CN108386185B - Method and device for determining sand body connectivity - Google Patents
Method and device for determining sand body connectivity Download PDFInfo
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- CN108386185B CN108386185B CN201810042852.5A CN201810042852A CN108386185B CN 108386185 B CN108386185 B CN 108386185B CN 201810042852 A CN201810042852 A CN 201810042852A CN 108386185 B CN108386185 B CN 108386185B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
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Abstract
The embodiment of the application discloses a method and a device for determining sand body connectivity. The method provides logging data and core sample analysis data at an injection and production well drilling location for a targeted interval; the method comprises the following steps: determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data; and determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type. The technical scheme provided by the embodiment of the application can effectively determine the sand body connectivity of the target interval in the sandstone oil reservoir with low permeability in the thin interbed.
Description
Technical Field
The application relates to the technical field of sand body connectivity evaluation in oil reservoir description, in particular to a method and a device for determining sand body connectivity.
Background
Reservoir sand connectivity generally refers to the manner and degree of contact and communication of cause unit sands with each other in the vertical and lateral directions, and is an important factor affecting the development of oil and gas fields. Chemical flooding is a main replacement technology for greatly improving the recovery ratio of a water injection sandstone reservoir, and for old oil fields with high extraction degree and high water cut, the exploitation degree of water flooding development is relatively high, the space for improving the recovery ratio is small, and exploration and test of chemical flooding are urgent.
The former chemical flooding reservoirs are thick-layer reservoirs with medium and high permeability, the reservoir sand body connectivity is good, and the corresponding perforation and chemical flooding development of an injection well can be realized only by screening target intervals with acoustic wave time difference larger than a specified threshold value and resistivity larger than the specified threshold value. However, for a sandstone reservoir with low permeability in a thin interbed, because the reservoir has strong heterogeneity and large difference of sand body connectivity, before chemical flooding development, it is necessary to determine the reservoir sand body connectivity of a target interval in the reservoir in order to guide the chemical flooding development.
For a sandstone oil reservoir with low and medium permeability in a thin interbed, no method for effectively determining the reservoir sand body connectivity of a target interval in the oil reservoir exists at present.
Disclosure of Invention
The embodiment of the application aims to provide a method and a device for determining the sand body connectivity, so as to effectively determine the sand body connectivity of a target interval in a sandstone oil reservoir with low permeability in a thin interbed.
In order to solve the above technical problem, embodiments of the present application provide a method and an apparatus for determining sand body connectivity, which are implemented as follows:
a method for determining the connectivity of sand body, provide the logging data and core sample analysis data at the injection and production well drilling position of the purposeful interval; the method comprises the following steps:
determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data;
and determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type.
In a preferred embodiment, the determining, according to the logging data and the core sample analysis data, the reservoir type of the target interval at the drilling position of the injection-production well includes:
determining formation attribute data of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data; wherein the formation property data is used to characterize formation property characteristics of the reservoir;
and determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the stratum attribute data.
In a preferred embodiment, the formation property data includes at least one of permeability, porosity, acoustic moveout, resistivity, pore structure characteristic data, and lithology characteristic data.
In a preferred embodiment, the determining, according to the logging data and the core sample analysis data, formation property data of the interval of interest at the drilling position of the injection-production well includes:
respectively acquiring acoustic time difference and resistivity in the formation attribute data from acoustic time difference logging curve data and resistivity logging curve data in the logging data; determining the porosity and permeability in the formation attribute data according to the acoustic time difference logging curve data, the neutron logging curve data and the density logging curve data in the logging data;
determining lithology characteristic data in the formation attribute data according to core cast body slice image data in the core sample analysis data; and determining pore structure characteristic data in the formation attribute data according to pore distribution data and mercury intrusion curve data in the core sample analysis data.
In a preferred embodiment, the determining the reservoir type of the interval of interest at the drilling position of the injection-production well according to the formation attribute data includes:
and determining a target first condition which is met by the stratum attribute data in a judging strategy for judging the reservoir type, and taking the reservoir type characterized by the target first condition as the reservoir type of the target interval at the injection-production well drilling position.
In a preferred embodiment, the decision strategy for deciding the reservoir type includes at least one of the following first conditions:
when the permeability in the formation attribute data is within a first preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a first preset resistivity range, the pore structure type represented by the pore structure characteristic data is a first preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a first preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a first type of reservoir;
when the permeability in the formation attribute data is within a second preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a second preset resistivity range, the pore structure type represented by the pore structure characteristic data is a second preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a second preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a second type reservoir;
and when the permeability in the formation attribute data is within a third preset permeability range, the porosity is within a second preset porosity range, the acoustic time difference is within a second preset acoustic time difference range, the resistivity is within a third preset resistivity range, the pore structure type represented by the pore structure characteristic data is a third preset pore structure type, and the lithology characteristic represented by the lithology characteristic data is a third preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a third type reservoir.
In a preferred embodiment, the determining the sand connectivity between the injection well and the production well in the injection and production well along the interval of interest based on the reservoir type includes:
and determining a target second condition met by the reservoir type in a judgment strategy for judging the sand body communication grade, and taking the sand body communication grade represented by the target second condition as the sand body communication grade between an injection well and a production well in the injection and production well along the target interval.
In a preferred embodiment, the determination strategy for determining the sand body communication level includes at least one of the following second conditions:
when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the first type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir, the sand body connectivity grade is a first connectivity grade;
when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the second type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body connectivity level is a second connectivity level;
when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body connectivity level is a third connectivity level;
and when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third reservoir type and the reservoir type at the drilling position of the other well in the injection and production wells is the third reservoir type, the sand body connectivity level is a fourth connectivity level.
An apparatus for determining sand connectivity that provides logging data and core sample analysis data at an injection and production well drilling location for a zone of interest; the device comprises: a reservoir type determination module and a connectivity determination module; wherein the content of the first and second substances,
the reservoir type determining module is used for determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data;
and the connectivity determining module is used for determining the sand connectivity between an injection well and a production well in the injection and production well along the target interval based on the reservoir type.
In a preferred embodiment, the reservoir type determining module is configured to determine, according to the logging data and the core sample analysis data, formation attribute data of the target interval at the injection-production well drilling position, where the formation attribute data is used to characterize formation attribute characteristics of a reservoir, and determine, according to the formation attribute data, a reservoir type of the target interval at the injection-production well drilling position.
According to the technical scheme provided by the embodiment of the application, the method and the device for determining the sand body connectivity can determine the reservoir type of the target interval at the drilling position of the injection and production well according to the logging data and the core sample analysis data; sand connectivity along the interval of interest between an injection well and a production well in the injection and production well may be determined based on the reservoir type. Therefore, the sand body connectivity of the target interval in the sandstone oil reservoir with low permeability in the thin interbed can be effectively determined.
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 sand connectivity according to the present application;
FIG. 2 is a schematic illustration of a well pattern plan configuration in an embodiment of the present application;
FIG. 3 is a block diagram illustrating the components of one embodiment of the apparatus for determining sand connectivity of the present application;
FIG. 4 is a block diagram illustrating the composition of another embodiment of the apparatus for determining sand connectivity of the present application.
Detailed Description
The embodiment of the application provides a method and a device for determining sand body connectivity.
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 embodiment of the application provides a method for determining sand body connectivity. The method of determining sand connectivity provides logging data and core sample analysis data at a drilling location of an injection and production well in a formation of interest.
In this embodiment, the interval of interest may be a sandstone reservoir to be chemically-flooding developed in a thin interbed low permeability reservoir.
In this embodiment, the logging data and the core sample analysis data at the drilling position of the injection well of the interval of interest may be obtained in a drilling measurement mode and a core laboratory analysis mode. Wherein the injection and production wells comprise injection wells and production wells.
FIG. 1 is a flow chart of an embodiment of a method of determining sand connectivity according to the present application. As shown in FIG. 1, the method for determining the sand body connectivity comprises the following steps.
Step S101: and determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data.
In this embodiment, determining the reservoir type of the interval of interest at the injection-production drilling position according to the logging data and the core sample analysis data may specifically include determining formation property data of the interval of interest at the injection-production drilling position according to the logging data and the core sample analysis data. Wherein the formation property data is used to characterize formation property characteristics of the reservoir. The reservoir type of the interval of interest at the injection and production well drilling location may be determined from the formation property data. And the well pattern corresponding to the injection well and the oil production well in the injection and production well can be a five-point injection and production well pattern. For example, the corresponding well pattern of the injection well and the production well in the injection and production well can be a five-point injection and production well pattern as shown in fig. 2.
In this embodiment, the formation property data may specifically include at least one of permeability, porosity, acoustic moveout, resistivity, pore structure characteristic data, and lithology characteristic data.
In this embodiment, determining the formation property data of the target interval at the injection-production well drilling position according to the logging data and the core sample analysis data may specifically include obtaining the acoustic time difference and the resistivity in the formation property data from the acoustic time difference logging curve data and the resistivity logging curve data in the logging data, respectively. The porosity and permeability in the formation property data may be determined from sonic moveout log data, neutron log data, and density log data in the log data. For example, the porosity in the formation attribute data can be calculated according to the acoustic time difference logging curve data, the neutron logging curve data and the density logging curve data in the logging data by utilizing the correlation between the conventional porosity and the acoustic time difference, the neutron value and the density, and the permeability in the formation attribute data can be determined according to the porosity in the formation attribute data and the correlation between the porosity and the permeability determined by a core analysis method. Lithology characteristic data in the formation attribute data can be determined according to core cast body slice image data in the core sample analysis data. For example, the lithology of the reservoir characterized by the lithology characteristic data can be determined by analyzing and comparing the slice image data of the core cast body, wherein the lithology characteristic data is mainly medium-fine sandstone, fine sandstone or siltstone, and the lithology characteristic of particle support, point contact, point-line contact or line-point contact, contact cementation or pore cementation. Pore structure characteristic data in the formation attribute data can be determined according to pore distribution data and mercury intrusion curve data in the core sample analysis data. For example, the pore structure characteristics of the large pore-extra fine throat uniform type, the large pore-extra fine throat nonuniform type or the medium pore-extra fine throat nonuniform type characterized by the pore structure characteristic data can be determined according to the pore structure type characterized by the pore distribution data and the characteristics of the capillary pressure change rate along with the mercury saturation degree characterized by the mercury intrusion curve.
In this embodiment, determining the reservoir type of the target interval at the injection-production well drilling position according to the formation attribute data may specifically include determining a target first condition that the formation attribute data meets in a determination strategy for determining the reservoir type, and using the reservoir type characterized by the target first condition as the reservoir type of the target interval at the injection-production well drilling position. Wherein the decision strategy for deciding the reservoir type comprises at least one first condition.
In this embodiment, the determination strategy for determining the reservoir type may specifically include at least one of the following first conditions:
(1) when the permeability in the formation attribute data is within a first preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a first preset resistivity range, the pore structure type represented by the pore structure characteristic data is a first preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a first preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a first type reservoir; wherein the first predetermined permeability range may be greater than or equal to 100 millidarcies; the first predetermined porosity may be in a range of 20 to 25 percent (%); the first preset acoustic moveout range may be greater than or equal to 260 microseconds/meter; the first predetermined resistivity range may be greater than or equal to 20 ohm-meters; the first preset pore structure type is a large pore-extra-fine throat uniform type, and the change rate of capillary pressure is firstly reduced and then increased along with the increase of mercury saturation; the first preset core characteristics can be reservoir lithology which mainly comprises medium-fine sandstone and fine sandstone, and particle support, point contact and contact cementation;
(2) when the permeability in the formation attribute data is within a second preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a second preset resistivity range, the pore structure type represented by the pore structure characteristic data is a second preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a second preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a second type reservoir; wherein the second predetermined permeability range may be greater than or equal to 50 millidarcies and less than 100 millidarcies; the second predetermined resistivity range may be greater than or equal to 17 ohm-meters; the second preset pore structure type is a large pore-extra-fine throat uneven type, and the change rate of capillary pressure is increased, decreased and then increased along with the increase of mercury saturation; the second preset core characteristics can be reservoir lithology which is mainly fine sandstone and is subjected to particle support, point-line contact and contact cementation;
(3) and when the permeability in the formation attribute data is within a third preset permeability range, the porosity is within a second preset porosity range, the acoustic time difference is within a second preset acoustic time difference range, the resistivity is within a third preset resistivity range, the pore structure type represented by the pore structure characteristic data is a third preset pore structure type, and the lithology characteristic represented by the lithology characteristic data is a third preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a third type reservoir. Wherein the third predetermined permeability range may be less than 50 millidarcies; the second predetermined porosity range may be less than 20%; the second predetermined acoustic moveout may be in a range of less than 260 microseconds/meter; the third predetermined resistivity range may be less than 17 ohm-meters; the third preset pore structure type is a mesopore-superfine throat nonuniform type, and the change rate of capillary pressure is increased along with the increase of mercury saturation; the third predetermined core characteristics may be reservoir lithology dominated by siltstone, and grain support, line-point contact, and pore type cementation.
Step S102: and determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type.
In this embodiment, determining sand connectivity between the injection well and the production well along the interval of interest in the injection and production well based on the reservoir type may specifically include determining a target second condition that the reservoir type meets in a determination strategy for determining a sand connectivity level, and using the sand connectivity level characterized by the target second condition as the sand connectivity level along the interval of interest between the injection well and the production well in the injection and production well. Wherein the judgment strategy for judging the sand body communication level comprises at least one second condition.
In this embodiment, the determination strategy for determining the sand body communication level may include at least one of the following second conditions:
(1) when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the first type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir, the sand body connectivity grade is a first connectivity grade;
(2) when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the second type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body connectivity level is a second connectivity level;
(3) when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body connectivity level is a third connectivity level;
(4) and when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third reservoir type and the reservoir type at the drilling position of the other well in the injection and production wells is the third reservoir type, the sand body connectivity level is a fourth connectivity level. The first communication grade is higher than the second communication grade, the second communication grade is higher than the third communication grade, the third communication grade is higher than the fourth communication grade, and the higher the communication grade is, the better the sand body connectivity is.
In one embodiment of the present application, the method for determining sand body connectivity may further provide seismic data of the interval of interest, and the method for determining sand body connectivity may further include: the method comprises the steps of obtaining a homophase axis of the target interval by carrying out horizon tracking and interpretation on seismic data of the target interval, indicating that a reservoir along the target interval between an injection well and a production well in the injection and production well is not communicated when the homophase axis of the target interval between the injection well and the production well in the injection and production well is interrupted, and determining that the sand body communication level along the target interval between the injection well and the production well in the injection and production well is a fourth communication level.
According to the embodiment of the method for determining the sand body connectivity, the reservoir type of the target interval at the well drilling position of the injection and production well can be determined according to the logging data and the core sample analysis data; sand connectivity along the interval of interest between an injection well and a production well in the injection and production well may be determined based on the reservoir type. Therefore, the sand body connectivity of the target interval in the sandstone oil reservoir with low permeability in the thin interbed can be effectively determined.
FIG. 3 is a block diagram illustrating the components of one embodiment of the apparatus for determining sand connectivity according to the present application. The device for determining the sand body connectivity provides logging data and core sample analysis data at the injection and production well drilling position of the target interval. As shown in fig. 3, the device for determining sand body connectivity may include: a reservoir type determination module 100 and a connectivity determination module 200.
The reservoir type determination module 100 may be configured to determine a reservoir type of the interval of interest at the injection well drilling location according to the logging data and the core sample analysis data.
The connectivity determination module 200 may be configured to determine sand connectivity along the interval of interest between an injection well and a production well in the injection and production well based on the reservoir type.
In this embodiment, the reservoir type determining module 100 may be configured to determine, according to the logging data and the core sample analysis data, formation property data of the target interval at the injection well drilling position, where the formation property data is used to characterize formation property characteristics of a reservoir, and determine, according to the formation property data, a reservoir type of the target interval at the injection well drilling position.
FIG. 4 is a block diagram illustrating the composition of another embodiment of the apparatus for determining sand connectivity of the present application. As shown in fig. 4, the apparatus for determining sand connectivity comprises a memory, a processor, and a computer program stored on the memory. The memory stores logging data and core sample analysis data at the injection and production well drilling position of the target interval; the computer program when executed by the processor performs the steps of:
step S101: determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data;
step S102: and determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type.
The device embodiment for determining the sand body connectivity corresponds to the method embodiment for determining the sand body connectivity, so that the technical scheme of the method embodiment for determining the sand body connectivity can be realized, and the technical effect of the method embodiment 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, hardbylangue (Hardware Description Language), vhjhdul (Hardware Description Language), and vhigh-Language, which are currently used in most common. 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, which 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 embodiments, those skilled 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 modifications without departing from the spirit of the application.
Claims (4)
1. A method for determining sand body connectivity is characterized by providing logging data and core sample analysis data at a well drilling position of an injection and production well of a target interval; the method comprises the following steps:
determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data;
determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type;
determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data, wherein the determining comprises the following steps: determining formation attribute data of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data; wherein the formation property data is used to characterize formation property characteristics of the reservoir; determining the reservoir type of the target interval at the well drilling position of the injection-production well according to the stratum attribute data;
determining the reservoir type of the target interval at the well drilling position of the injection-production well according to the stratum attribute data, wherein the reservoir type comprises the following steps: determining a target first condition met by the stratum attribute data in a judgment strategy for judging the reservoir type, and taking the reservoir type characterized by the target first condition as the reservoir type of the target interval at the injection-production well drilling position; the decision strategy for deciding the reservoir type includes at least one of the following first conditions: when the permeability in the formation attribute data is within a first preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a first preset resistivity range, the pore structure type represented by the pore structure characteristic data is a first preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a first preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a first type reservoir; when the permeability in the formation attribute data is within a second preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a second preset resistivity range, the pore structure type represented by the pore structure characteristic data is a second preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a second preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a second type reservoir; when the permeability in the formation attribute data is within a third preset permeability range, the porosity is within a second preset porosity range, the acoustic time difference is within a second preset acoustic time difference range, the resistivity is within a third preset resistivity range, the pore structure type represented by the pore structure characteristic data is a third preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a third preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a third type reservoir; wherein the first predetermined permeability range is greater than or equal to 100 millidarcies; the first preset porosity range is 20-25 percent; the first preset sound wave time difference range is greater than or equal to 260 microseconds/meter; the first preset resistivity range is greater than or equal to 20 ohm-meters; the second predetermined permeability range is greater than or equal to 50 millidarcies and less than 100 millidarcies; the second preset resistivity range is greater than or equal to 17 ohm-meters; the third predetermined permeability range is less than 50 millidarcies; the second predetermined porosity range is less than 20%; the second preset sound wave time difference range is less than 260 microseconds/meter; the third preset resistivity range is less than 17 ohm-meters; the first preset core is characterized in that reservoir lithology mainly comprises medium-fine sandstone and fine sandstone, and particle support, point contact and contact cementation are adopted; the second preset core is characterized in that the reservoir lithology is mainly fine sandstone, and particle support, point-line contact and contact cementation are performed; the third preset pore structure type is a mesopore-superfine throat nonuniform type, the change rate of capillary pressure is increased along with the increase of mercury saturation, and the third preset core is characterized in that reservoir lithology is mainly siltstone, and particle support, line-point contact and pore type cementation are adopted;
determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type, comprising: determining a target second condition which is met by the reservoir type in a judgment strategy for judging the sand body communication grade, and taking the sand body communication grade represented by the target second condition as the sand body communication grade between an injection well and a production well in the injection and production well along the target interval; the judgment strategy for judging the sand body communication level comprises at least one second condition as follows: when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the first type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir, the sand body communication grade is a first communication grade; when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the second type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body communication level is a second communication level; when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body communication level is a third communication level; when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the third type of reservoir, the sand body communication level is a fourth communication level; the first communication grade is higher than the second communication grade, the second communication grade is higher than the third communication grade, the third communication grade is higher than the fourth communication grade, and the higher the communication grade is, the better the sand body connectivity is.
2. The method of claim 1, wherein the formation property data comprises at least one of permeability, porosity, acoustic moveout, resistivity, pore structure characteristic data, and lithology characteristic data.
3. The method of claim 2, wherein determining formation property data for the interval of interest at the injection well drilling location based on the logging data and the core sample analysis data comprises:
respectively acquiring acoustic time difference and resistivity in the formation attribute data from acoustic time difference logging curve data and resistivity logging curve data in the logging data; determining the porosity and permeability in the formation attribute data according to the acoustic time difference logging curve data, the neutron logging curve data and the density logging curve data in the logging data;
determining lithology characteristic data in the formation attribute data according to core cast body slice image data in the core sample analysis data; and determining pore structure characteristic data in the formation attribute data according to pore distribution data and mercury intrusion curve data in the core sample analysis data.
4. An apparatus for determining sand connectivity, the apparatus providing logging data and core sample analysis data at a drilling location of an injection and production well for a zone of interest; the device comprises: a reservoir type determination module and a connectivity determination module; wherein the content of the first and second substances,
the reservoir type determining module is used for determining the reservoir type of the target interval at the well drilling position of the injection and production well according to the logging data and the core sample analysis data;
the connectivity determining module is used for determining sand connectivity between an injection well and a production well in the injection and production well along the target interval based on the reservoir type;
the reservoir type determining module is used for determining formation attribute data of the target interval at the injection and production well drilling position according to the logging data and the core sample analysis data, wherein the formation attribute data are used for representing formation attribute characteristics of a reservoir, and determining the reservoir type of the target interval at the injection and production well drilling position according to the formation attribute data;
determining the reservoir type of the target interval at the injection-production well drilling position according to the stratum attribute data, wherein the reservoir type comprises the following steps: determining a target first condition met by the stratum attribute data in a judgment strategy for judging the reservoir type, and taking the reservoir type characterized by the target first condition as the reservoir type of the target interval at the injection-production well drilling position; the decision strategy for deciding the reservoir type includes at least one of the following first conditions: when the permeability in the formation attribute data is within a first preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a first preset resistivity range, the pore structure type represented by the pore structure characteristic data is a first preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a first preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a first type of reservoir; when the permeability in the formation attribute data is within a second preset permeability range, the porosity is within a first preset porosity range, the acoustic time difference is within a first preset acoustic time difference range, the resistivity is within a second preset resistivity range, the pore structure type represented by the pore structure characteristic data is a second preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a second preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a second type reservoir; when the permeability in the formation attribute data is within a third preset permeability range, the porosity is within a second preset porosity range, the acoustic time difference is within a second preset acoustic time difference range, the resistivity is within a third preset resistivity range, the pore structure type represented by the pore structure characteristic data is a third preset pore structure type, and the lithological characteristic represented by the lithological characteristic data is a third preset core characteristic, the reservoir type of the target interval at the injection and production well drilling position is a third type reservoir; wherein the first predetermined permeability range is greater than or equal to 100 millidarcies; the first preset porosity range is 20-25 percent; the first preset sound wave time difference range is greater than or equal to 260 microseconds/meter; the first preset resistivity range is greater than or equal to 20 ohm-meters; the second predetermined permeability range is greater than or equal to 50 millidarcies and less than 100 millidarcies; the second preset resistivity range is greater than or equal to 17 ohm-meters; the third predetermined permeability range is less than 50 millidarcies; the second predetermined porosity range is less than 20%; the second preset sound wave time difference range is less than 260 microseconds/meter; the third preset resistivity range is less than 17 ohm-meters; the first preset core is characterized in that reservoir lithology mainly comprises medium-fine sandstone and fine sandstone, and particle support, point contact and contact cementation are adopted; the second preset core is characterized in that the reservoir lithology is mainly fine sandstone, and particle support, point-line contact and contact cementation are performed; the third preset pore structure type is a mesopore-superfine throat nonuniform type, the change rate of capillary pressure is increased along with the increase of mercury saturation, and the third preset core is characterized in that reservoir lithology is mainly siltstone, and particle support, line-point contact and pore type cementation are adopted;
determining sand connectivity between an injection well and a production well in the injection and production well along the interval of interest based on the reservoir type, comprising: determining a target second condition which is met by the reservoir type in a judgment strategy for judging the sand body communication grade, and taking the sand body communication grade represented by the target second condition as the sand body communication grade between an injection well and a production well in the injection and production well along the target interval; the judgment strategy for judging the sand body communication level comprises at least one second condition as follows: when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the first type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir, the sand body communication grade is a first communication grade; when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the second type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body communication grade is a second communication grade; when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the first type of reservoir or the second type of reservoir, the sand body communication level is a third communication level; when the reservoir type of the target interval at the drilling position of one well in the injection and production wells is the third type of reservoir and the reservoir type at the drilling position of the other well in the injection and production wells is the third type of reservoir, the sand body communication level is a fourth communication level; the first communication grade is higher than the second communication grade, the second communication grade is higher than the third communication grade, the third communication grade is higher than the fourth communication grade, and the higher the communication grade is, the better the sand body connectivity is.
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