CN107939371B - Method and device for determining encryption feasibility of well pattern - Google Patents
Method and device for determining encryption feasibility of well pattern Download PDFInfo
- Publication number
- CN107939371B CN107939371B CN201710974861.3A CN201710974861A CN107939371B CN 107939371 B CN107939371 B CN 107939371B CN 201710974861 A CN201710974861 A CN 201710974861A CN 107939371 B CN107939371 B CN 107939371B
- Authority
- CN
- China
- Prior art keywords
- well pattern
- encrypted
- gas production
- density
- well
- 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.)
- Active
Links
- 238000000034 method Methods 0.000 title claims abstract description 47
- 238000004519 manufacturing process Methods 0.000 claims abstract description 142
- 238000011084 recovery Methods 0.000 claims abstract description 122
- 230000001186 cumulative effect Effects 0.000 claims description 52
- 230000000638 stimulation Effects 0.000 claims description 11
- 230000008901 benefit Effects 0.000 abstract description 4
- 239000007789 gas Substances 0.000 description 212
- 230000006872 improvement Effects 0.000 description 8
- 238000011161 development Methods 0.000 description 6
- 230000006870 function Effects 0.000 description 5
- 230000008569 process Effects 0.000 description 5
- 238000004088 simulation Methods 0.000 description 5
- 238000005516 engineering process Methods 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 230000003068 static effect Effects 0.000 description 4
- 238000010586 diagram Methods 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 230000003416 augmentation Effects 0.000 description 1
- 230000005540 biological transmission Effects 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 238000004891 communication Methods 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000005055 memory storage 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
- 238000013517 stratification Methods 0.000 description 1
- 230000001052 transient effect Effects 0.000 description 1
- 239000002699 waste material Substances 0.000 description 1
Classifications
-
- 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
- E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
- G06Q50/00—Information and communication technology [ICT] specially adapted for implementation of business processes of specific business sectors, e.g. utilities or tourism
- G06Q50/06—Energy or water supply
Landscapes
- Engineering & Computer Science (AREA)
- Business, Economics & Management (AREA)
- Physics & Mathematics (AREA)
- Health & Medical Sciences (AREA)
- Economics (AREA)
- Mining & Mineral Resources (AREA)
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Health & Medical Sciences (AREA)
- Theoretical Computer Science (AREA)
- Strategic Management (AREA)
- Tourism & Hospitality (AREA)
- Marketing (AREA)
- General Business, Economics & Management (AREA)
- General Physics & Mathematics (AREA)
- Primary Health Care (AREA)
- Human Resources & Organizations (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Water Supply & Treatment (AREA)
- Public Health (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
The embodiment of the application discloses a method and a device for determining encryption feasibility of a well pattern. The method comprises the following steps: determining the average accumulated gas production and the recovery ratio corresponding to the initial well pattern density, and determining the average accumulated gas production and the recovery ratio corresponding to the encrypted well pattern density; calculating the yield increasing gas of the encrypted well corresponding to the density of the encrypted well pattern according to the average accumulated gas production corresponding to the density of the initial well pattern and the average accumulated gas production corresponding to the density of the encrypted well pattern, and calculating the yield increment corresponding to the density of the encrypted well pattern according to the yield corresponding to the density of the initial well pattern and the yield corresponding to the density of the encrypted well pattern; and determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the density of the encrypted well pattern. The technical scheme provided by the embodiment of the application can provide a reasonable basis for well pattern encryption, thereby improving the recovery ratio and ensuring the economic benefit.
Description
Technical Field
The application relates to the technical field of oil and gas reservoir development, in particular to a method and a device for determining encryption feasibility of a well pattern.
Background
Hypotonic-tight sandstone gas reservoirs are an important type of gas reservoir. Because the effective reservoir scale in the hypotonic-tight sandstone gas reservoir is small, a fixed well pattern development mode or a depletion development mode is usually adopted for initial development, and in the initial development process, the initial well pattern is often difficult to control all reserves in the hypotonic-tight sandstone gas reservoir, and the well pattern encryption is usually required in the middle and later development stages so as to improve the recovery ratio of the gas reservoir.
However, in the practical application process of well pattern encryption on the well pattern in the initial stage, the well pattern encryption may be sparse or dense, and when the well pattern encryption is sparse, the degree of control over the reserves on the plane may be insufficient; when the well pattern is denser, severe cross-well interference may occur, thereby affecting the ultimate economic benefit. Therefore, there is a need for a method of determining the feasibility of encrypting the well pattern of a hypotonic-tight sandstone reservoir in order to perform a reasonable well pattern encryption.
Disclosure of Invention
The embodiment of the application aims to provide a method and a device for determining well pattern encryption feasibility so as to provide a reasonable basis for well pattern encryption, thereby improving the recovery rate and ensuring the economic benefit.
In order to solve the above technical problem, an embodiment of the present application provides a method and an apparatus for determining encryption feasibility of a well pattern, which are implemented as follows:
a method of determining well pattern encryption feasibility, providing an initial well pattern density and an encrypted well pattern density for a destination gas reservoir, wherein the encrypted well pattern density represents a well pattern density after well pattern encryption of the destination gas reservoir based on the initial well pattern density; the method comprises the following steps:
determining the average accumulated gas production and the recovery factor corresponding to the initial well pattern density, and determining the average accumulated gas production and the recovery factor corresponding to the encrypted well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir;
calculating the encrypted well stimulation gas yield corresponding to the encrypted well pattern density according to the average accumulated gas yield corresponding to the initial well pattern density and the average accumulated gas yield corresponding to the encrypted well pattern density, and calculating the recovery factor increment corresponding to the encrypted well pattern density according to the recovery factor corresponding to the initial well pattern density and the recovery factor corresponding to the encrypted well pattern density;
and determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density.
In the preferred scheme, the yield increasing gas volume of the encrypted well corresponding to the density of the encrypted well pattern is calculated by adopting the following formula:
A＝(n2×q2-n1×q1)/(n2-n1)
wherein A represents the additionProduction increasing gas volume n of encrypted well corresponding to density of dense well pattern1And n2Representing the initial and the encrypted pattern densities, q, respectively1And q is2And respectively representing the average accumulated gas production corresponding to the initial well pattern density and the average accumulated gas production corresponding to the density of the encrypted well pattern.
In a preferred scheme, the difference value between the density of the encrypted well pattern and the density of the initial well pattern is 1 hole/square kilometer.
In a preferred embodiment, the calculating a recovery factor increment corresponding to the density of the encrypted well pattern includes:
and taking the difference value obtained by subtracting the recovery factor corresponding to the initial well pattern density from the recovery factor corresponding to the density of the encrypted well pattern as the recovery factor increment corresponding to the density of the encrypted well pattern.
In a preferred embodiment, the determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density includes:
determining an accumulated gas production threshold value and an encrypted well yield increase threshold value of the target gas reservoir;
and determining the well pattern encryption feasibility of the target gas reservoir based on a preset recovery factor increment threshold, the accumulated gas production threshold, the encrypted well yield increase threshold, and the average accumulated gas production, the encrypted well yield increase and the recovery factor increment corresponding to the encrypted well pattern density.
In a preferred embodiment, the determining the threshold of the cumulative gas production rate of the target oil reservoir and the threshold of the yield increase of the infill well comprises:
acquiring the current gas price and the comprehensive investment cost of a single gas well of the target gas reservoir;
determining the threshold value of the accumulated gas production rate according to a preset threshold value of the profitability, the current gas price and the comprehensive investment cost of the single gas well of the target gas reservoir;
and determining the yield increase threshold of the encrypted well according to the current gas price and the comprehensive investment cost of the single gas well of the target gas reservoir.
In a preferred embodiment, the preset profitability threshold is 12%.
Preferably, the pre-determined recovery factor augmentation threshold is 5 percent.
In a preferred embodiment, the determining the well pattern encryption feasibility of the target gas reservoir based on a preset recovery factor increment threshold, the cumulative gas production threshold, the encrypted well yield increase threshold, and an average cumulative gas production, an encrypted well yield increase and a recovery factor increment corresponding to the encrypted well pattern density includes:
and when the average accumulated gas production corresponding to the density of the encrypted well pattern is greater than the accumulated gas production threshold, the gas production of the encrypted well is greater than the yield increasing threshold of the encrypted well, and the recovery factor increment is greater than the preset recovery factor increment threshold, determining that the well pattern encryption feasibility result of the target gas reservoir is feasible.
An apparatus for determining well pattern encryption feasibility, the apparatus providing an initial well pattern density and an encrypted well pattern density for a target gas reservoir, wherein the encrypted well pattern density represents a well pattern density after a well pattern encryption of the target gas reservoir based on the initial well pattern density; the device comprises: the system comprises an accumulative gas production and recovery rate determining module, a gas production and recovery rate increment determining module and a well pattern encryption feasibility determining module; wherein,
the cumulative gas production and recovery rate determining module is used for determining the average cumulative gas production and recovery rate corresponding to the initial well pattern density and determining the average cumulative gas production and recovery rate corresponding to the encrypted well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir;
the yield increasing and recovery factor increment determining module is used for calculating the encrypted well yield corresponding to the encrypted well pattern density according to the average accumulated gas production corresponding to the initial well pattern density and the average accumulated gas production corresponding to the encrypted well pattern density, and calculating the recovery factor increment corresponding to the encrypted well pattern density according to the recovery factor corresponding to the initial well pattern density and the recovery factor corresponding to the encrypted well pattern density;
and the well pattern encryption feasibility determining module is used for determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density.
The embodiment of the application provides a method and a device for determining encryption feasibility of a well pattern, which can determine average accumulated gas production and recovery ratio corresponding to initial well pattern density, and determine average accumulated gas production and recovery ratio corresponding to encrypted well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir; calculating the yield of the encrypted well corresponding to the density of the encrypted well pattern according to the average accumulated gas production corresponding to the density of the initial well pattern and the average accumulated gas production corresponding to the density of the encrypted well pattern, and calculating the recovery factor increment corresponding to the density of the encrypted well pattern according to the recovery factor corresponding to the density of the initial well pattern and the recovery factor corresponding to the density of the encrypted well pattern; and determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density, so that a reasonable basis for well pattern encryption can be provided for the target gas reservoir, the recovery factor is improved, and the economic benefit is ensured.
Drawings
In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort.
FIG. 1 is a flow chart of an embodiment of a method of determining well pattern encryption feasibility of the present application;
FIG. 2 is a block diagram of an embodiment of the present apparatus for determining the encryption feasibility of a well pattern.
Detailed Description
The embodiment of the application provides a method and a device for determining encryption feasibility of a well pattern.
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
The present application provides a method of determining well pattern encryption feasibility. The method of determining the well pattern encryption feasibility provides an initial well pattern density and an encrypted well pattern density for a target gas reservoir, wherein the encrypted well pattern density represents a well pattern density after well pattern encryption is performed on the target gas reservoir on the basis of the initial well pattern density.
In this embodiment, the destination gas reservoir may refer to a gas reservoir for which the encryption feasibility of the well pattern has not yet been determined. The target gas reservoir may be a hypotonic-tight sandstone gas reservoir.
In this embodiment, the difference between the encrypted pattern density and the initial pattern density may be 1 hole per square kilometer. For example, the initial pattern density may be 2 openings per square kilometer, and the pattern density of the target reservoir may be densified to a densified pattern density of 3 openings per square kilometer.
FIG. 1 is a flow chart of an embodiment of a method of determining well pattern encryption feasibility of the present application. As shown in fig. 1, the method for determining the confidential feasibility of a well pattern comprises the following steps.
Step S101: determining the average accumulated gas production and the recovery factor corresponding to the initial well pattern density, and determining the average accumulated gas production and the recovery factor corresponding to the encrypted well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir.
In this embodiment, a gas reservoir numerical simulation method may be used to determine the average cumulative gas production and recovery factor corresponding to the initial well pattern density, and to determine the average cumulative gas production and recovery factor corresponding to the consolidated well pattern density. Wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir. The target gas reservoir may include at least one gas well therein. Each gas well has a corresponding cumulative gas production.
In this embodiment, a gas reservoir numerical simulation method is adopted to determine the average cumulative gas production and the recovery factor corresponding to the initial well pattern density and determine the average cumulative gas production and the recovery factor corresponding to the encrypted well pattern density, which may specifically include, first, obtaining static parameters of gas wells in the target gas reservoir at different periods. Wherein the static parameters may include: well position of the gas well, well completion mode, well track, geological stratification data, well logging interpretation data, perforation parameters at different periods, gas well coring data, core observation data and the like. A geological model of the target gas reservoir may then be established based on the static parameters. Historical fitting can be performed on the initial geological model to obtain a historical fitting result of the target gas reservoir. And determining the numerical value of the target gas reservoir according to the historical fitting result of the target gas reservoir and the geological model, thereby completing the numerical simulation of the target gas reservoir. Finally, on the basis of the numerical simulation result of the target gas reservoir, according to the set production indexes such as the production mode of the gas well in the target gas reservoir (the production mode with constant pressure or constant output) and the waste output (less than 0.1 ten thousand square/day), the average cumulative gas production and the recovery factor corresponding to the initial well pattern density can be determined, and the average cumulative gas production and the recovery factor corresponding to the encrypted well pattern density can be determined.
For example, the target gas reservoir may be a gas reservoir selected in a hypotonic-tight sandstone gas field to have an abundance of 1.88 billion per square kilometer and an area of 14.6 square kilometers. And determining the average accumulated gas production and the recovery ratio of the target gas reservoir under different well pattern densities by adopting a gas reservoir numerical simulation method. Table 1 is the average cumulative gas production and recovery for the examples of this application at different well pattern densities.
TABLE 1 average cumulative gas production and recovery at different well pattern densities
Step S102: and calculating the yield increasing rate of the encrypted well corresponding to the density of the encrypted well pattern according to the average accumulated gas production rate corresponding to the density of the initial well pattern and the average accumulated gas production rate corresponding to the density of the encrypted well pattern, and calculating the recovery factor increment corresponding to the density of the encrypted well pattern according to the recovery factor corresponding to the density of the initial well pattern and the recovery factor corresponding to the density of the encrypted well pattern.
In this embodiment, according to the average accumulated gas production rate corresponding to the initial well pattern density and the average accumulated gas production rate corresponding to the encrypted well pattern density, the encrypted well gas production rate corresponding to the encrypted well pattern density may be calculated by using the following formula:
A＝(n2×q2-n1×q1)/(n2-n1)
wherein A represents the encrypted well production-increasing gas volume corresponding to the encrypted well pattern density, n1And n2Representing the initial and the encrypted pattern densities, q, respectively1And q is2And respectively representing the average accumulated gas production corresponding to the initial well pattern density and the average accumulated gas production corresponding to the density of the encrypted well pattern.
In this embodiment, the calculating the recovery factor increment corresponding to the encrypted pattern density may include calculating a recovery factor increment corresponding to the encrypted pattern density from the recovery factor corresponding to the initial pattern density and the recovery factor corresponding to the encrypted pattern density, and specifically, may include calculating a difference between the recovery factor corresponding to the encrypted pattern density and the recovery factor corresponding to the initial pattern density as the recovery factor increment corresponding to the encrypted pattern density.
For example, table 2 shows the gas and oil recovery increments for the infill wells calculated from the average cumulative gas and oil recovery in table 1 in the examples of this application. Wherein the difference between the density of the encrypted well pattern and the density of the initial well pattern may be 1 hole per square kilometer. When the initial well pattern density is 2 holes/square kilometer, the density of the encrypted well pattern is 3 holes/square kilometer, and the gas production and recovery factor increment of the encrypted well corresponding to the density of the encrypted well pattern are 2101.84 squares/hole and 11.18 percent respectively; when the initial well pattern density is 3 holes/square kilometer, the density of the encrypted well pattern is 4 holes/square kilometer, and the gas production and recovery factor increment of the encrypted well corresponding to the density of the encrypted well pattern are 1372.40 squares/hole and 7.30 percent respectively; and by analogy, when the initial well pattern density is 7 ports per square kilometer, the density of the encrypted well pattern is 8 ports per square kilometer, and the gas production and recovery factor increment of the encrypted well corresponding to the density of the encrypted well pattern are 191.76 ten thousand square meters and 1.02 percent respectively.
TABLE 2 increase in gas production and recovery for infill wells
Step S103: and determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density.
In this embodiment, determining the well pattern encryption feasibility of the target gas reservoir based on the average cumulative gas production, the encrypted well gas production yield and the recovery factor increment corresponding to the encrypted well pattern density may specifically include determining a cumulative gas production threshold and an encrypted well production yield threshold of the target gas reservoir. And determining the well pattern encryption feasibility of the target gas reservoir based on a preset recovery factor increment threshold, the accumulated gas production threshold and the encrypted well yield increase threshold, and the average accumulated gas production, the encrypted well yield increase and the recovery factor increment corresponding to the encrypted well pattern density. Wherein the preset delta recovery threshold may be 5 percent.
In this embodiment, determining the threshold of the cumulative gas production of the target reservoir and the threshold of the yield increase of the infill well may specifically include obtaining a current gas price and a single-gas-well comprehensive investment cost of the target gas reservoir. Wherein the current gas price represents the current price of the natural gas leaving the factory. The threshold value of the cumulative gas production rate can be determined according to a preset threshold value of the profitability, the current gas price and the comprehensive investment cost of the single gas well of the target gas reservoir. And determining the yield increase threshold of the encrypted well according to the current gas price and the comprehensive investment cost of the single gas well of the target gas reservoir.
In this embodiment, the lower limit of the threshold of cumulative gas production may be represented by the following formula:
wherein Q is1Representing the lower limit of the accumulated gas production threshold, a representing the single-well comprehensive investment cost of the target gas reservoir, b representing the current gas reservoirAnd c represents the preset profitability threshold. Wherein the preset profitability threshold may be 12%. The comprehensive investment cost of the single gas well is associated with parameters such as fixed investment cost, loan rate, loan term, sales tax, city construction related cost, resource tax and the like of the single gas well.
In this embodiment, the lower limit of the threshold of the yield increase of the infill well may be characterized by the following formula:
wherein Q is2And representing the lower limit of the accumulated gas production threshold, a representing the single-well comprehensive investment cost of the target gas reservoir, and b representing the current gas price.
In this embodiment, determining the well pattern encryption feasibility of the target gas reservoir based on the preset incremental recovery threshold, the cumulative gas production threshold, the infill stimulation threshold, and the average cumulative gas production, the infill stimulation, and the incremental recovery corresponding to the infill well pattern density may specifically include determining that the well pattern encryption feasibility result of the target gas reservoir is feasible, that is, the well pattern density of the target gas reservoir may be encrypted from the initial well pattern density to the infill well pattern density, when the average cumulative gas production corresponding to the infill well pattern density is greater than the cumulative gas production threshold, the infill well stimulation is greater than the infill stimulation threshold, and the incremental recovery is greater than the preset incremental recovery threshold. Otherwise, the outcome of the well pattern encryption feasibility of the destination reservoir may be determined to be infeasible.
For example, for the target gas reservoir in tables 1 and 2, the current gas price and the single-well composite investment cost for the target gas reservoir may be obtained. Wherein, the current gas price, namely the factory price of the natural gas is 1.15 yuan/square; the comprehensive investment cost of a single gas well is 920 ten thousand yuan. According to the economic profit standard of investment requirements, the preset profitability threshold is 12 percent, correspondingly, the cumulative gas production threshold is 1500 ten thousand square/port, and the yield increasing threshold of the encryption well is 1075 ten thousand square/port. The pre-determined recovery factor delta threshold is 5 percent.
When the initial well pattern density is 2 ports/square kilometer and the density of the encrypted well pattern is 3 ports/square kilometer, the average accumulated gas production rate corresponding to the density of the encrypted well pattern is 2845.07 and is greater than the threshold value of the accumulated gas production rate (1500 ten thousand square/port); the yield increasing gas volume of the encrypted well corresponding to the density of the encrypted well pattern is 2101.84 ten thousand squares/mouth and is larger than the yield increasing threshold value (1075 ten thousand squares/mouth) of the encrypted well; the recovery factor increment corresponding to the density of the encrypted well pattern is 11.18 percent and is larger than the preset recovery factor increment threshold value (5 percent); thus, the result of the well pattern encryption feasibility is feasible, i.e., the target reservoir has the potential to encrypt from 2 ports per square kilometer to 3 ports per square kilometer.
When the initial well pattern density is 3 openings/square kilometer and the density of the encrypted well pattern is 4 openings/square kilometer, the average accumulated gas production rate corresponding to the density of the encrypted well pattern is 2476.90 and is greater than the threshold value of the accumulated gas production rate (1500 ten thousand square/opening); the yield increasing gas volume of the encrypted well corresponding to the density of the encrypted well pattern is 1372.40 ten thousand squares/mouth and is larger than the yield increasing threshold value (1075 ten thousand squares/mouth) of the encrypted well; the recovery factor increment corresponding to the density of the encrypted well pattern is 7.30 percent and is larger than the preset recovery factor increment threshold value (5 percent); as such, the result of the well pattern encryption feasibility is viable, i.e., the target reservoir has the potential to encrypt from 3 ports per square kilometer to 4 ports per square kilometer.
When the initial well pattern density is 4 holes/square kilometer and the density of the encrypted well pattern is 5 holes/square kilometer, the average accumulated gas production rate corresponding to the density of the encrypted well pattern is 2177.79 and is greater than the threshold value of the accumulated gas production rate (1500 ten thousand square/hole); the yield increasing gas volume of the encrypted well corresponding to the density of the encrypted well pattern is 981.36 ten thousand squares/mouth, and is smaller than the yield increasing threshold value (1075 ten thousand squares/mouth) of the encrypted well; the recovery factor increment corresponding to the density of the encrypted well pattern is 5.22 percent and is larger than the preset recovery factor increment threshold value (5 percent); as such, the result of the well pattern encryption feasibility was not feasible, i.e., the destination reservoir did not have the potential to encrypt from 4 beats per square kilometer to 5 beats per square kilometer.
Combining the above results, it is feasible to pack the pattern density of the hypotonic-tight sandstone gas reservoir to 4 openings per square kilometer.
FIG. 2 is a block diagram of an embodiment of the present apparatus for determining the encryption feasibility of a well pattern. The means for determining the well pattern encryption feasibility provides an initial well pattern density and an encrypted well pattern density for a target gas reservoir, wherein the encrypted well pattern density represents a well pattern density after well pattern encryption is performed on the target gas reservoir based on the initial well pattern density. As shown in fig. 2, the means for determining the encryption feasibility of the well pattern may comprise: an accumulative gas production and recovery factor determination module 100, a gas production and recovery factor increment determination module 200, and a well pattern encryption feasibility determination module 300.
The cumulative gas production and recovery factor determination module 100 may be configured to determine an average cumulative gas production and recovery factor corresponding to the initial well pattern density, and determine an average cumulative gas production and recovery factor corresponding to the infixed well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir.
The gas production and recovery factor increment determining module 200 may be configured to calculate a gas production of the encrypted well corresponding to the density of the encrypted well pattern according to the average accumulated gas production corresponding to the density of the initial well pattern and the average accumulated gas production corresponding to the density of the encrypted well pattern, and calculate a recovery factor increment corresponding to the density of the encrypted well pattern according to a recovery factor corresponding to the density of the initial well pattern and a recovery factor corresponding to the density of the encrypted well pattern.
The well pattern encryption feasibility determining module 300 may be configured to determine the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production, and the recovery factor increment corresponding to the encrypted well pattern density.
The embodiment of the device for determining the encryption feasibility of the well pattern corresponds to the embodiment of the method for determining the encryption feasibility of the well pattern, so that the technical scheme of the embodiment of the method for determining the encryption feasibility of the well pattern can be realized, and the technical effect of the embodiment of the method can be obtained.
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.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may thus be considered a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The apparatuses and modules illustrated in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions.
For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, the functionality of the various modules may be implemented in the same one or more software and/or hardware implementations as the present application.
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. With this understanding in mind, the present solution, or portions thereof that contribute to the prior art, may be embodied in the form of a software product, which in a typical configuration includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory. The computer software product may include instructions for causing a computing device (which may be a personal computer, a server, or a network device, etc.) to perform the methods described in the various embodiments or portions of embodiments of the present application. The computer software product may be stored in a memory, which may include forms of volatile memory in a computer readable medium, Random Access Memory (RAM) and/or non-volatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). Memory is an example of a computer-readable medium. Computer-readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), Static Random Access Memory (SRAM), Dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), Read Only Memory (ROM), Electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), Digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information that can be accessed by a computing device. As defined herein, computer readable media does not include transitory computer readable media (transient media), such as modulated data signals and carrier waves.
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, as for the apparatus embodiment, since it is substantially similar to the method embodiment, the description is relatively simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
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.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the spirit of the application.
Claims (10)
1. A method of determining feasibility of well pattern encryption, wherein an initial well pattern density and an encrypted well pattern density are provided for a target reservoir, wherein the encrypted well pattern density represents a well pattern density after well pattern encryption of the target reservoir based on the initial well pattern density; the method comprises the following steps:
determining the average accumulated gas production and the recovery factor corresponding to the initial well pattern density, and determining the average accumulated gas production and the recovery factor corresponding to the encrypted well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir;
calculating the encrypted well stimulation gas yield corresponding to the encrypted well pattern density according to the average accumulated gas yield corresponding to the initial well pattern density and the average accumulated gas yield corresponding to the encrypted well pattern density, and calculating the recovery factor increment corresponding to the encrypted well pattern density according to the recovery factor corresponding to the initial well pattern density and the recovery factor corresponding to the encrypted well pattern density;
and determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density.
2. The method of claim 1, wherein the encrypted well stimulation gas volume for the encrypted well pattern density is calculated using the following equation:
A＝(n2×q2-n1×q1)/(n2-n1)
wherein A represents the encrypted well production-increasing gas volume corresponding to the encrypted well pattern density, n1And n2Representing the initial and the encrypted pattern densities, q, respectively1And q is2And respectively representing the average accumulated gas production corresponding to the initial well pattern density and the average accumulated gas production corresponding to the density of the encrypted well pattern.
3. The method of determining encryption feasibility of a well pattern of claim 2, wherein the difference between the encrypted well pattern density and the initial well pattern density is 1 hole per square kilometer.
4. The method of claim 1, wherein said calculating a recovery factor delta for said consolidated well pattern density comprises:
and taking the difference value obtained by subtracting the recovery factor corresponding to the initial well pattern density from the recovery factor corresponding to the density of the encrypted well pattern as the recovery factor increment corresponding to the density of the encrypted well pattern.
5. The method of claim 1, wherein determining the well pattern encryption feasibility of the target gas reservoir based on the average cumulative gas production, the infill stimulation and the recovery factor increment corresponding to the infill well pattern density comprises:
determining an accumulated gas production threshold value and an encrypted well yield increase threshold value of the target gas reservoir;
and determining the well pattern encryption feasibility of the target gas reservoir based on a preset recovery factor increment threshold, the accumulated gas production threshold, the encrypted well yield increase threshold, and the average accumulated gas production, the encrypted well yield increase and the recovery factor increment corresponding to the encrypted well pattern density.
6. The method of claim 5, wherein determining the cumulative gas production threshold and the infill stimulation threshold for the reservoir of interest comprises:
acquiring the current gas price and the comprehensive investment cost of a single gas well of the target gas reservoir;
determining the threshold value of the accumulated gas production rate according to a preset threshold value of the profitability, the current gas price and the comprehensive investment cost of the single gas well of the target gas reservoir;
and determining the yield increase threshold of the encrypted well according to the current gas price and the comprehensive investment cost of the single gas well of the target gas reservoir.
7. The method of determining encryption feasibility of a well pattern as claimed in claim 6, wherein the preset profitability threshold is 12 percent.
8. The method of determining feasibility of encryption of a well pattern according to claim 5, wherein the pre-determined delta recovery threshold is 5 percent.
9. The method for determining well pattern encryption feasibility of claim 5, wherein the determining the well pattern encryption feasibility of the target gas reservoir based on the pre-set incremental recovery threshold, the cumulative gas production threshold and the infill stimulation threshold, and the average cumulative gas production, infill stimulation and recovery incremental corresponding to the infill pattern density comprises:
and when the average accumulated gas production corresponding to the density of the encrypted well pattern is greater than the accumulated gas production threshold, the gas production of the encrypted well is greater than the yield increasing threshold of the encrypted well, and the recovery factor increment is greater than the preset recovery factor increment threshold, determining that the well pattern encryption feasibility result of the target gas reservoir is feasible.
10. An apparatus for determining feasibility of well pattern encryption, the apparatus providing an initial well pattern density and an encrypted well pattern density for a target gas reservoir, wherein the encrypted well pattern density represents a well pattern density after well pattern encryption of the target gas reservoir based on the initial well pattern density; the device comprises: the system comprises an accumulative gas production and recovery rate determining module, a gas production and recovery rate increment determining module and a well pattern encryption feasibility determining module; wherein,
the cumulative gas production and recovery rate determining module is used for determining the average cumulative gas production and recovery rate corresponding to the initial well pattern density and determining the average cumulative gas production and recovery rate corresponding to the encrypted well pattern density; wherein the average cumulative gas production represents an average of cumulative gas production of gas wells in the target gas reservoir;
the yield increasing and recovery factor increment determining module is used for calculating the encrypted well yield corresponding to the encrypted well pattern density according to the average accumulated gas production corresponding to the initial well pattern density and the average accumulated gas production corresponding to the encrypted well pattern density, and calculating the recovery factor increment corresponding to the encrypted well pattern density according to the recovery factor corresponding to the initial well pattern density and the recovery factor corresponding to the encrypted well pattern density;
and the well pattern encryption feasibility determining module is used for determining the well pattern encryption feasibility of the target gas reservoir based on the average accumulated gas production, the encrypted well gas production and the recovery factor increment corresponding to the encrypted well pattern density.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710974861.3A CN107939371B (en) | 2017-10-19 | 2017-10-19 | Method and device for determining encryption feasibility of well pattern |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201710974861.3A CN107939371B (en) | 2017-10-19 | 2017-10-19 | Method and device for determining encryption feasibility of well pattern |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN107939371A CN107939371A (en) | 2018-04-20 |
| CN107939371B true CN107939371B (en) | 2019-09-10 |
Family
ID=61936216
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201710974861.3A Active CN107939371B (en) | 2017-10-19 | 2017-10-19 | Method and device for determining encryption feasibility of well pattern |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107939371B (en) |
Families Citing this family (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109236265B (en) * | 2018-08-29 | 2020-12-01 | 中国石油天然气股份有限公司 | Method for optimizing tight gas reservoir well pattern |
| CN111119840B (en) * | 2018-11-01 | 2023-05-26 | 中国石油天然气股份有限公司 | Well position optimization method for high water-cut period oil reservoir |
Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102930345A (en) * | 2012-10-12 | 2013-02-13 | 中国石油大学(华东) | Self-adaptive well pattern optimization method based on gradient algorithm |
| CN103790565A (en) * | 2012-10-29 | 2014-05-14 | 中国石油化工股份有限公司 | Complicated fault block oil reservoir development well pattern optimizing design method |
| CN104453836A (en) * | 2014-11-17 | 2015-03-25 | 中国石油天然气股份有限公司长庆油田分公司勘探开发研究院 | Multiple-stratum-series tight sandstone gas reservoir well spacing method |
| CN105545265A (en) * | 2016-01-05 | 2016-05-04 | 郭建林 | Large-area tight gas reservoir exploitation method |
| CN106337679A (en) * | 2015-07-10 | 2017-01-18 | 中国石油化工股份有限公司 | Novel method for measuring and calculating well pattern thickening potential |
| CN106837289A (en) * | 2016-12-29 | 2017-06-13 | 中国石油天然气集团公司 | A kind of method and apparatus for determining well location |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US20020036089A1 (en) * | 2000-04-24 | 2002-03-28 | Vinegar Harold J. | In situ thermal processing of a hydrocarbon containing formation using distributed combustor heat sources |
-
2017
- 2017-10-19 CN CN201710974861.3A patent/CN107939371B/en active Active
Patent Citations (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN102930345A (en) * | 2012-10-12 | 2013-02-13 | 中国石油大学(华东) | Self-adaptive well pattern optimization method based on gradient algorithm |
| CN103790565A (en) * | 2012-10-29 | 2014-05-14 | 中国石油化工股份有限公司 | Complicated fault block oil reservoir development well pattern optimizing design method |
| CN104453836A (en) * | 2014-11-17 | 2015-03-25 | 中国石油天然气股份有限公司长庆油田分公司勘探开发研究院 | Multiple-stratum-series tight sandstone gas reservoir well spacing method |
| CN106337679A (en) * | 2015-07-10 | 2017-01-18 | 中国石油化工股份有限公司 | Novel method for measuring and calculating well pattern thickening potential |
| CN105545265A (en) * | 2016-01-05 | 2016-05-04 | 郭建林 | Large-area tight gas reservoir exploitation method |
| CN106837289A (en) * | 2016-12-29 | 2017-06-13 | 中国石油天然气集团公司 | A kind of method and apparatus for determining well location |
Non-Patent Citations (1)
| Title |
|---|
| 透镜状致密砂岩气藏井网加密技术与应用;万玉金等;《科技创新导报》;20141231(第28期);第41-44页 |
Also Published As
| Publication number | Publication date |
|---|---|
| CN107939371A (en) | 2018-04-20 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN108106964B (en) | Method and device for determining gas content of shale | |
| CN106324676B (en) | Method and device for determining fault closure | |
| Wu et al. | Hyperchaos in a conservative system with nonhyperbolic fixed points | |
| CN108019205A (en) | Method and device for determining fracturing index of reservoir | |
| CN111101929B (en) | A method, device and system for calculating average formation pressure of oil and gas reservoirs | |
| CN105095237A (en) | Method and device used for generating schema of not-only-structured-query-language database | |
| CN111507537A (en) | A method and device for predicting reserves and water influx of water-driven gas reservoirs | |
| CN107939371B (en) | Method and device for determining encryption feasibility of well pattern | |
| CN108008444B (en) | Method and device for determining rock physical model | |
| CN105335389A (en) | Business visualization method and system | |
| CN106845786A (en) | Method and device for evaluating reservoir connectivity between injection well and production well | |
| CN115686499A (en) | Method, device, storage medium and electronic equipment for generating request message | |
| CN107944126B (en) | Method and device for determining water content of water-drive reservoir | |
| CN107975358A (en) | Oil reservoir exploitation method and device | |
| US9576085B2 (en) | Selective importance sampling | |
| CN107704685A (en) | A kind of Meshing Method and device | |
| CN108505991B (en) | Method and device for determining extraction degree of oil in rock core | |
| CN107563617B (en) | Method and device for determining oil and gas amount on oil and gas migration path | |
| CN106529147B (en) | Method and device for determining oil gas reserves and water body scale | |
| CN107765318B (en) | A kind of method and device of determining geologic horizon | |
| CN108196300B (en) | A kind of seismic data processing technique and device | |
| CN108629463B (en) | Ground stress change prediction method and device | |
| CN109542401A (en) | A kind of Web development approach, device, storage medium and processor | |
| CN108107470B (en) | A kind of seismic data processing technique and device | |
| CN107180161A (en) | Stratum contrast result integration method and device |
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 |