CN111191183A - Reservoir parameter calculation method, device and equipment - Google Patents
Reservoir parameter calculation method, device and equipment Download PDFInfo
- Publication number
- CN111191183A CN111191183A CN202010020558.1A CN202010020558A CN111191183A CN 111191183 A CN111191183 A CN 111191183A CN 202010020558 A CN202010020558 A CN 202010020558A CN 111191183 A CN111191183 A CN 111191183A
- Authority
- CN
- China
- Prior art keywords
- water
- water injection
- reservoir
- volume
- parameter
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 238000004364 calculation method Methods 0.000 title claims description 35
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 181
- 239000007924 injection Substances 0.000 claims abstract description 143
- 238000002347 injection Methods 0.000 claims abstract description 143
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 55
- 238000000034 method Methods 0.000 claims abstract description 41
- 239000003921 oil Substances 0.000 claims description 89
- 239000010779 crude oil Substances 0.000 claims description 17
- 238000004590 computer program Methods 0.000 claims description 4
- 238000011084 recovery Methods 0.000 claims description 3
- 230000008569 process Effects 0.000 abstract description 13
- 230000006872 improvement Effects 0.000 description 8
- 238000004519 manufacturing process Methods 0.000 description 7
- 230000008859 change Effects 0.000 description 3
- 238000011161 development Methods 0.000 description 3
- 230000006870 function Effects 0.000 description 3
- 238000005259 measurement Methods 0.000 description 3
- 239000000243 solution Substances 0.000 description 3
- 238000010276 construction Methods 0.000 description 2
- 238000009795 derivation Methods 0.000 description 2
- 238000010586 diagram Methods 0.000 description 2
- 238000005516 engineering process Methods 0.000 description 2
- 230000009286 beneficial effect Effects 0.000 description 1
- 230000001413 cellular effect Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 150000001875 compounds Chemical class 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000012530 fluid Substances 0.000 description 1
- 238000012886 linear function Methods 0.000 description 1
- 230000005055 memory storage Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 230000003287 optical effect Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
Images
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F17/00—Digital computing or data processing equipment or methods, specially adapted for specific functions
- G06F17/10—Complex mathematical operations
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/20—Displacing by water
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
Landscapes
- Engineering & Computer Science (AREA)
- Physics & Mathematics (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Mining & Mineral Resources (AREA)
- Mathematical Physics (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Theoretical Computer Science (AREA)
- Environmental & Geological Engineering (AREA)
- Data Mining & Analysis (AREA)
- General Physics & Mathematics (AREA)
- Mathematical Optimization (AREA)
- Mathematical Analysis (AREA)
- Computational Mathematics (AREA)
- Pure & Applied Mathematics (AREA)
- Databases & Information Systems (AREA)
- Software Systems (AREA)
- General Engineering & Computer Science (AREA)
- Algebra (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
本说明书实施例提供一种储层参数计算方法、装置及设备。所述储层参数包括井控储量、初始时刻水体体积；所述方法包括：获取至少一组地层压力参数和注水体积参数；根据所述地层压力参数和所述注水体积参数构建注水指示曲线；基于所述注水指示曲线，计算对应于储层的初始时刻水油比；根据所述注水指示曲线和预先构建的注水指示模型，利用所述初始时刻水油比计算所述储层参数。通过所述方法，在考虑初始时刻水油比的情况下，计算相应的储层参数，使其满足实际应用过程中的需求，实现了较为准确地对储层参数进行计算。
Embodiments of this specification provide a method, device, and device for calculating reservoir parameters. The reservoir parameters include well-controlled reserves and initial water volume; the method includes: acquiring at least one set of formation pressure parameters and water injection volume parameters; constructing a water injection indication curve based on the formation pressure parameters and the water injection volume parameters; For the water injection indication curve, the water-oil ratio corresponding to the initial time of the reservoir is calculated; according to the water injection indication curve and the pre-built water injection indication model, the water-oil ratio at the initial time is used to calculate the reservoir parameter. Through the method, the corresponding reservoir parameters are calculated under the condition of considering the water-oil ratio at the initial time, so as to meet the requirements in the actual application process, and the reservoir parameters can be calculated more accurately.
Description
Technical Field
The embodiment of the specification relates to the technical field of geological exploration and development, in particular to a reservoir parameter calculation method, device and equipment.
Background
In the field of geological exploration and development, as the oil production in a reservoir is gradually carried out, the pressure in an oil layer is gradually reduced, so that the production speed of the reservoir is reduced. To increase production rates and oil recovery, water may be injected into the reservoir through the injection well to restore pressure to the reservoir, again with corresponding production capacity.
In the process of water injection exploitation for a reservoir, a water injection indication curve for the reservoir is generally used as a standard, but in the application process at present, a model corresponding to the water injection indication curve is not combined with an actual application situation, and when the water injection indication curve is calculated, the interference of an original water-oil ratio to the model in the actual application process is often ignored, relative errors are ignored, the value of actual utilization is lacked, and the calculated reservoir parameters and the actual situation often have certain differences. Therefore, a method for accurately calculating geological parameters by using a corresponding model under the premise of considering practical situations is needed.
Disclosure of Invention
An object of the embodiments of the present specification is to provide a method, an apparatus, and a device for calculating reservoir parameters, so as to solve a problem of how to accurately calculate reservoir parameters.
In order to solve the above technical problem, an embodiment of the present specification provides a reservoir parameter calculation method, device and apparatus implemented as follows:
a reservoir parameter calculation method comprises the steps of well control reserve and initial time water volume; the method comprises the following steps:
acquiring at least one group of formation pressure parameters and water injection volume parameters;
constructing a water injection indication curve according to the formation pressure parameter and the water injection volume parameter;
calculating an initial time water-oil ratio corresponding to a reservoir based on the waterflood indication curve;
and calculating the reservoir parameters by using the initial time water-oil ratio according to the water injection indication curve and a pre-constructed water injection indication model.
A reservoir parameter calculation device, wherein the reservoir parameters comprise well control reserves and initial time water volume; the device comprises:
the parameter acquisition module is used for acquiring at least one group of formation pressure parameters and water injection volume parameters;
the curve construction module is used for constructing a water injection indication curve according to the formation pressure parameter and the water injection volume parameter;
the water-oil ratio calculation module is used for calculating the water-oil ratio corresponding to the reservoir at the initial moment based on the water injection indication curve;
and the reservoir parameter calculation module is used for calculating the reservoir parameters by using the initial time water-oil ratio according to the water injection indication curve and a pre-constructed water injection indication model.
A reservoir parameter calculation apparatus, the apparatus comprising a memory and a processor;
the memory to store computer program instructions;
the processor to execute the computer program instructions to implement the steps of: acquiring at least one group of formation pressure parameters and water injection volume parameters; constructing a water injection indication curve according to the formation pressure parameter and the water injection volume parameter; calculating an initial time water-oil ratio corresponding to a reservoir based on the waterflood indication curve; and calculating the reservoir parameters by using the initial time water-oil ratio according to the water injection indication curve and a pre-constructed water injection indication model, wherein the reservoir parameters comprise well control reserve and initial time water volume.
According to the technical scheme provided by the embodiment of the specification, after the water injection indication curve is constructed by using the formation pressure parameter and the water injection volume parameter, the embodiment of the specification calculates the corresponding initial time water-oil ratio based on the water injection indication curve, and further calculates the corresponding reservoir parameter by using the initial time water-oil ratio. According to the method, the water-oil ratio at the initial moment is considered in the process of calculating by using the model, so that the calculation by using the model can better meet the requirements in practical application, and the corresponding geological parameters can be calculated more accurately.
Drawings
In order to more clearly illustrate the embodiments of the present specification or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments described in the specification, and other drawings can be obtained by those skilled in the art without creative efforts.
FIG. 1 is a flow chart of a method for reservoir parameter calculation according to an embodiment of the present disclosure;
FIG. 2 is a block diagram of a reservoir parameter calculation apparatus according to an embodiment of the present disclosure;
fig. 3 is a block diagram of a reservoir parameter calculation device according to an embodiment of the present disclosure.
Detailed Description
The technical solutions in the embodiments of the present disclosure will be clearly and completely described below with reference to the drawings in the embodiments of the present disclosure, and it is obvious that the described embodiments are only a part of the embodiments of the present disclosure, and not all of the embodiments. All other embodiments obtained by a person of ordinary skill in the art based on the embodiments in the present specification without any creative effort shall fall within the protection scope of the present specification.
A reservoir parameter calculation method according to an embodiment of the present disclosure is described below with reference to fig. 1. The execution main body of the method is computer equipment, and the computer equipment comprises but is not limited to a server, an all-in-one machine, an industrial personal computer and a PC. The method specifically comprises the following steps:
s110: at least one set of formation pressure parameters and water injection volume parameters is obtained.
The formation pressure parameter is used to represent the pressure of fluid in the reservoir. When the reservoir is not developed, the pressure of all parts in the reservoir reaches balance, and when the reservoir is exploited, the formation pressure in the reservoir is continuously changed along with operations such as crude oil extraction, water injection into the reservoir and the like. Based on the formation pressure, corresponding measures can be taken to ensure the efficiency and the oil production. Formation pressure parameters may be obtained by direct measurement.
The water injection volume parameter is used to indicate the volume of water injected into the formation when the crude oil is produced by means of water injection.
In the practical application process, water is often injected into the reservoir for multiple times in order to maintain the balance in the reservoir. Therefore, after each round of water injection, the formation pressure parameters and the water injection volume parameters corresponding to different rounds can be measured respectively, and then a plurality of groups of formation pressure parameters and corresponding water injection volume parameters can be obtained. The acquisition of the parameters of the plurality of rounds can be beneficial to further solving other parameters in the subsequent process.
S120: and constructing a water injection indication curve according to the formation pressure parameter and the water injection volume parameter.
The water injection indication curve represents the relationship between the formation pressure parameter and the water injection volume parameter under steady flow conditions. The relationship between the formation pressure parameter and the water injection volume parameter may be represented by the water injection indicator curve, for example, a linear relationship that can be expressed as a function. A corresponding water filling indication curve is determined based on a linear relationship between the two.
In one embodiment, the water filling indication curve may be P ═ Po+K×WeWherein P is the formation pressure parameter, PoIs the formation pressure at the initial momentThe parameter K is the slope of the water injection indication curve WeAnd the volume parameter of the water injection. Therefore, a corresponding water injection indication curve may be constructed based on the collected formation pressure parameters and water injection reference parameters.
The water-filling indication curve corresponds to a water-filling indication model, and the water-filling indication curve can determine a specific form according to the water-filling indication model.
In one embodiment, the waterflooding indication model is
Wherein P is the formation pressure parameter, PoAs a parameter of formation pressure at the initial moment, WeFor the volume parameter of water injection, VoiIs the initial oil volume, CoIs the oil body coefficient, R is the initial time water-oil ratio, CwIs the water coefficient. In the water injection indication model, the relation between the formation pressure parameter and the water injection volume parameter is a linear function. Therefore, based on the water filling indication model, a water filling indication curve can be determined as P ═ Po+K×WeWherein P is the formation pressure parameter, PoIs a formation pressure parameter at an initial moment, K is the slope of the water injection indication curve, WeAnd the volume parameter of the water injection. Under the condition that formation pressure parameters and water injection volume parameters in different rounds are obtained through measurement, a water injection indication curve can be sequentially constructed by using data of different rounds.
The derivation of the waterflood indication model is briefly described below. In the reservoir, the volume V of the multi-cavern-containing volume is in addition to the medium in the stratump＝Voi+VwiIn the formula, VoiVolume of crude oil in reservoir at initial moment, VwiThe volume of water in the reservoir at the initial moment, after flooding, the formation pressure rises, Vp＝Voi+Vwi+We×BwIn the formula WeAs a volume parameter of water injection, BwThe volume coefficient of water injection can be ignored in practical application, and the volume coefficient of the water injected from the earth surface and the volume change of the multi-cave constant volume bodyChange to order BwWhen 1, then Vp＝Vo+Vw+WeIn the formula, VoIs the volume of crude oil in the reservoir, VwIs the volume of water in the reservoir. And is also provided with
And
in the formula, CoIs the oil volume coefficient, CwIs the water body coefficient, and Δ P is the difference of stratum variation, Δ VoIs the volume change of crude oil in the reservoir, delta VwIs the volume change of water in the reservoir, VoIs the volume of crude oil in the reservoir, VwThe volume of the water body in the reservoir is converted to obtain the delta V respectivelyo＝Voi-Vo＝Co×Voix.DELTA.P and Δ Vw＝Vwi-Vw＝Cw×Vwix.DELTA.P, and further W can be obtainede＝ΔVo+ΔVw＝Co×Voi×ΔP+Cw×Vwix.DELTA.P, then converted to
Because the water-oil ratio R is V at the initial momentwi/VoiThen, then
Thereby, a corresponding water filling indication model is obtained, and a corresponding water filling indication curve can be determined based on the water filling indication model.
Based on the expression of the water injection indication curve, after the specific data of the formation pressure parameter and the water injection volume parameter are obtained through measurement, the formation pressure parameter and the water injection volume parameter can be labeled in a coordinate system, and the water injection indication curve is drawn based on the formation pressure parameter and the water injection volume parameter.
S130: and calculating the water-oil ratio corresponding to the reservoir at the initial moment based on the water injection indication curve.
The initial time water to oil ratio is the ratio between water and oil in the reservoir when the reservoir is not flooded. In the original state of the reservoir, the elastic energy of the water body in the reservoir can cause certain influence on other parameters, and needs to be considered. In addition, the calculation of the geological parameters is carried out under the condition of considering the water-oil ratio at the initial moment, so that different initial conditions corresponding to different reservoirs can be considered, and the method has more practical application value.
In one embodiment, the initial time water-oil ratio corresponding to the reservoir may be calculated by first obtaining at least one set of slopes corresponding to the waterflood indication curve and then using the at least one set of slopes and the waterflood oil production to calculate the initial time water-oil ratio corresponding to the reservoir.
In practical application, water injection into a reservoir is divided into a plurality of different turns, and due to the influence caused by different geological conditions, the slopes of water injection indication curves corresponding to the different turns may have certain differences. The at least one set of slopes may thus be slopes corresponding to different water injection runs, respectively, i.e. slopes corresponding to different sets of formation pressure parameters and water injection volume parameters.
The calculation of the initial time water-oil ratio corresponding to the reservoir using the at least one set of slopes and the water injection and oil production may specifically be using a formula
Calculating the initial time water-oil ratio corresponding to the reservoir, wherein R is the initial time water-oil ratio, KnThe slope of the nth set of water injection indication curves, Kn-1The slope of the water injection indication curve for the n-1 th group,
for the crude oil collection volume between the n-1 st water injection and the n-th water injection, CoIs the oil volume coefficient, CwAnd n is the water body coefficient, and the water injection turns into the reservoir.
The derivation of the above calculation formula is briefly described below. As can be seen from the introduction of the water filling indication model in step S120, the slope of the water filling indication curve
Then
In the formula (I), the compound is shown in the specification,
the difference in total volume of crude oil in the reservoir between the nth water injection and the (n-1) th water injection,
the total volume of crude oil in the reservoir after n-1 rounds of water injection,
total volume of crude oil in reservoir after nth water injection, KnThe slope of the nth set of water injection indication curves, Kn-1Slope of water injection indication curve for group n-1, CoIs the oil body coefficient, R is the initial time water-oil ratio, CwAnd n is the water body coefficient, and the water injection turns into the reservoir. Let Δ V for ease of calculationon＝Npon-1，Npon-1 is the volume of the crude oil produced in the water injection process of the n-1 th round. Then the above formula is converted to obtain
Namely, the oil-water ratio at the initial moment can be obtained by measuring the volume of the collected crude oil and the slope of the curve corresponding to the turn.
According to the method, under the condition that the volume parameters of the collected crude oil are obtained, the water-oil ratio of the reservoir at the initial moment can be directly calculated, so that the difference between reservoir parameters under different conditions is considered, and the accuracy of reservoir parameter calculation is improved.
S140: and calculating the reservoir parameters by using the initial time water-oil ratio according to the water injection indication curve and a pre-constructed water injection indication model.
After the water injection indication curve and the pre-constructed water injection indication model are obtained, the water-oil ratio at the initial moment obtained through calculation is combined, and the reservoir parameters of response can be calculated.
Reservoir parameters include well-controlled reserves and initial time water volumes. The well control reserve is used to represent the reserve of crude oil in the reservoir at an initial time, and the initial time water volume is used to represent the volume of water in the reservoir at the initial time. Through the well control reserves and the initial moment water volume, the quality of the reservoir can be effectively evaluated, and the exploration and development process is convenient to carry out. In practical applications, the reservoir parameters are not limited to the above examples, and the reservoir parameters calculated by combining the waterflood indicating curve and the waterflood indicating model in the embodiments of the present specification all belong to the protection scope of the present application.
In one embodiment, calculating the reservoir parameters may be calculating an initial time oil volume corresponding to the reservoir according to the waterflood indicating curve and a pre-constructed waterflood indicating model, and then calculating the reservoir parameters by using the initial time oil volume.
Specifically, according to the water injection indication curve P ═ Po+K×WeAnd the pre-constructed waterflooding indication model
The calculation formula of the oil body volume at the initial moment can be determined as
Wherein P is the formation pressure parameter, K is the slope of the water injection indication curve, PoAs a parameter of formation pressure at the initial moment, WeFor the volume parameter of water injection, VoiIs the initial oil volume, CoIs the oil body coefficient, R is the initial time water-oil ratio, CwIs the water coefficient. In obtainingAfter the slope K of the water injection indication curve and the water-oil ratio R at the initial moment, converting the formula into
Therefore, the volume of the oil body at the initial moment is obtained.
In the case where the geological parameter is a well-controlled reserve, the formula W ═ B may be usedoi×VoiCalculating well control reserve, wherein W is the well control reserve, BoiVolume coefficient of crude oil at initial time, VoiIs the volume of oil body at the initial moment.
Under the condition that the geological parameter is the volume of the water body at the initial moment, a formula V can be utilizedwi＝R×VoiCalculating the volume of the water body at the initial moment, wherein V iswiThe volume of the water body at the initial moment, R is the water-oil ratio at the initial moment, VoiIs the volume of oil body at the initial moment.
It can be seen from the above example that, in combination with the initial time water-oil ratio, after the initial time oil volume is calculated, other reservoir parameters can be further calculated, so that the range of parameters capable of realizing accurate calculation is expanded.
According to the method, under the condition that the initial time water-oil ratio is obtained through calculation, the initial time water-oil ratio is applied to the geological parameter calculation process, so that the actual condition of the reservoir is further applied, different conditions of the geological parameters under different reservoir conditions are met, the calculation result is more practical, and the aim of accurately calculating the geological parameters is fulfilled.
An embodiment of a reservoir parameter calculation apparatus provided in the computer device is described below with reference to fig. 2, where the apparatus includes:
a parameter obtaining module 210, configured to obtain at least one set of formation pressure parameters and water injection volume parameters;
a curve construction module 220, configured to construct a water injection indication curve according to the formation pressure parameter and the water injection volume parameter;
a water-oil ratio calculation module 230, configured to calculate a water-oil ratio at an initial time corresponding to the reservoir based on the waterflood indication curve;
and the reservoir parameter calculation module 240 is configured to calculate the reservoir parameters by using the initial time water-oil ratio according to the water injection indication curve and a pre-constructed water injection indication model.
A reservoir parameter calculation device including a memory and a processor according to an embodiment of the present disclosure is described below with reference to fig. 3.
In this embodiment, the memory may be implemented in any suitable manner. For example, the memory may be a read-only memory, a mechanical hard disk, a solid state disk, a U disk, or the like. The memory may be used to store computer instructions.
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. The processor may execute the computer instructions to perform the steps of: acquiring at least one group of formation pressure parameters and water injection volume parameters; constructing a water injection indication curve according to the formation pressure parameter and the water injection volume parameter; calculating an initial time water-oil ratio corresponding to a reservoir based on the waterflood indication curve; and calculating the reservoir parameters by using the initial time water-oil ratio according to the water injection indication curve and a pre-constructed water injection indication model, wherein the reservoir parameters comprise well control reserve and initial time water volume.
In the 90 s of the 20 th century, improvements in a technology could clearly distinguish between improvements in hardware (e.g., improvements in circuit structures such as diodes, transistors, switches, etc.) and improvements in software (improvements in process flow). However, as technology advances, many of today's process flow improvements have been seen as direct improvements in hardware circuit architecture. Designers almost always obtain the corresponding hardware circuit structure by programming an improved method flow into the hardware circuit. Thus, it cannot be said that an improvement in the process flow cannot be realized by hardware physical modules. For example, a Programmable Logic Device (PLD), such as a Field Programmable Gate Array (FPGA), is an integrated circuit whose Logic functions are determined by programming the Device by a user. A digital system is "integrated" on a PLD by the designer's own programming without requiring the chip manufacturer to design and fabricate application-specific integrated circuit chips. Furthermore, nowadays, instead of manually making an integrated Circuit chip, such Programming is often implemented by "logic compiler" software, which is similar to a software compiler used in program development and writing, but the original code before compiling is also written by a specific Programming Language, which is called Hardware Description Language (HDL), and HDL is not only one but many, such as abel (advanced Boolean Expression Language), ahdl (alternate Language Description Language), traffic, pl (core unified Programming Language), HDCal, JHDL (Java Hardware Description Language), langue, Lola, HDL, laspam, hardsradware (Hardware Description Language), vhjhd (Hardware Description Language), and vhigh-Language, which are currently used in most popular applications. It will also be apparent to those skilled in the art that hardware circuitry that implements the logical method flows can be readily obtained by merely slightly programming the method flows into an integrated circuit using the hardware description languages described above.
The systems, devices, modules or units illustrated in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions. One typical implementation device is a computer. In particular, the computer may be, for example, a personal computer, a laptop computer, a cellular telephone, a camera phone, a smartphone, a personal digital assistant, a media player, a navigation device, an email device, a game console, a tablet computer, a wearable device, or a combination of any of these devices.
From the above description of the embodiments, it is clear to those skilled in the art that the present specification can be implemented by software plus a necessary general hardware platform. Based on such understanding, the technical solutions of the present specification may be essentially or partially implemented in the form of software products, which may be stored in a storage medium, such as ROM/RAM, magnetic disk, optical disk, etc., and include instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) to execute the methods described in the embodiments or some parts of the embodiments of the present specification.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, for the system embodiment, since it is substantially similar to the method embodiment, the description is simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The description is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
This description 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 specification 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.
While the specification has been described with examples, those skilled in the art will appreciate that there are numerous variations and permutations of the specification that do not depart from the spirit of the specification, and it is intended that the appended claims include such variations and modifications that do not depart from the spirit of the specification.
Claims (10)
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010020558.1A CN111191183B (en) | 2020-01-09 | 2020-01-09 | A kind of reservoir parameter calculation method, device and equipment |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202010020558.1A CN111191183B (en) | 2020-01-09 | 2020-01-09 | A kind of reservoir parameter calculation method, device and equipment |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN111191183A true CN111191183A (en) | 2020-05-22 |
| CN111191183B CN111191183B (en) | 2022-02-11 |
Family
ID=70709882
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202010020558.1A Expired - Fee Related CN111191183B (en) | 2020-01-09 | 2020-01-09 | A kind of reservoir parameter calculation method, device and equipment |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN111191183B (en) |
Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2315863C2 (en) * | 2005-12-06 | 2008-01-27 | Александр Сергеевич Трофимов | Method for multipay field survey and development |
| CN104179499A (en) * | 2013-05-27 | 2014-12-03 | 中国石油化工股份有限公司 | Numerical simulation method considering oil reservoir parameter time variant |
| CN106677750A (en) * | 2017-01-11 | 2017-05-17 | 西南石油大学 | Carbonate rock reservoir karst cave-fracture reservoir body water injection indication curve interpretation model |
| CN106837273A (en) * | 2017-01-11 | 2017-06-13 | 西南石油大学 | The double solution cavity Reservoir Body water injection indication curve interpretation models of Carbonate Reservoir |
| CN107807410A (en) * | 2017-09-29 | 2018-03-16 | 中国石油化工股份有限公司 | Reservoir geophysical sensitive parameter method for optimizing and system |
| CN108133087A (en) * | 2017-12-11 | 2018-06-08 | 常州大学 | A kind of Gas-water phases seepage stress sensitivity reservoir original permeability inversion method |
| CN109697538A (en) * | 2017-10-22 | 2019-04-30 | 哈尔滨石油学院 | Carbonate Reservoir Caves-constant volume physical efficiency amount indicative curve interpretation model |
-
2020
- 2020-01-09 CN CN202010020558.1A patent/CN111191183B/en not_active Expired - Fee Related
Patent Citations (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2315863C2 (en) * | 2005-12-06 | 2008-01-27 | Александр Сергеевич Трофимов | Method for multipay field survey and development |
| CN104179499A (en) * | 2013-05-27 | 2014-12-03 | 中国石油化工股份有限公司 | Numerical simulation method considering oil reservoir parameter time variant |
| CN106677750A (en) * | 2017-01-11 | 2017-05-17 | 西南石油大学 | Carbonate rock reservoir karst cave-fracture reservoir body water injection indication curve interpretation model |
| CN106837273A (en) * | 2017-01-11 | 2017-06-13 | 西南石油大学 | The double solution cavity Reservoir Body water injection indication curve interpretation models of Carbonate Reservoir |
| CN107807410A (en) * | 2017-09-29 | 2018-03-16 | 中国石油化工股份有限公司 | Reservoir geophysical sensitive parameter method for optimizing and system |
| CN109697538A (en) * | 2017-10-22 | 2019-04-30 | 哈尔滨石油学院 | Carbonate Reservoir Caves-constant volume physical efficiency amount indicative curve interpretation model |
| CN108133087A (en) * | 2017-12-11 | 2018-06-08 | 常州大学 | A kind of Gas-water phases seepage stress sensitivity reservoir original permeability inversion method |
Non-Patent Citations (5)
| Title |
|---|
| 梅胜文等: "缝洞型碳酸盐岩注水指示曲线理论改进新模型", 《长江大学学报(自科版)》 * |
| 谭亦然: "塔河缝洞型油藏AD4井区井间连通性研究", 《中国优秀博硕士学位论文全文数据库（硕士）-工程科技I辑》 * |
| 谭文才: "低渗储层裂缝预测方法研究 ——以白豹油田白209井区为例", 《中国优秀博硕士学位论文全文数据库（硕士）-基础科学辑》 * |
| 陈羊羊: "低渗透油藏分层注水水驱前缘分析及仿真", 《中国优秀博硕士学位论文全文数据库（硕士）-工程科技II辑》 * |
| 马旭: "缝洞型碳酸盐岩油藏注水替油井失效治理研究", 《中国优秀博硕士学位论文全文数据库（硕士）-工程科技I辑》 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN111191183B (en) | 2022-02-11 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN108920852B (en) | Method for determining injection-production well spacing of ultra-low permeability reservoir | |
| WO2024148671A1 (en) | Gas-liquid numerical simulation drag force correction method and system, device, and medium | |
| CN107882541B (en) | Water flooding flow field generation method and device | |
| CN104453882A (en) | Method and device for determining movable crude oil reserve of tight reservoir | |
| CN108227032B (en) | Determination method and device for ground stress | |
| CN110083852A (en) | Method and device for determining bottom hole pressure and storage medium | |
| CN109918769A (en) | A Method of Calculating Unsteady Water Influx in Fracture-cavity Reservoirs Using Instantaneous Equation | |
| CN112377182A (en) | Method and device for determining parameters of large-size hole crack type carbonate rock reservoir body | |
| CN107246900B (en) | Method and device for determining oil-water interface position | |
| CN111191183B (en) | A kind of reservoir parameter calculation method, device and equipment | |
| CN109555514B (en) | Tracer interpretation model of fracture-cavity reservoir and its construction method and application | |
| Zhou et al. | A well‐balanced stable generalized Riemann problem scheme for shallow water equations using adaptive moving unstructured triangular meshes | |
| CN109978303B (en) | Method and device for determining exploitation measures of heavy oil reservoir and storage medium | |
| CN113536218B (en) | A method and device for calculating the compressibility coefficient of rock pore volume | |
| CN113610292A (en) | A method and device for determining dynamic reserves of fracturing horizontal wells in tight gas reservoirs | |
| CN108629463B (en) | Ground stress change prediction method and device | |
| CN111696000A (en) | Gas well production allocation method, device and equipment | |
| CN115217467A (en) | Method and device for determining breakthrough time of bottom water of multi-medium bottom water gas reservoir horizontal well | |
| CN105649610B (en) | Method and device for acquiring oil reservoir pressure | |
| CN111797507A (en) | Method for determining reservoir water level descending rate threshold value in reservoir area landslide stable state | |
| CN112443317A (en) | Method and system for determining wellhead pressure of simulated chemical flooding injection well | |
| Fredj et al. | Evaluation of a hybrid Eulerian-Lagrangian method for free surface flows with material transport | |
| CN119539549A (en) | A method, device, electronic equipment and medium for evaluating oil reservoir reserve production potential | |
| CN114060017B (en) | Low-permeability oil reservoir vertical well volume transformation method and transformation system | |
| CN109915124B (en) | A Method of Calculating Quasi-steady-state Water Influx in Fracture-cavity Reservoirs Using Global Equation |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant | ||
| CF01 | Termination of patent right due to non-payment of annual fee | ||
| CF01 | Termination of patent right due to non-payment of annual fee |
Granted publication date: 20220211 |