent water can flow out by how much, and the well group is injected with water, so that the failure or low-efficiency water injection well group is called.

The control and treatment of the flow of the fracture water directly controls the development effect of the whole dissolved-fluid reservoir, and effectively reduces the water channeling in the fracture is a core technology for treating the injection-production well group of the deep dissolved-fluid reservoir. Most of the treatment of the injection and production well group focuses on the water control content in the aspects of water control and precipitation, and the benefit of water injection development is improved to a certain extent due to the reduction of water production.

Practice proves that the water control effect is directly related to the incoming water direction, the incoming water quantity and the incoming water strength, so that whether the water produced by an oil well is from bottom water or manually injected water needs to be known, the type and the volume of the water plugging material and the injection position of the plugging agent can be determined in a targeted manner only by determining the incoming water direction and the incoming water quantity and calculating the incoming water strength according to the incoming water direction and the incoming water quantity, a water flow channel is changed and residual oil is displaced, and the water wave coefficient and the water injection effect are improved to the greatest extent as possible.

The prior art provides a water increase and discharge amount calculation system based on water transfer and water saving measures and a method (CN 103413034A), and the water increase and discharge amount calculation system comprises a data management module, a data standardization module, a water increase and discharge amount calculation module, a calculation result output and display module and the like.

The method for forecasting the inflow flow of the reservoir in the prior art (CN 103164628A) discloses a continuous smoothing method of flow subsection forecasting data on time nodes, which comprises the steps of firstly determining the minimum time and the maximum time interval of the required flow, then obtaining integral distribution of the subsection forecasting data along the interval by adopting cumulative summation, then carrying out spline interpolation on the data after integral to obtain the function distribution of the integral on the interval, and then deriving the function at each time to obtain the forecasting inflow flow process line.

In the prior art, a regional water resource optimal allocation method (CN 106529166A) based on a MAEPSO algorithm provides a regional water resource optimal allocation method based on a MAEPSO algorithm, so that global optimization is realized, the calculation efficiency is improved, and the calculation requirement of a selected multi-target optimal allocation scheme of a water resource system is met.

It can be seen that the related technical content of the method for determining the water inflow of the deep-layer fractured-fluid reservoir is not involved in the prior art, and for the above situation, the invention provides a method and a device for quantitatively determining the water inflow of the deep-layer fractured-fluid reservoir.

Disclosure of Invention

In order to solve the above problems, the present invention provides a method for quantitatively determining the incoming water of a deep-layer solution reservoir, the method comprising:

an incoming water direction determining step: analyzing to obtain an incoming water direction result according to a static connectivity analysis result of a well group to be analyzed;

and a communication degree calculation step: determining a bottom water position and an oil well perforation position, setting initial values of conductivity and communication volume, and calculating to obtain communication degree results of the well group to be analyzed at different production moments through production history fitting;

calculating the water inflow amount: and calculating the water inlet quantity by combining with the water inlet quantity calculation model based on the communication degree result obtained through normalization processing.

According to an embodiment of the present invention, the incoming water direction determining step specifically includes the following steps:

data collection and analysis steps: selecting an injection and production well group with a geological background of an interrupted solution reservoir as an alternative well group, collecting production dynamic data and seismic data of the alternative well group, and removing abnormal data points to obtain historical production data.

According to an embodiment of the present invention, the water direction determining step specifically includes the following steps:

a static communication analysis step: and carrying out reservoir carving of the alternative well group based on the seismic data in the historical production data, and analyzing the static connectivity among the reservoirs to obtain the analysis result of the static connectivity.

According to an embodiment of the present invention, the incoming water direction determining step specifically includes the following steps:

well group determination: and carrying out production dynamic analysis on the alternative well group based on the production dynamic data in the historical production data, determining whether the alternative well group is connected or not, deleting the disconnected well numbers, and determining the well group to be analyzed.

According to an embodiment of the present invention, the analyzing the incoming water direction result specifically comprises the following steps:

and analyzing the communication condition of the reservoir body and the bottom water based on the static connectivity analysis result, determining the mainly communicated oil-water well, defining the possible mainly incoming water direction, determining that the incoming water is mainly the bottom water or the injected water or both.

According to one embodiment of the invention, the connectivity results include, but are not limited to: conductivity and communication volume between the water injection well and the oil production well and between the oil production well and bottom water.

According to one embodiment of the invention, the inflow water amount calculation model comprises the following formula:

Q _in ＝Q _out *A _ijz *T _ijz

wherein Q is _in Denotes the amount of incoming water, Q _out Indicating the volume of fluid produced during the phase, A _ijz Denotes conductivity, T _ijz Representing the connected volume, i representing the injection well, j representing the production well, z representing the bottom water.

According to one embodiment of the invention, the method further comprises:

water treatment step: and proposing a water treatment measure and a water treatment scheme based on the water coming direction result and the water coming quantity.

According to another aspect of the invention, there is also provided a storage medium containing a series of instructions for carrying out the steps of the method as described in any one of the above.

According to another aspect of the present invention, there is also provided an apparatus for quantitatively determining the water from a deep-fractured reservoir, the method for quantitatively determining the water from the deep-fractured reservoir as described in any one of the above, the apparatus comprising:

the water direction determining module is used for analyzing to obtain a water direction result according to the static connectivity analysis result of the well group to be analyzed;

the communication degree calculation module is used for determining the bottom water position and the oil well perforation position, setting the initial values of the conductivity and the communication volume, and calculating to obtain the communication degree results of the well group to be analyzed at different production moments through production history fitting;

and the water inlet quantity calculation module is used for calculating the water inlet quantity by combining the water inlet quantity calculation model based on the communication degree result obtained through the normalization processing.

The method and the device for quantitatively determining the water inflow of the deep-layer dissolved oil reservoir utilize the production dynamic data of the injection and production well group, perform fine history fitting, quantitatively calculate the communication degree, and calculate the water inflow distribution through normalizing the communication degree.

Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by the practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.

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 specification, illustrate embodiments of the invention and together with the description serve to explain the principles of the invention and not to limit the invention. In the drawings:

FIG. 1 illustrates a flow diagram of a method for quantitatively determining the incoming water of a deep-seated solution reservoir, according to one embodiment of the present invention;

FIG. 2 shows a flow diagram of a method for quantitatively determining the incoming water of a deep-cut solution reservoir according to another embodiment of the present invention;

FIG. 3 shows a TH12120 well group integrated development plot, according to one embodiment of the present invention;

FIG. 4 shows a TH12120 well group reservoir sculpting result chart according to one embodiment of the present invention;

FIG. 5 shows a TH12120 well group fracture tracking and identification result chart according to one embodiment of the present invention;

FIG. 6 shows a graph of a TH12120 well group interwell conductivity calculation according to one embodiment of the present invention;

FIG. 7 shows a graph of the results of calculations of interwell connected volumes for a group of TH12120 wells, according to one embodiment of the present invention;

FIG. 8 shows a TH12120 well group incoming water volume profile according to an embodiment of the present invention;

FIG. 9 shows a TH12437X well group integrated development plot, in accordance with an embodiment of the present invention;

figure 10 shows a TH12437X well group reservoir sculpting and fracture tracking result graph according to one embodiment of the invention;

FIG. 11 is a graph illustrating the results of a TH12437X well group cross-well connectivity calculation, in accordance with an embodiment of the present invention;

FIG. 12 shows a TH12437X well group incoming water volume profile according to an embodiment of the invention; and

fig. 13 shows a block diagram of an apparatus for quantitatively determining the incoming water of a deep-fractured fluid reservoir according to an embodiment of the invention.

Detailed Description

In order to make the objects, technical solutions and advantages of the present invention more apparent, the following embodiments of the present invention are further described in detail with reference to the accompanying drawings.

High angle crack development is a major geological feature of deep-seated solution at the periphery of the taheu and at the north of the townra basin. After the stratum is buried to a certain degree, the development degree of the horizontal fracture is obviously lower than that of the high-angle fracture, and the description result of the north-oriented and other deep dissolved-water reservoirs also proves that the deep dissolved-water reservoirs account for more than 72 percent of the development of the high-angle fractures, reservoir development is primarily controlled by fractures, with collapse forming a small number of caverns, collapsed rock pieces making up a portion of the breccia, and fractured zones with a large number of tectonic fractures being the most three reservoir spaces. Because of the obedience relationship between the cracks and the fractures, the development of the cracks is controlled by the fracture development rule, the trend of the cracks is basically consistent with the fracture trend, the cracks not only serve as flow passages of carbonate oil and gas reservoirs, but also are one of the main types of reservoir spaces (Luxinshu, huwenge, wang Yan, etc., carbonate fracture reservoir characteristics and development practices [ J ] in the tower river region, oil and gas geology 2015, 36 (3): 347-09).

Bottom water development is another important geological feature of deep-level fractured solution reservoirs. Researches prove that the volume of bottom water in the northern region of the Tarim basin is about ten times to dozens of times of the reserve volume generally, the bottom water is developed, on one hand, the water injection cost is saved, and the effects of stratum energy and depletion development are ensured. In another aspect. A large number of high-angle fractures develop in deep oil reservoirs to communicate with bottom water, the bottom water is high in energy and large in volume, serious water channeling is generated along the high-angle fractures, an oil well can quickly see water, the development effect of the dissolved-water reservoir is directly reduced (Tang sea, juan, rong Yushuai, liwavelet, tahe dissolved-water reservoir typical dissolved-water injection displacement rule and residual oil distribution characteristics [ J ], oil-gas geology and recovery ratio, 2018, 25 (3): 95-06), and the dual action of fully utilizing the bottom water energy is always the difficult point and hot point problem of the bottom water reservoir development.

The fracture and the bottom water increase the complexity of water injection development of the dissolved-solution reservoir, and greatly influence the water injection development effect of the deep dissolved-solution reservoir. In the middle and later stages of the development of the solution reservoir, in order to keep the formation energy, partial oil wells with poor development effect and high water content need to be re-injected, so that the situation that water injection points to the oil wells along a few transverse fractures is generated (Liubazao, zuilianjie, lizongjie, and the like, and the space carving and quantitative description technology of the ultra-deep solution reservoir in the northern region [ J ]. Petroleum institute, 2020, 40 (4): 412-09). Because the physical properties of the deep dissolved-water-cut reservoir are complex and the heterogeneity is strong, the general water injection not only can not obtain high yield, but also can aggravate the injection-production contradiction, seriously influences the yield and the stable production capacity of the oil well, ensures the differentiated balanced water injection of each interval and each well, and is a key problem of the water injection design of the deep dissolved-water-cut reservoir. In addition, as the solution reservoir development progresses, bottom water and injected water preferentially flow along certain channels, displacing the crude oil around the channels.

After the oil well encounters water, the crude oil in the channel is replaced by formation water or injected water with smaller flow resistance, the channel is called a water flow channel, then the crude oil communicated with the water flow channel is difficult to drive continuously, residual oil shielded by a high flow guide channel is formed, the subsequent water can flow out by how much, and the well group is injected with water, so that the failure or low-efficiency water injection well group is called.

The control and treatment of the flow of the fracture water directly controls the development effect of the whole dissolved-fluid reservoir, and effectively reduces the water channeling in the fracture is a core technology for treating the injection-production well group of the deep dissolved-fluid reservoir. Most of the treatment of the injection and production well group focuses on the water control content in the aspects of water control and precipitation, and the benefit of water injection development is improved to a certain extent due to the reduction of water production.

Practice proves that the water control effect is directly related to the incoming water direction, the incoming water quantity and the incoming water strength, so that the condition that the water produced by an oil well is from bottom water or manually injected water needs to be known, the type and the volume of the water plugging material and the injection position of the plugging agent can be determined in a targeted manner only by determining the incoming water direction and the incoming water quantity and calculating the incoming water strength according to the incoming water direction and the incoming water quantity, a water flow channel is changed and residual oil is displaced, and the water fluctuation coefficient and the water injection effect are improved to the greatest extent possible.

In addition, the deep dissolved-water reservoir with bottom water development has short development time and less experience, and due to the unique geological characteristics of the dissolved-water reservoir, the oil-water flow capacity along the longitudinal direction is obviously higher than that along other directions, and strong bottom water energy and high-angle cracks develop, which all generate huge development risks, which show that the development effect is rapidly reduced once an oil well encounters water. According to field statistics, the recovery ratio of the oil reservoir development is mostly about 10%, an obvious water flow channel and a large amount of residual oil exist between a bottom water body in the oil reservoir and an oil extraction well group, and the residual oil is used as a material basis for treatment of an injection and extraction well group.

From the production process, the connectivity between the oil well and the bottom water and between the oil well and the water well is a restrictive factor on the oil-water motion rule, the water content rising rule, the water drive recovery rate and the like, so the difference of the water incoming direction, the water incoming quantity and the water incoming strength of the oil well is determined on the basis of the historical fitting of a well group according to the connectivity degree between the oil well and the natural water body and the artificial water body. According to the incoming water analysis results, the working system of the oil-water well is further adjusted by using a production optimization method, the type of water treatment measures is determined, a water treatment scheme is compiled, and the flowing direction and the flowing degree of oil and water are adjusted while the incoming water in the oil-water well is treated and adjusted, so that the oil increasing effect is achieved. Therefore, the workload of geological modeling and numerical simulation calculation is reduced, the working system of the oil-water well can be adjusted in real time, and an implementable scheme is provided for the treatment of the injection-production well group of the deep-layer fractured solution oil reservoir.

Determining the incoming water comprises the incoming water direction, the incoming water amount and the incoming water strength, wherein the incoming water strength is related to the water injection pressure and the water absorption layer thickness. The method for determining the incoming water of an oil well mainly comprises a numerical Simulation method, a tracer method and a reservoir engineering method (Tailai Wen, marco R.Thiele, waterflow Management using two-stage Optimization with Streamline Simulation [ J ]. Computational geosciences.2014 (3-4)). The numerical simulation method needs to establish a proper geological model, and the quantities of natural bottom water and artificial water injection are determined through fine oil reservoir production history fitting and numerical simulation calculation. The tracer method is to inject a certain volume of water-soluble tracer slug into a water injection well, monitor the relation between the tracer and time in other wells around the water well, and calculate the split coefficient of the water injection amount of the water well by using professional tracer simulation calculation software for evaluating the water inflow amount and the water inflow direction. Most of the oil reservoir engineering methods are based on a material balance method, a mathematical model suitable for reservoir characteristics is established, the oil reservoir engineering method basically considers the influence of longitudinal heterogeneity of an oil layer in the calculation process of the amount of water supplied or the water injection split component, and few plane heterogeneity is considered.

For an oil reservoir engineering method, the calculation of a water injection split coefficient or a water inflow amount has more articles. The research on the influence factors occupies a large part, and the factors influencing the distribution of injected water mainly comprise permeability, communication coefficient, effective thickness of an oil layer, the number of injection and production wells, measure and reconstruction coefficient, injection and production well spacing and the like, and are classified into three major categories of geological factors, controllable factors and comprehensive factors (Analytical Method to preliminary Water flow Performance [ J ]. M.K (Val) Lerma, troy consumping, SPE83511,2003, 5). And analyzing and calculating the influence degree of each influence factor on the interval water injection quantity value by adopting a grey correlation degree analysis method, and screening out main influence factors to construct a splitting coefficient so as to calculate the layered injection allocation quantity. It is clear that splitting of the injected water volume, as well as the analysis of the water volume from the production well, should be a three-dimensional problem, including both longitudinal and planar dimensions. The problem of reasonable injection allocation quantity of the interval with the calculation change of the splitting number in the longitudinal direction is solved, and the aim is to ensure that the oil field keeps the layered injection-production balance in the water injection development process and realize the layered reasonable injection allocation. The method for calculating the splitting number of the layering well mainly comprises an effective thickness method (H method), a static splitting formation coefficient (Kh method), a water absorption section coefficient method, a seepage resistance coefficient method, a comprehensive multi-factor dynamic splitting number method and the like (Tangshenglie, wangfang billows, and the like, a new method for calculating the splitting number of the water injection well is researched, and the split oil-gas field [ J ] 2006.13 (5): 43-45) is formed.

For a plane with a plurality of water injection wells and a production well, the injection allocation calculation method comprises a displaceable volume allocation water injection method, a correction coefficient method and an injection-production ratio method. A displaceable volume allocation method is proposed by j.l. anthony et al, based on maintaining the economic consumption of water injection required for oil field development, and based on the limitations of the injection capacity and oil production capacity of the actual formation of the oil field, calculating the upper limit of water injection in the whole water injection development process (j.l. anthony, golden payroll. Method of determining the optimal economic water injection and oil recovery for large multi-well group water drive [ M ]. Oil and gas field development engineering translation cluster. 1992). The correction coefficient method is a method provided by China Petroleum North China Petroleum on the basis of field statistics, and is used for carrying out in-depth analysis on water injection rules of different types of oil field water injection areas in different time periods. Carrying out mathematical statistics on factors such as water content rise rate, liquid production capacity of a production well, different characteristics of each water flooding block, proportion of water flooding oil layer liquid production, aging and the like to obtain a calculation formula of injection allocation amount (Xiekaoqing, jianghai bridge, heterogeneous reservoir layered water distribution theory, daqing petroleum geology and development [ J ].2008.27 (6): 83-85); the injection-production ratio method considers that the water injection layer section of the water injection well is communicated with the multidirectional oil well production layer, so the liquid production quantities of the plurality of communicated production layers are accumulated to be used as the basis of the injection distribution quantity of the water injection well layer section (Zhang Yurong, wang Navy, etc. the new development and development trend of domestic layered water injection technology, oil drilling and production process [ J ].2011.33 (2): 103-106).

From the above analysis, it can be seen that the reservoir engineering method has certain limitations. In the calculation process of the flow mathematical model, the material of the injection and production system is considered to be balanced, the bottom water invasion amount and the manual accumulated water injection amount are used as input items, the calculation methods of the splitting numbers in the two water injection processes are considered to be the same, the influence degree of gravity in the rising process of the bottom water is not considered to be obviously higher than that of the injected water, so that the splitting number obtained by utilizing the inversion of the production dynamic data is very large, the bottom water and the manual water injection cannot be distinguished, the applicability of the method is greatly reduced, and the quantitative water inflow result cannot be obtained by the method.

In the prior art, a water-drive development multi-layer oil reservoir inter-well connectivity inversion model (Zhaohui, kanjianjiang, seawa, and the like.) is established by a water-drive development multi-layer oil reservoir inter-well connectivity inversion model [ J ] oil and natural gas geology 2016,43 (1): 99-08) based on a flow tube method, so that inter-well connectivity of different development stages can be obtained in real time. The above prior art does not relate to the quantitative determination of the amount of water from a deep-fractured solution reservoir.

Based on the current situation of the prior art, the invention utilizes the production dynamic data of the deep-layer fractured solution reservoir oil-water well, and carries out connectivity analysis and calculation between the oil well and the bottom water body and between the oil-water wells through refined production history fitting to obtain the mutual communication degree, and uses the communication degree for the water supply calculation and analysis, and provides a water treatment suggestion of a well group by combining the water distribution condition, thereby providing a basis for the treatment of the low-efficiency water injection well group.

Fig. 1 shows a flow diagram of a method for quantitatively determining the incoming water of a deep-level desolvated reservoir according to an embodiment of the present invention.

As shown in fig. 1, step S101 is an incoming water direction determining step: and analyzing to obtain a water incoming direction result according to the static connectivity analysis result of the well group to be analyzed.

The incoming water direction determining step further comprises the data collecting and analyzing step: and selecting an injection and production well group with the geological background of the fractured fluid reservoir as an alternative well group, collecting production dynamic data and seismic data of the alternative well group, and removing abnormal data points to obtain historical production data. Specifically, the abnormal data points are mainly data which change suddenly in a short time in the production dynamic data, and the situation can be human error and should be removed.

The incoming water direction determining step further comprises a static communication analyzing step: reservoir carving of the alternative well group is carried out based on seismic data in historical production data, static connectivity among reservoirs is analyzed, and a static connectivity analysis result is obtained. Specifically, the static connectivity analysis results mainly indicate whether connected, whether the fracture or the cavern is connected.

The incoming water direction determining step further comprises a well group determining step of: and carrying out production dynamic analysis on the alternative well group based on the production dynamic data in the historical production data, determining whether the alternative well group is connected or not, deleting the disconnected well numbers, and determining the well group to be analyzed. Specifically, determining whether the alternate well groups are connected includes analyzing whether the oil wells and the oil-water wells are connected by water, production and pressure change curves.

In one embodiment, the analyzing the incoming water direction result specifically includes the following steps: and analyzing the communication condition of the reservoir body and the bottom water based on the static connectivity analysis result, determining the mainly communicated oil-water well, defining the possible mainly incoming water direction, determining that the incoming water is mainly the bottom water or the injected water or both.

As shown in fig. 1, step S102 is a communication degree calculation step: and determining the bottom water position and the oil well perforation position, setting the initial values of the conductivity and the communication volume, and calculating to obtain the communication degree results of the well group to be analyzed at different production moments through production history fitting.

In one embodiment, according to the actual drilling and completion and test oil production results of the oil reservoir, the bottom water position and the oil well perforation position are determined, and for the well with the water production rate greater than a preset value (for example, 20%) in the test oil production stage, the bottom water position is set as the bottom water position; and setting the well with the trial production water yield smaller than a preset value (for example, 20%) according to the mountain advance depth and the water production condition of the adjacent well.

In one embodiment, the initial values of the conductivity and the connected volume are set empirically, and the magnitudes thereof do not affect the subsequent calculation results, but only the number of calculation iterations.

In one embodiment, the connectivity results include, but are not limited to: conductivity and communication volume between the water injection well and the oil production well and between the oil production well and bottom water. Specifically, according to the material balance principle, production dynamic data is utilized to establish a correlation equation of the communication degree and the production data, and the equation is solved to obtain the communication degree between wells and bottom water in different development stages.

As shown in fig. 1, step S103 is a water supply amount calculation step: and calculating the inflow water quantity by combining the inflow water quantity calculation model based on the communication degree result obtained through the normalization processing.

In one embodiment, the normalization process yields a dimensionless conductivity A _ijz And a communicating volume T _ijz Wherein i is a water injection well, j is an oil production well, and z is bottom water. For example, the degree of communication between the first well and the 7 th well is A _1-7 And T _1-7 And the degree of communication with the bottom water is respectively A _1z ，A _7z And T _1z ，T _7z 。

In one embodiment, the water input calculation model comprises the following formula:

Q _in ＝Q _out *A _ijz *T _ijz

wherein Q _in Denotes the amount of incoming water, Q _out Indicating the volume of fluid produced during the phase, A _ijz Denotes conductivity, T _ijz Represents the connected volume, i represents the water injection well, j represents the oil production well, and z represents the bottom water.

In one embodiment, the method for quantitatively determining the water inflow of the deep-layer dissolved oil reservoir further comprises the step of treating water: and (4) based on the result of the water direction and the water amount, providing water treatment measures and water treatment schemes.

Further, the water treatment measures and the water treatment scheme comprise the steps of water source determination and flow potential calculation: and determining an adjusting mode according to the conductivity in the communication degree result, wherein the adjusting mode comprises flow channel adjustment and flow potential adjustment.

In one embodiment, the water source determination and flow potential calculation step comprises:

step a, determining a main communicated oil-water well according to the conductivity, determining whether the water source is bottom water or injected water, mainly adjusting a flow channel for a well group communicated with the bottom water, and mainly adjusting the flow potential for a well communicated with an injection and production well. Specifically, the oil-water well mainly connected is determined in the order of the conductivity from large to small from the conductivity calculation result table in the communication degree calculation result, and it is clear whether the water-containing source is bottom water or injected water.

And b, injecting a flow channel adjusting system with a preset volume near the bottom of the well when flow channel adjustment is carried out, blocking a communication crack between the reservoir body and the bottom water, and realizing flow channel adjustment. Particularly, because the bottom water is large in volume, the operation is not easy through adjusting the flow potential, the effect is not good, and a flow channel adjusting system with a certain volume is injected near the bottom of the well to block a communication crack between a reservoir body and the bottom water, so that the flow channel adjustment is realized.

And c, when the flow potential is adjusted, calculating the flow potential distribution of the well group, drawing an equipotential line, adjusting the yield of each well in the communicated well group according to the flow potential distribution of the oil wells communicated with the water injection well, and achieving the purposes of adjusting the flow potential and oil-water distribution of the well group and improving the yield of the oil wells. Particularly, the oil well communicated with the water injection well can simply adjust the yield of each well in the communicated well group according to the flow potential distribution, thereby achieving the purposes of adjusting the flow potential and oil-water distribution of the well group and improving the yield of the oil well.

Further, the water treatment measures and the water treatment scheme comprise the following steps of optimization and adjustment: and calculating the working system of the water injection well and the oil production well in real time by taking the maximum accumulated oil volume as a constraint condition according to the equipotential lines and the water-containing isoline distribution diagram so as to determine a real-time adjusting scheme and predict the treatment effect of the well group to be analyzed.

In one embodiment, the optimizing and adjusting step comprises: and (3) carrying out iterative calculation on a material balance equation and a development index by taking the communication degree between wells and bottom water as a control variable and the yield and the pressure of the oil-water well as an independent variable to obtain well group development indexes and streaming potential field distribution at different development time.

Fig. 2 shows a flow diagram of a method for quantitatively determining the incoming water of a deep-cutoff reservoir according to another embodiment of the present invention.

As shown in fig. 2, first, qualitative connectivity analysis and static connectivity analysis between injection well groups are performed based on the production data of the fracture-cavity unit and the seismic data of the fracture-cavity unit.

As shown in fig. 2, then, judging whether the injection-production well group is communicated or not, if not, not processing; and if the communication is carried out, setting an initial value of the inter-well communication degree, carrying out iterative calculation, and calculating to obtain a communication degree result after fitting precision is met. The degree of connectivity results include conductivity as well as connected volume.

As shown in fig. 2, the communication degree results are then normalized to determine the incoming water direction and the incoming water amount.

The method and the device for quantitatively determining the water coming from the deep-layer dissolved-water reservoir can also be matched with a computer-readable storage medium, wherein a computer program is stored on the storage medium and is executed to run the method for quantitatively determining the water coming from the deep-layer dissolved-water reservoir. The computer program is capable of executing computer instructions comprising computer program code, which may be in the form of source code, object code, an executable file or some intermediate form, etc.

The computer-readable storage medium may include: any entity or device capable of carrying computer program code, recording medium, U.S. disk, removable hard disk, magnetic diskette, optical disk, computer Memory, read-Only Memory (ROM), random Access Memory (RAM), electrical carrier wave signal, telecommunications signal, software distribution medium, etc.

It should be noted that the computer readable storage medium may include content that is subject to appropriate increase or decrease as required by legislation and patent practice in jurisdictions, for example, in some jurisdictions, computer readable storage media that does not include electrical carrier signals and telecommunications signals in accordance with legislation and patent practice.

Practical application A: TH12120 well group flow regulation and treatment

The well is positioned in twelve areas of a tower river oil field, belongs to an injection and production well group with a dissolved body breaking geological background, and has 5 wells in total, the well area has better reservoir connectivity and possible communication, the carving (as shown in figure 4) reserve scale of the TH12120 well group reaches 85.13 ten thousand tons, the well group produces 36.18 ten thousand tons of oil, the production degree is 35.5 percent, the daily average oil production is 39.2 tons at present, and the well group is developed by intermittent water injection and comprehensively contains 73.6 percent of water. The comprehensive development curve for the well group is shown in figure 3. Fig. 5 shows a graph of results of fracture tracking and identification of TH12120 well groups, fig. 6 shows a graph of results of conductivity calculations between TH12120 well groups, and fig. 7 shows a graph of results of volume calculations of communication between TH12120 well groups.

The TH12120 well group water yield analysis considers that mainly 82% comes from bottom water and 18% comes from a TH12120 water injection well (as shown in FIG. 8), so that the well group needs to be controlled from flooding caused by bottom water flooding, and based on the proposal, a water control scheme of flow channel adjustment is provided, the comprehensive water content of the well group is 73.6%, the comprehensive water content of the well group after treatment is reduced by 12.1%, and the water control effect is obvious.

Practical application B: adjustment and treatment of TH12437X well group flow potential

The TH12437X well group belongs to a TH12402 unit and is positioned in the northwest part of the twelve areas, the target layer is of Ordovician, and the whole well group is positioned on the background of the breaking control karst. By the end of 2020 at 4 months, the TH12437X injection and production well group opens 3 oil wells, 0 water injection well, 52.1 tons of daily oil per day and the comprehensive water content of the well group is 69.3 percent. The comprehensive development curve for the well group is shown in figure 9. Figure 10 shows a TH12437X well group reservoir sculpting and fracture tracking results plot. FIG. 11 shows a graph of the results of calculations of the degree of communication between wells of the TH12437X well group. Figure 12 shows the TH12437X well group inflow profile.

The first stage of the scheme is implemented at 21 days 3 and 3 in 2020, the daily yield is increased to 49.6t, and the oil is increased by 267.2t in the first stage; and 7, 15 days after the second stage is carried out, the daily oil yield is increased to 61.6t, the cumulative oil increase 1769.6t is carried out in the stage, and the total oil increase amount 2036.8t is carried out in the two stages, so that the effect is very obvious.

In addition, as long as 2020, 6 months and 20 days, the method is used for 12 fracture-cave units of a deep-layer solution-breaking oil reservoir of a tower river oil field, the treatment of 48 low-efficiency and ineffective injection and production well groups is developed, the water injection, the water production and the oil production of the well groups are used as control parameters, the benefit (NPV) maximization is used as a constraint, a water treatment scheme for real-time adjustment of the well groups is obtained, 5.32 million tons of crude oil are cumulatively increased through the implementation of an adjustment and treatment scheme by an oil production plant, the water production is cumulatively reduced by 16.8 million tons, the cumulative water injection quantity is reduced by 6.4 million squares, the effective rate of well group treatment is up to more than 85.7%, and the method has high application value and application effect.

Fig. 13 shows a block diagram of an apparatus for quantitatively determining the incoming water of a deep-fractured fluid reservoir according to an embodiment of the invention.

As shown in fig. 13, an apparatus 1300 for quantitatively determining the water from a deep-layer dissolved oil reservoir includes a water direction determination module 1301, a communication degree calculation module 1302, and a water supply amount calculation module 1303.

The incoming water direction determining module 1301 analyzes the incoming water direction result according to the static connectivity analysis result of the well group to be analyzed.

The communication degree calculation module 1302 determines the bottom water position and the oil well perforation position, sets the initial values of the conductivity and the communication volume, and calculates and obtains the communication degree results of the well group to be analyzed at different production moments through production history fitting.

The inflow amount calculation module 1303 calculates the inflow amount based on the result of the communication degree obtained through the normalization process in combination with the inflow amount calculation model.

In conclusion, the method and the device for quantitatively determining the water inflow of the deep-layer dissolved oil reservoir utilize the production dynamic data of the injection and production well group, perform fine history fitting, quantitatively calculate the communication degree, and calculate the water inflow distribution through normalizing the communication degree.

It is to be understood that the disclosed embodiments of the invention are not limited to the particular structures, process steps, or materials disclosed herein but are extended to equivalents thereof as would be understood by those ordinarily skilled in the relevant arts. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting.

In the description of the present invention, "a plurality" means two or more unless otherwise specified; the terms "upper", "lower", "left", "right", "inner", "outer", "front", "rear", "head", "tail", and the like, indicate orientations or positional relationships based on the orientations or positional relationships shown in the drawings, are only for convenience in describing and simplifying the description, and do not indicate or imply that the device or element referred to must have a particular orientation, be constructed in a particular orientation, and be operated, and thus, should not be construed as limiting the invention. Furthermore, the terms "first," "second," "third," and the like are used for descriptive purposes only and are not to be construed as indicating or implying relative importance.

In the description of the present invention, it is to be noted that, unless otherwise explicitly specified or limited, the terms "connected" and "connected" are to be interpreted broadly, e.g., as being fixed or detachable or integrally connected; can be mechanically or electrically connected; may be directly connected or indirectly connected through an intermediate. The specific meanings of the above terms in the present invention can be understood in a specific case to those of ordinary skill in the art.

Reference in the specification to "one embodiment" or "an embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Thus, the appearances of the phrase "one embodiment" or "an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment.

The embodiments of the present invention have been presented for purposes of illustration and description, and are not intended to be exhaustive or limited to the invention in the form disclosed. Many modifications and variations will be apparent to practitioners skilled in this art. The embodiment was chosen and described in order to best explain the principles of the invention and the practical application, and to enable others of ordinary skill in the art to understand the invention for various embodiments with various modifications as are suited to the particular use contemplated.

Although the embodiments of the present invention have been described above, the above description is only for the convenience of understanding the present invention, and is not intended to limit the present invention. It will be understood by those skilled in the art that various changes in form and details may be made therein without departing from the spirit and scope of the invention as defined by the appended claims.

Claims (10)

1. A method for quantitatively determining the water coming from a deep-fractured fluid reservoir, the method comprising:

an incoming water direction determining step: analyzing to obtain an incoming water direction result according to a static connectivity analysis result of a well group to be analyzed;

a communication degree calculating step: determining a bottom water position and an oil well perforation position, setting initial values of conductivity and communication volume, and calculating to obtain communication degree results of the well group to be analyzed at different production moments through production history fitting;

calculating the water inflow amount: and calculating the inflow water quantity by combining the inflow water quantity calculation model based on the communication degree result obtained through the normalization processing.

2. The method for quantitatively determining the water coming from a deep-level gas-water reservoir as claimed in claim 1, wherein the water coming direction determining step comprises the following steps:

data collection and analysis steps: selecting an injection and production well group with a geological background of an interrupted solution reservoir as an alternative well group, collecting production dynamic data and seismic data of the alternative well group, and obtaining historical production data after removing abnormal data points.

3. The method for quantitatively determining the water coming from a deep-level gas-water reservoir as claimed in claim 2, wherein the water coming direction determining step comprises the following steps:

a static communication analysis step: and carrying out reservoir carving of the alternative well group based on the seismic data in the historical production data, and analyzing the static connectivity among the reservoirs to obtain the analysis result of the static connectivity.

4. The method for quantitatively determining the water coming from a deep-level gas-water reservoir as claimed in claim 3, wherein the water coming direction determining step comprises the following steps:

well group determination: and carrying out production dynamic analysis on the alternative well group based on the production dynamic data in the historical production data, determining whether the alternative well group is communicated or not, deleting the number of the non-communicated well, and determining the well group to be analyzed.

5. The method for quantitatively determining the water coming from a deep-level gas-water reservoir as claimed in claim 1, wherein the analyzing the result of the direction of the water coming comprises the following steps:

and analyzing the communication condition of the reservoir body and the bottom water based on the static connectivity analysis result, determining the mainly communicated oil-water well, defining the possible mainly incoming water direction, determining that the incoming water is mainly the bottom water or the injected water or both.

6. The method of quantitatively determining the incoming water of a deep-cut fluid reservoir as set forth in claim 1, wherein the results of the degree of connectivity include, but are not limited to: conductivity and communication volume between the water injection well and the oil production well and between the oil production well and bottom water.

7. The method of quantitatively determining the incoming water of a deep-water-fractured-fluid reservoir as set forth in claim 1, wherein the incoming water quantity calculation model comprises the following formula:

Q _in ＝Q _out *A _ijz *T _ijz

wherein Q is _in Denotes the amount of incoming water, Q _out Indicating the volume of fluid produced during the phase, A _ijz Denotes conductivity, T _ijz Representing the connected volume, i representing the injection well, j representing the production well, z representing the bottom water.

8. The method for quantitatively determining the incoming water of a deep-cutoff fluid reservoir as set forth in claim 1, further comprising:

water treatment step: and proposing a water treatment measure and a water treatment scheme based on the water coming direction result and the water coming quantity.

9. A storage medium characterized in that it contains a series of instructions for carrying out the steps of the method according to any one of claims 1 to 8.

10. An apparatus for quantitatively determining an incoming water of a deep-fractured reservoir, which performs the method for quantitatively determining an incoming water of a deep-fractured reservoir according to any one of claims 1 to 8, the apparatus comprising:

the water direction determining module is used for analyzing and obtaining a water direction result according to the static connectivity analysis result of the well group to be analyzed;

the communication degree calculation module is used for determining the bottom water position and the oil well perforation position, setting the initial values of the conductivity and the communication volume, and calculating to obtain the communication degree results of the well group to be analyzed at different production moments through production history fitting;

and the water inflow calculation module is used for calculating the water inflow by combining the water inflow calculation model based on the communication degree result obtained through the normalization processing.

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