CN109630094B - Unconventional pressure relief speed analysis method, device and system and storable equipment - Google Patents
Unconventional pressure relief speed analysis method, device and system and storable equipment Download PDFInfo
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Abstract
The embodiment of the application discloses an unconventional pressure relief speed analysis method, a device, a system and a storage device, wherein the unconventional pressure relief speed analysis method comprises the following steps: acquiring the ineffective water injection speed of the target well group according to the production dynamics; acquiring the near-well reservoir water storage speed of the target well group according to the well storage coefficient; determining an unconventional pressure relief speed of a target well group by using the ineffective water injection speed and the near-well reservoir water storage speed; analyzing the target well group by using the unconventional pressure relief speed to obtain the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio of the target well group; and determining the oil reservoir development measures of the target well group according to the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio.
Description
Technical Field
The application relates to the field of low-permeability and compact reservoir development, in particular to an unconventional pressure relief speed analysis method, device and system and a storage device.
Background
For low permeability/tight or conglomerate reservoirs, high pressure waterflooding or near-well fracturing often causes a network of fractures to develop near the injection well. When a target well group is developed by water injection, part of injected water enters a non-target layer along a fracture network, and the effective proportion of water injection is less than 1; a portion of the injected water will form a near well water reservoir near the injection well wellbore. Unlike the conventional water invasion concept, the phenomenon of injection of water into a non-target zone may be referred to as an "unconventional pressure relief" phenomenon. How to accurately represent the unconventional pressure relief degree is very important in the measures such as reservoir water injection development, fracturing and the like.
At present, there is no in-depth study on unconventional pressure relief: the phenomenon that the well storage is abnormal due to overlarge well storage and the production dynamic is abnormal due to non-conservation of substances is not known; during high pressure water injection or near well fracturing, parameters and calculation methods for the unconventional pressure relief speed are not accurately and specifically expressed. Therefore, the water injection speed, the plugging agent consumption and the injection-production ratio are not matched with the actual conditions of the reservoir during field work, the evaluation of the water injection and plugging regulation effects is also influenced, and hidden dangers are buried for subsequent production and prediction work.
Disclosure of Invention
The technical scheme solves the problem that parameters such as water injection speed, plugging agent dosage, injection-production ratio and the like are not matched with the actual condition of a reservoir by utilizing the more accurate unconventional pressure relief speed, so that the scientific and reasonable formulation and development technical policy of the hypotonic/compact oil reservoir can be realized.
In order to achieve the above object, an embodiment of the present application provides an unconventional pressure relief speed analysis method, including:
acquiring the ineffective water injection speed of the target well group according to the production dynamics;
acquiring the near-well reservoir water storage speed of the target well group according to the well storage coefficient;
determining an unconventional pressure relief speed of a target well group by using the ineffective water injection speed and the near-well reservoir water storage speed;
and analyzing the target well group by using the unconventional pressure relief speed.
After the injected water reaches the formation, a portion of the water does not enter the destination zone, but instead passes into other zones or into near-well reservoirs. Water which does not enter the target layer does not play a displacement role, and is called ineffective water injection; water channeling into other layers is a pressure relief action for the destination layer, which is called unconventional pressure relief; high pressure bodies of water stored near a wellbore are referred to as near-well reservoirs.
The target well group is the well group actually studied. The ineffective water injection coefficient is the ineffective water injection quantity in unit time and unit pressure difference; the unconventional pressure relief speed is a physical quantity for evaluating the speed of unconventional pressure relief; the near-well reservoir volume is a near-well fracture network volume; the near-well reservoir water storage volume is the sum of the original fracture network volume and the water volume which enables the fracture network to store more due to the compressibility of water.
The effective water injection speed is the water injection speed of the well group without the unconventional pressure relief speed; the actual amount of the plugging agent is the sum of the amount of the plugging agent lost by unconventional pressure relief and the amount of the plugging agent of a plugging target layer; the actual injection-production ratio is the ratio of the well group water injection rate to the well group production fluid rate excluding the ineffective water injection rate.
Preferably, the step of analyzing the target well group by using the unconventional pressure relief speed comprises:
obtaining the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio of the target well group by utilizing the unconventional pressure relief speed;
and determining the oil reservoir development measures of the target well group according to the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio.
Preferably, the step of obtaining the ineffective water injection rate of the target well group according to the production dynamics comprises:
acquiring the average formation pressure of a target well group;
obtaining a water injection pressure difference by utilizing the average formation pressure;
the water injection differential pressure is the difference value between the bottom flowing pressure of the water injection well and the current average formation pressure of the reservoir;
obtaining invalid water injection quantity according to the water injection pressure difference;
obtaining an ineffective water injection coefficient based on the ineffective water injection amount;
and obtaining the invalid water injection speed according to the invalid water injection coefficient and the water injection pressure difference.
Preferably, the step of obtaining the near-well reservoir water storage rate of the target well group according to the well storage coefficient comprises:
obtaining the near-well reservoir volume of the water injection well of the target well group by utilizing the well storage coefficient;
obtaining a near-well reservoir water storage volume from the near-well reservoir volume of the water injection well;
and obtaining the near-well reservoir water storage speed of the target well group according to the near-well reservoir water storage volume.
Preferably, the unconventional pressure relief rate is obtained by subtracting the near-well reservoir water storage rate from the ineffective water injection rate.
Preferably, the effective water injection rate is obtained by subtracting the unconventional pressure relief rate from the well group water injection rate.
Preferably, the actual amount of the plugging agent is obtained by using the effective amount of the plugging agent, the water injection speed of a well group and the unconventional pressure relief speed.
Preferably, the actual injection-production ratio is obtained through a well group water injection speed, the unconventional pressure relief speed and a fluid production speed.
In order to achieve the above object, an embodiment of the present invention provides an unconventional pressure relief speed analysis device, including:
the invalid water injection speed acquisition unit is used for acquiring the invalid water injection speed of the target well group according to the production dynamic state;
the near-well reservoir water storage speed acquisition unit is used for acquiring the near-well reservoir water storage speed of the target well group according to the well storage coefficient;
the unconventional pressure relief speed acquisition unit is used for determining the unconventional pressure relief speed of the target well group by utilizing the invalid water injection speed and the near-well reservoir water storage speed;
and the analysis unit is used for analyzing the target well group by utilizing the unconventional pressure relief speed.
Preferably, the analysis unit comprises:
the water injection and plugging regulation quantification module is used for obtaining the effective water injection speed, the actual plugging agent consumption and the actual injection-production ratio of the target well group by utilizing the unconventional pressure relief speed;
and the development measure module is used for determining the oil reservoir development measure of the target well group according to the effective water injection speed, the actual plugging agent consumption and the actual injection-production ratio.
Preferably, the invalid water filling rate obtaining unit includes:
the average formation pressure acquisition module is used for acquiring the average formation pressure of the target well group;
the water injection differential pressure acquisition module is used for acquiring water injection differential pressure by utilizing the average formation pressure;
the invalid water injection quantity obtaining module is used for obtaining invalid water injection quantity according to the water injection pressure difference;
the invalid water injection coefficient acquisition module is used for acquiring an invalid water injection coefficient based on the invalid water injection amount;
and the invalid water injection speed calculation module is used for obtaining an invalid water injection speed according to the invalid water injection coefficient and the water injection pressure difference.
Preferably, the near-well reservoir water storage rate acquisition unit comprises:
the near-well reservoir volume acquisition module is used for acquiring the near-well reservoir volume of the water injection well of the target well group by utilizing the well storage coefficient;
the near-well reservoir water storage volume acquisition module is used for acquiring the near-well reservoir water storage volume according to the near-well reservoir volume of the water injection well;
and the near-well reservoir water storage speed module is used for obtaining the near-well reservoir water storage speed of the target well group according to the near-well reservoir water storage volume.
Preferably, the water injection and blockage regulation quantification unit obtains the effective water injection speed by subtracting the unconventional pressure relief speed from the water injection speed of the well group.
Preferably, the water injection and plugging adjustment quantifying unit obtains the actual plugging agent using amount by using the effective plugging agent using amount, the water injection speed of the well group and the unconventional pressure relief speed.
Preferably, the water injection and plugging regulation quantification unit obtains the actual injection-production ratio through the water injection speed, the unconventional pressure relief speed and the liquid production speed of the well group.
In order to achieve the above object, an electronic device according to an embodiment of the present invention further includes a memory, a processor, and a computer program stored in the memory and executable on the processor, where the processor executes the computer program to implement the abnormal pressure relief speed analysis method disclosed in the embodiment of the present invention.
In order to achieve the above object, the embodiments of the present application provide a readable storage medium, on which a computer program is stored, and the computer program, when executed, implements the steps of the unconventional pressure relief speed analysis method disclosed in the embodiments of the present invention.
Therefore, compared with the prior art, the technical scheme acquires the unconventional pressure relief speed in two aspects of comprehensive production dynamics and well storage coefficients, analyzes based on the acquired unconventional pressure relief speed, and solves the problem that the parameters such as the existing water injection speed, plugging agent dosage, injection-production ratio and the like are not matched with the actual condition of a reservoir, so that the scientific and reasonable formulation and development technical policy of the hypotonic/compact oil reservoir can be realized, and a reliable basis is provided for further yield increasing measures.
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In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without creative efforts.
FIG. 1 is a flow chart of an unconventional pressure relief velocity analysis method disclosed herein;
FIG. 2 is a functional block diagram of an unconventional pressure relief velocity analysis apparatus disclosed herein;
fig. 3 is a schematic view of an electronic device according to an embodiment of the present application.
Detailed Description
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments obtained by a person of ordinary skill in the art without any inventive work based on the embodiments in the present application shall fall within the scope of protection of the present application.
The working principle of the technical scheme is as follows: in order to evaluate the unconventional pressure release speed of the injection well, a rapid quantification method based on production dynamics and well storage coefficients is established, so that the effective water injection speed is more accurate in calculation, and the method has important practical significance for guiding field water injection or fracturing operation.
Based on the above description, the present specification provides an unconventional pressure relief velocity analysis method, as shown in fig. 1. The method for determining the reservoir development measures can be applied to a server. In particular, the server may be a background business server of a website capable of providing query services. In this embodiment, the server may be an electronic device having data operation, storage function and network interaction function; software may also be provided that runs in the electronic device to support data processing, storage, and network interaction. The number of servers is not particularly limited in the present embodiment. The server may be one server, several servers, or a server cluster formed by several servers. The method comprises the following steps:
step 101): and acquiring the ineffective water injection speed of the target well group according to the production dynamics.
In this embodiment, the step of obtaining the ineffective water injection rate of the target well group comprises:
acquiring the average formation pressure of a target well group; wherein, the average formation pressure p of the well group is obtained by an arithmetic average method according to the bottom flow pressure of the injection well and the bottom flow pressure of the production well in the well groupi。
Obtaining a water injection pressure difference by utilizing the average formation pressure; and subtracting the average formation pressure of the well group from the bottom flow pressure of the water injection well to obtain the water injection differential pressure delta p of the well group.
Obtaining invalid water injection quantity according to the water injection pressure difference; wherein, the expression of the ineffective water injection amount is as follows:
We＝(NpBo+Wp-Wi)-NCtBoiΔp (1)
wherein, WeThe water injection amount is invalid; n is a radical ofpTo accumulate oil production; b isoAverage formation pressure of p for a well groupiThe volume factor of crude oil in the formation; wpThe accumulated water yield is obtained; wiThe accumulated water injection amount is used; n is the original reserve of the well group; ctIs the comprehensive compression coefficient; b isoiIs the volume coefficient of crude oil; and delta p is the water injection pressure difference of the well group.
Obtaining an ineffective water injection coefficient based on the ineffective water injection amount; it is composed ofMiddle and invalid water injection coefficient K2The expression of (a) is:
wherein, WeThe water injection amount is invalid; k2Is the ineffective water injection coefficient; p is a radical ofiIs the average formation pressure; p is a radical of0To pnThe pressure of the water injection well at different times; and t is water injection time.
And obtaining the invalid water injection speed according to the invalid water injection coefficient and the water injection pressure difference. Wherein the ineffective water injection rate qe1The expression of (a) is:
qe1＝K2Δp (3)
wherein q ise1For ineffective waterflood rates, Δ p is the well group waterflood differential pressure.
Step 102): and acquiring the near-well reservoir water storage speed of the target well group according to the well storage coefficient.
In this embodiment, step 102 includes:
obtaining a near-well reservoir volume for a water injection well of a target well group; wherein the near-well reservoir volume V of the water injection well is expressed as:
wherein V is the near-well reservoir volume of the water injection well; c is the well storage coefficient of the water injection well; cwIs the water compression factor.
Obtaining a near-well reservoir water storage volume from the water injection well near-well reservoir volume; wherein the near-well reservoir water storage volume Δ V is expressed as:
ΔV＝Δp·Cw·V+V (5)
wherein Δ V is the near-well reservoir water storage volume; and V is the near-well reservoir volume of the water injection well.
Obtaining a near-well reservoir water storage speed according to the near-well reservoir water storage volume; wherein the near well reservoir water storage rate qe2The expression of (a) is:
wherein q ise2The near-well reservoir water storage rate; Δ V is near-well reservoir water storage volume; and t is water injection time.
Step 103): determining an unconventional pressure relief speed of a target well group by using the ineffective water injection speed and the near-well reservoir water storage speed; wherein, unconventional pressure release speed expression is as follows:
qe＝qe1-qe2(7)
wherein q ise1The ineffective water injection speed; q. q.se2The near-well reservoir water storage rate; q. q.seThe pressure relief speed is unconventional.
Step 104): and analyzing the target well group by using the unconventional pressure relief speed.
In practical application, the unconventional pressure relief speed is utilized to obtain the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio of the target well group. Wherein the content of the first and second substances,
the expression for the effective water injection rate for the target well group is:
qr＝qi-qe(8)
in the formula, qrEffective water injection speed; q. q.si(ii) a water injection rate for the well group; q. q.seThe pressure relief speed is unconventional.
The expression of the actual amount of the plugging agent is as follows:
in the formula, QiThe actual dosage of the plugging agent is used; q is the dosage of the effective plugging agent; q. q.seUnconventional pressure relief speed; q. q.siThe water injection rate for the well group.
The expression of the actual injection-production ratio is as follows:
in the formula, IW is the actual injection-production ratio; q. q.si(ii) a water injection rate for the well group; q. q.se1The ineffective water injection speed; w is the well composition fluid velocity.
And then determining the oil reservoir development measures of the target well group according to the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio.
In order to provide a more intuitive understanding of the technical scheme, a specific implementation of the technical scheme is described by taking the unconventional pressure relief characterization process of a low permeability oilfield by using the method as an example.
There is a typical five-well pattern well group, and the calculated parameters for the typical well group are shown in table 1.
TABLE 1
By using the formulas 1 to 3, the average formation pressure of the well group is calculated to be 11.27MPa, and the ineffective water injection rate is calculated to be 3.7 × 104m3The ineffective water injection coefficient is 5.8m3/(MPa. d), the ineffective water injection rate was 24.30m3/d。
The water injection time of the well group is 396 days, the water injection pressure difference is 4.18MPa, and the water compression coefficient is 0.5 × 10-4MPa-1The well storage coefficient of the water injection well is 0.12m3In MPa. According to the formulas 4 to 6, the volume of the near-well reservoir of the water injection well is calculated to be 2400m3The near-well reservoir water storage volume is 2400.50m3The near-well reservoir water storage speed is 6.0619m3And d. Using equation 7, the unconventional pressure relief velocity was calculated to be 18.2381m3/d。
By utilizing the obtained unconventional pressure relief speed, the well group water injection speed q is calculated in the aspect of effective water injection speediIs 40.3m3D, calculating the effective injection amount q according to the formula (8)rIs 22.0619m3And d. In the aspect of calculating the actual dosage of the plugging agent, the dosage of the effective plugging agent is designed to be 300m3Then, the effective dosage Q of the chemical plugging agent needed by the well group is obtained by calculation according to the formula (9) and is 550m3. In calculating the actual injection-production ratio, the well group production fluid velocity W is 21.28m3And/d, calculating the actual injection-production ratio IW to be 0.75 according to the formula (10).
According to the effective water injection speed and the actual injection-production ratio which are calculated and provided by the invention, an oil reservoir manager can make more reasonable oil reservoir management measures, including changing the injection-production amount, treating the shaft condition and the like. Meanwhile, the actual plugging agent dosage provided by the invention can be used for guiding the profile control and water plugging work of the oil reservoir.
The embodiment calculates the invalid water filling speed q according to the production dynamicse1And the near-well reservoir water storage speed q obtained by calculating the well storage coefficiente2Establishing an unconventional pressure relief speed qeThe calculation method makes up the blank of the unconventional pressure relief speed characterization at the present stage, and solves the characterization problem that water injected into a low-permeability/compact or conglomerate oil reservoir enters a non-target layer. Therefore, the problem that parameters such as water injection speed, plugging agent dosage, injection-production ratio and the like in the development of the low-permeability/compact oil reservoir are not matched with the actual condition of the reservoir is solved, and a reliable basis is provided for further yield increasing measures.
Fig. 2 is a functional block diagram of an unconventional pressure relief speed analysis device disclosed in the present specification. The method comprises the following steps:
an invalid water injection speed obtaining unit 201, configured to obtain an invalid water injection speed of the target well group according to the production dynamics;
a near-well reservoir water storage speed acquisition unit 202, configured to acquire a near-well reservoir water storage speed of the target well group according to the well storage coefficient;
an unconventional pressure relief speed acquisition unit 203, configured to determine an unconventional pressure relief speed of the target well group using the invalid water injection speed and the near-well reservoir water storage speed;
and the analysis unit 204 is used for analyzing the target well group by using the unconventional pressure relief speed.
In the present embodiment, the analysis unit 204 includes:
the water injection and plugging regulation quantification module is used for obtaining the effective water injection speed, the actual plugging agent consumption and the actual injection-production ratio of the target well group by utilizing the unconventional pressure relief speed;
and the development measure module is used for determining the oil reservoir development measure of the target well group according to the effective water injection speed, the actual plugging agent consumption and the actual injection-production ratio.
In this embodiment, the invalid water filling rate obtaining unit 201 includes:
the average formation pressure acquisition module is used for acquiring the average formation pressure of the target well group;
the water injection differential pressure acquisition module is used for acquiring water injection differential pressure by utilizing the average formation pressure;
the invalid water injection quantity obtaining module is used for obtaining invalid water injection quantity according to the water injection pressure difference;
the invalid water injection coefficient acquisition module is used for acquiring an invalid water injection coefficient based on the invalid water injection amount;
and the invalid water injection speed calculation module is used for obtaining an invalid water injection speed according to the invalid water injection coefficient and the water injection pressure difference.
In this embodiment, the average formation pressure obtaining module obtains the average formation pressure of the target well group by an arithmetic average method based on the bottom-hole flow pressure of the injection well and the bottom-hole flow pressure of the production well in the well group.
In this embodiment, the water injection differential pressure acquisition module subtracts the average formation pressure of the target well group from the bottom hole flow pressure of the water injection well to obtain the water injection differential pressure.
In this embodiment, the invalid water injection speed obtaining module obtains the invalid water injection speed by using the average formation pressure of the target well group, the invalid water injection near-well volume, the pressure of each water injection well in the target well group, and the production time of the corresponding water injection well.
In this embodiment, the near-well reservoir water storage rate acquisition unit includes:
the water injection well storage coefficient acquisition module is used for acquiring the well storage coefficient of the water injection well of the target well group through well testing interpretation;
and the near-well reservoir body water storage speed calculation module is used for obtaining the near-well reservoir body water storage speed of the target well group according to the well storage coefficient of the water injection well of the target well group, the pressure change of the water injection well in the water injection period and the water injection time.
In this embodiment, the irregular pressure relief speed obtaining unit includes:
and the unconventional pressure relief speed acquisition module is used for acquiring the unconventional pressure relief speed according to the result that the water storage speed of the near-well reservoir body is subtracted from the invalid water injection speed.
In this embodiment, the water injection and blockage regulation quantifying unit obtains the effective water injection speed by subtracting the unconventional pressure relief speed from the water injection speed of the well group.
In this embodiment, the water injection and plugging adjustment quantifying unit obtains the actual plugging agent amount by using the effective plugging agent amount, the water injection speed of the well group, and the unconventional pressure relief speed.
In this embodiment, the water injection and plugging adjustment quantifying unit obtains the actual injection-production ratio through a well group water injection speed, the unconventional pressure relief speed and a well group production fluid speed.
Fig. 3 is a schematic view of an electronic device according to an embodiment of the present disclosure. The non-conventional pressure relief speed analysis method comprises a memory, a processor and a computer program which is stored on the memory and can run on the processor, wherein the processor executes the computer program to realize the non-conventional pressure relief speed analysis method.
The specific functions implemented by the memory and the processor of the method for determining oil reservoir development measures provided by the embodiments of the present specification can be explained in comparison with the foregoing embodiments in the present specification, and can achieve the technical effects of the foregoing embodiments, and will not be described herein again.
In this embodiment, the memory may include a physical device for storing information, and typically, the information is digitized and then stored in a medium using an electrical, magnetic, or optical method. The memory according to this embodiment may further include: devices that store information using electrical energy, such as RAM, ROM, etc.; devices that store information using magnetic energy, such as hard disks, floppy disks, tapes, core memories, bubble memories, usb disks; devices for storing information optically, such as CDs or DVDs. Of course, there are other ways of memory, such as quantum memory, graphene memory, and so forth.
In this embodiment, the processor may be implemented in any suitable manner. For example, the processor may take the form of, for example, a microprocessor or processor and a computer-readable medium that stores computer-readable program code (e.g., software or firmware) executable by the (micro) processor, logic gates, switches, an Application Specific Integrated Circuit (ASIC), a programmable logic controller, an embedded microcontroller, and so forth.
In this embodiment, a readable storage medium is further provided, on which a computer program is stored, and the computer program is executed to implement the steps of the above-mentioned unconventional pressure relief speed analysis method.
Therefore, the technical scheme solves the problems of unstable calculation result, poor effect predictability and the like when a large technical policy is formulated for the low-permeability/compact or conglomerate oil reservoir, and realizes the scientific development of the low-permeability/compact or conglomerate oil reservoir.
In the 90 th generation of 20 th century, it is obvious that improvements in Hardware (for example, improvements in Circuit structures such as diodes, transistors and switches) or software (for improvement in method flow) can be distinguished for a technical improvement, however, as technology develops, many of the improvements in method flow today can be regarded as direct improvements in Hardware Circuit structures, designers almost all obtain corresponding Hardware Circuit structures by Programming the improved method flow into Hardware circuits, and therefore, it cannot be said that an improvement in method flow cannot be realized by Hardware entity modules, for example, Programmable logic devices (Programmable logic devices L organic devices, P L D) (for example, Field Programmable Gate Arrays (FPGAs) are integrated circuits whose logic functions are determined by user Programming of devices), and a digital system is "integrated" on a P L D "by self Programming of designers without requiring many kinds of integrated circuits manufactured and manufactured by special chip manufacturers to design and manufacture, and only a Hardware program is written by Hardware logic editor (software) such as Hardware editor software, software editor, software, Hardware editor, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software, Hardware, software.
Those skilled in the art will also appreciate that, in addition to implementing clients and servers as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the clients and servers implement logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such clients and servers may thus be considered a hardware component, and the means included therein for performing the various functions may also be considered as structures within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
From the above description of the embodiments, it is clear to those skilled in the art that the present application can be implemented by software plus necessary general hardware platform. Based on such understanding, the technical solutions of the present application may be essentially or partially implemented in the form of a software product, which may be stored in a storage medium, such as a ROM/RAM, a magnetic disk, an optical disk, etc., and includes several instructions for enabling a computer device (which may be a personal computer, a server, or a network device, etc.) to execute the method described in the embodiments or some parts of the embodiments of the present application.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments can be referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, both for the embodiments of the client and the server, reference may be made to the introduction of embodiments of the method described above.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
Although the present application has been described in terms of embodiments, those of ordinary skill in the art will recognize that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the spirit of the application.
Claims (6)
1. An unconventional pressure relief speed analysis method is characterized by comprising the following steps:
acquiring the ineffective water injection speed of the target well group according to the production dynamics;
acquiring the near-well reservoir water storage speed of the target well group according to the well storage coefficient;
determining an unconventional pressure relief speed of the target well group by using the ineffective water injection speed and the near-well reservoir water storage speed, wherein the unconventional pressure relief speed is the speed of the ineffective water injection to flow into other layers except the target layer;
analyzing the target well group by using the unconventional pressure relief speed;
wherein the step of analyzing the target well group using the unconventional pressure relief speed comprises:
obtaining the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio of the target well group by utilizing the unconventional pressure relief speed;
determining a target well group oil reservoir development measure according to the effective water injection speed, the actual plugging agent dosage and the actual injection-production ratio;
the step of obtaining the ineffective water injection speed of the target well group according to the production dynamic comprises the following steps:
acquiring the average formation pressure of a target well group;
obtaining a water injection pressure difference by utilizing the average formation pressure;
obtaining invalid water injection quantity according to the water injection pressure difference;
obtaining an ineffective water injection coefficient based on the ineffective water injection amount;
obtaining an invalid water injection speed according to the invalid water injection coefficient and the water injection pressure difference;
the step of obtaining the near-well reservoir water storage speed of the target well group according to the well storage coefficient comprises the following steps:
obtaining the near-well reservoir volume of the water injection well of the target well group by utilizing the well storage coefficient;
obtaining a near-well reservoir water storage volume from the near-well reservoir volume of the water injection well;
and obtaining the near-well reservoir water storage speed of the target well group according to the near-well reservoir water storage volume.
2. The method of claim 1, wherein the unconventional pressure relief rate is obtained by subtracting the near-well reservoir water storage rate from the ineffective waterflood rate.
3. The method of claim 1, wherein the effective rate of water injection is obtained using a well group water injection rate minus the unconventional pressure relief rate.
4. The method of claim 1, wherein said actual plugging agent dosage is obtained using an effective plugging agent dosage, a well group water injection rate, and said unconventional pressure relief rate.
5. The method of claim 1, wherein said actual voidage replacement ratio is obtained from a well group waterflood rate, said unconventional pressure relief rate, and a fluid production rate.
6. An unconventional pressure relief speed analysis device, comprising:
the invalid water injection speed acquisition unit is used for acquiring the invalid water injection speed of the target well group according to the production dynamic state;
the near-well reservoir water storage speed acquisition unit is used for acquiring the near-well reservoir water storage speed of the target well group according to the well storage coefficient, wherein the unconventional pressure relief speed is the speed of invalid water injection to flow into other layers except the target layer;
the unconventional pressure relief speed acquisition unit is used for determining the unconventional pressure relief speed of the target well group by utilizing the invalid water injection speed and the near-well reservoir water storage speed;
the analysis unit is used for analyzing the target well group by utilizing the unconventional pressure relief speed;
wherein the analysis unit comprises:
the water injection and plugging regulation quantification module is used for obtaining the effective water injection speed, the actual plugging agent consumption and the actual injection-production ratio of the target well group by utilizing the unconventional pressure relief speed;
the development measure module is used for determining the oil reservoir development measure of the target well group according to the effective water injection speed, the actual plugging agent consumption and the actual injection-production ratio;
the invalid water injection speed obtaining unit includes:
the average formation pressure acquisition module is used for acquiring the average formation pressure of the target well group;
the water injection differential pressure acquisition module is used for acquiring water injection differential pressure by utilizing the average formation pressure;
the invalid water injection quantity obtaining module is used for obtaining invalid water injection quantity according to the water injection pressure difference;
the invalid water injection coefficient acquisition module is used for acquiring an invalid water injection coefficient based on the invalid water injection amount;
the invalid water injection speed calculation module is used for obtaining an invalid water injection speed according to the invalid water injection coefficient and the water injection pressure difference;
the near-well reservoir water storage rate acquisition unit comprises:
the near-well reservoir volume acquisition module is used for acquiring the near-well reservoir volume of the water injection well of the target well group by utilizing the well storage coefficient;
the near-well reservoir water storage volume acquisition module is used for acquiring the near-well reservoir water storage volume according to the near-well reservoir volume of the water injection well;
and the near-well reservoir water storage speed module is used for obtaining the near-well reservoir water storage speed of the target well group according to the near-well reservoir water storage volume.
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