CN112782780A - Reservoir evaluation method, device and equipment based on rock physical facies - Google Patents
Reservoir evaluation method, device and equipment based on rock physical facies Download PDFInfo
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Abstract
The embodiment of the specification provides a reservoir evaluation method, device and equipment based on a petrophysical facies. Wherein the method comprises the following steps: determining lithologic lithofacies types, lithofacies formation types and pore structure facies types of the reservoir based on the reservoir exploration data; determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir; calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters; and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard. By the method, the physical facies of the rock is determined under the condition of comprehensively considering lithologic facies, lithogenic facies and pore structures, and quantitative evaluation is carried out on the reservoir stratum by utilizing the physical facies of the rock, so that the quality of the reservoir stratum is conveniently and accurately determined.
Description
Technical Field
The embodiment of the specification relates to the technical field of geological exploration and development, in particular to a reservoir evaluation method, device and equipment based on a rock physical facies.
Background
In the field of geological exploration, after a reservoir possibly containing oil and gas resources is determined, evaluation is carried out on various attribute characteristics of the reservoir before development and exploration are carried out on the reservoir, and an actually developed geological model is determined according to an evaluation result, so that a development scheme can be optimized, and the development success rate and the economic benefit are improved.
At present, the method for evaluating based on the petrophysical facies is widely applied to the characterization and evaluation of reservoirs. However, tight reservoirs are affected by multiple factors of sedimentary microphase, diagenesis and tectonic transformation, resulting in poor physical properties and complex pore structures. In practical application, because the influencing factors aiming at the quality of the compact reservoirs are complex, when the traditional reservoir evaluation method based on the rock physical phase is utilized, the sedimentary characteristics, diagenetic factors and pore structure types influencing the reservoir quality are not considered, so that the description of the reservoirs is not complete. Meanwhile, the multi-solution of the logging data can cause errors in the classification and logging identification of the rock physical facies, and the final evaluation result can be influenced.
In conclusion, the traditional evaluation method based on the petrophysical facies cannot meet the current requirements in accuracy and practical application when the reservoir is evaluated. Therefore, there is a need for an evaluation method that can overcome the above technical problems and can quantitatively perform well logging evaluation based on rock physical phases.
Disclosure of Invention
An object of the embodiments of the present specification is to provide a reservoir evaluation method, device and apparatus based on petrophysical facies, so as to solve the problem in the prior art that the accuracy is not sufficient when evaluating a reservoir.
In order to solve the technical problem, a method, a device and equipment for evaluating a reservoir based on a petrophysical facies, which are provided by the embodiments of the present specification, are implemented as follows:
a method for reservoir evaluation based on petrophysical facies, comprising:
determining lithologic lithofacies types, lithofacies formation types and pore structure facies types of the reservoir based on the reservoir exploration data;
determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir;
calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters;
and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
A petrophysical facies-based reservoir evaluation apparatus comprising:
the reservoir type determining module is used for determining the lithologic facies type, lithomorphic facies type and pore structure facies type of the reservoir based on the reservoir exploration data;
the reservoir parameter determination module is used for determining lithologic facies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by utilizing a preset parameter determination rule based on the lithologic facies type, lithofacies formation type and pore structure facies type of the reservoir;
the rock physical phase parameter calculation module is used for calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters;
and the reservoir evaluation module is used for evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
A petrophysical facies-based reservoir evaluation apparatus comprising a memory and a processor;
the memory to store computer instructions;
the processor to execute the computer instructions to implement the steps of: determining lithologic lithofacies types, lithofacies formation types and pore structure facies types of the reservoir based on the reservoir exploration data; determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir; calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters; and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
According to the technical scheme provided by the embodiment of the specification, the embodiment of the specification sequentially determines the lithologic facies type, the diagenesis type and the pore structure facies type of the reservoir according to the exploration data, further determines parameters corresponding to each type, calculates the rock physical facies parameters by using the determined parameters, and then quantitatively evaluates the quality of the reservoir according to the rock physical facies parameters. According to the method provided by the embodiment of the specification, the sedimentary characteristics, diagenetic factors and pore structure types of the reservoir are comprehensively considered when the rock physics relative reservoir quality is evaluated, so that the reservoir description is more complete. The rock physical phase parameters are obtained through calculation when the reservoir quality is evaluated, and the objectivity for the reservoir quality evaluation is improved by using the quantitative evaluation mode of the parameters, so that the technical effect of conveniently and accurately evaluating the reservoir quality is realized.
Drawings
In order to more clearly illustrate the embodiments of the present specification or the technical solutions in the prior art, the drawings used in the description of the embodiments or the prior art will be briefly described below, it is obvious that the drawings in the following description are only some embodiments described in the specification, and other drawings can be obtained by those skilled in the art without creative efforts.
FIG. 1 is a flow chart of a method for reservoir evaluation based on petrophysical facies in an embodiment of the present disclosure;
FIG. 2 is a schematic diagram illustrating an embodiment of the present disclosure for determining lithofacies types of a reservoir;
FIG. 3 is a schematic diagram illustrating analysis of data for a reservoir diagenesis in accordance with an embodiment of the present disclosure;
FIG. 4 is a schematic diagram illustrating a method for determining lithogenic facies types of a reservoir in accordance with an embodiment of the present disclosure;
FIG. 5 is a schematic diagram illustrating one embodiment of the present disclosure for determining a pore structure phase type of a reservoir;
FIG. 6A is a schematic diagram illustrating evaluation of petrophysical facies of an A reservoir in accordance with an embodiment of the present disclosure;
FIG. 6B is a schematic diagram illustrating evaluation of petrophysical facies for a B reservoir in accordance with an embodiment of the present disclosure;
FIG. 7 is a block diagram of a reservoir evaluation apparatus based on petrophysical facies in an embodiment of the present disclosure;
fig. 8 is a block diagram of a reservoir evaluation apparatus based on petrophysical facies in an embodiment of the present disclosure.
Detailed Description
The technical solutions in the embodiments of the present disclosure will be clearly and completely described below with reference to the drawings in the embodiments of the present disclosure, and it is obvious that the described embodiments are only a part of the embodiments of the present disclosure, and not all of the embodiments. All other embodiments obtained by a person of ordinary skill in the art based on the embodiments in the present specification without any creative effort shall fall within the protection scope of the present specification.
An embodiment of a reservoir evaluation method based on petrophysical facies according to the present disclosure is described below with reference to fig. 1. The execution main body of the method is computer equipment, and the computer equipment comprises a server, an industrial personal computer, an all-in-one machine, a PC (personal computer) and the like. The concrete implementation steps of the reservoir evaluation method based on the petrophysical facies are as follows:
s110: based on the reservoir exploration data, lithologic facies types, lithogenic facies types, and pore structure facies types of the reservoir are determined.
Before development of a reservoir, a plurality of different types of well logging and exploratory wells are arranged in the reservoir in advance and used for acquiring data such as acoustic waves, electromagnetic waves and geological structures of the reservoir. And acquiring data obtained by exploration by using well logging, well exploration and other geological exploration methods as reservoir exploration data. By utilizing the reservoir exploration data, the characteristics of the reservoir such as sedimentary characteristics, diagenetic factors, pore structure types and the like can be evaluated, and then the related information of the rock physical phases of the reservoir is obtained, so that the evaluation of the reservoir quality is realized.
Lithology can be used for reflecting the characteristics of rock such as color, components, structure, cement type and the like, and lithofacies can be used for reflecting lithology characteristics and biological characteristics of a deposition environment in which a sediment is located. In embodiments of the present description, a lithofacies type of a reservoir may be determined based on picks of depositional constructs of the reservoir.
In one embodiment, the lithologic lithofacies types may be classified as oil shale facies, semi-deep lake shale facies, slumped fine sandstone facies, turbid silty fine sandstone facies, sandy clastic flow fine sandstone facies.
The different lithofacies types described above have different properties in sedimentary formations, e.g., the oil shale phase has shale features; the half-deep lake shale facies has horizontal bedding and blocky structures; the collapsed fine sandstone phase has deformed bedding and liquefied sandstone veins; the turbid powder fine sandstone phase has bauma sequence and positive particle sequence bedding; the fine sandstone phase of the stream of sandy debris has a blocky structure, parallel bedding, and mudstone torn debris.
The different lithofacies types have different characteristics, so that the different lithofacies types have differences in detectable physical properties such as sound waves, electromagnetism, natural gamma, imaging and the like, and therefore the lithofacies types of the reservoir can be determined through resistivity logging curve data, natural gamma logging curve data and imaging logging data in the reservoir exploration data.
The above process is explained using a specific example. For example, the lithologic facies types of the above-identified oil shale facies, semi-deep lake shale facies, slumped fine sandstone facies, turbid silty fine sandstone facies, and fine sandstone flow sandstone facies are different from the characteristics embodied in the conventional log data, the natural gamma-ray log data, and the imaging log data. The oil shale phase is high in gamma, resistivity and acoustic time difference, and dark spot-shaped pyrite is formed on an imaging log; the half-deep lake shale facies are represented by medium-high gamma, low resistivity and medium-acoustic wave time difference, and the imaging logging is in a dark stripe shape; the slumped fine sandstone phase is represented by medium gamma, medium and high resistivity and medium and low acoustic wave time difference, and the slumped deformation structure of the bright block body can be seen in the imaging logging data; the turbid powder fine sandstone phase is expressed as medium gamma, medium and high resistivity and medium and low acoustic wave time difference, and the imaging logging data is expressed as dark siltstone and light fine sandstone interbedding; the fine sandstone phase of the sandy debris flow is represented by low gamma, high resistance and low acoustic time difference, and the imaging logging is represented by a homogeneous bright block. Based on the differences of the different lithofacies types on gamma, resistance, acoustic time difference and imaging logging, the lithofacies types of the reservoir can be determined according to conventional logging curve data, natural gamma logging curve data and imaging logging data in reservoir exploration data corresponding to the reservoir, so that subsequent analysis aiming at the quality of the reservoir is facilitated.
The above example is described in connection with a specific application scenario. As shown in fig. 2, based on the natural gamma GR value, the resistivity value RT, and the imaging data displayed by the imaging log, different lithology combinations in the reservoir may be determined, thereby determining lithofacies types for different regions.
The diagenetic phase is the result of the comprehensive action of the conditions such as structure, fluid, temperature and pressure on the sediment and mainly reflects the mineral composition and the texture appearance. The diagenesis of the reservoir is complex, the diagenesis mineral types are rich, and the diagenesis mineral types can be composed of substances such as carbonate, siliceous substances, clay minerals and the like, so the diagenesis phase is related to the diagenesis action strength and the diagenesis mineral types and contents. Based on the characteristics, different diagenetic facies can be distinguished through diagenetic action strength and diagenetic mineral combination characteristics.
In one embodiment, the lithogenic phase types may be classified as an unstable component erosion phase, a clay mineral filling phase, a carbonate cementation phase, a compacted compaction phase.
The different lithofacies types have certain differences in diagenesis intensity and diagenesis mineral combination characteristics, so that the lithofacies types of the reservoir can be determined according to conventional well logging data of a core slice scale, acoustic jet-lag well logging data, natural gamma well logging data and compensation density well logging data in the reservoir exploration data.
The distinction between different lithofacies types is illustrated using a specific example. For example, there is a certain difference between the core slice scale conventional logging data, acoustic moveout logging data, natural gamma logging data and compensated density logging data corresponding to the above-mentioned divided unstable component corrosion phase, clay mineral filling phase, carbonate cementing phase and compacted dense phase. As shown in fig. 3, the different lithogenic phase types have differences in acoustic moveout AC, natural gamma GR, compensated neutron CNL, compensated density DEN, etc., and the lithogenic phase type of the reservoir can be determined based on the measured data. The unstable component corrosion phase is expressed by a medium-low natural gamma value, a medium acoustic wave time difference and a medium compensation density; the clay mineral filling phase is represented by a medium-high natural gamma value, a medium acoustic wave time difference and a medium compensation density; the carbonate cementing phase has a medium natural gamma value, a low sound wave time difference and a medium and high compensation density; the compact dense phase is expressed by a high natural gamma value, a medium-high sound wave time difference and a medium-high compensation density. Based on the difference of the different lithofacies types in the data such as natural gamma and acoustic moveout, the lithofacies types of the reservoir can be determined based on natural gamma logging data, acoustic moveout logging data and compensation density logging data in reservoir exploration data corresponding to the reservoir, and subsequent analysis aiming at the reservoir quality is facilitated.
As shown in fig. 4, the acoustic time difference AC, the natural gamma-ray GR, the compensated neutron CNL, the compensated density DEN and the high resolution array induction resistivity M are shown for different lithogenic phases2R2Spider-web plot of the values distributed above. And based on the criteria divided by the spider-web graph, determining lithogenic facies types corresponding to different regions of the reservoir.
The pore structure represents the conditions of the type, size, distribution, communication and the like of pores and throats in the reservoir. The pore is an enlarged portion in the reservoir and the throat is a fine portion connecting the pores. The pore structure can reflect the reserve size and distribution condition of oil and gas resources in the reservoir. In embodiments of the present description, drainage pressure data and nuclear magnetic resonance T in the reservoir exploration data may be based2Geometric mean data, determining pore structure phase type of the reservoir
In one embodiment, the pore structure phase types include a coarse throat macropore type, a medium throat mesopore type, and a fine throat micropore type.
The above process is explained using a specific example. For example, the displacement pressure of the coarse-throat macroporous pore structure is less than 1.0MPa, and the nuclear magnetic resonance T2The geometric mean value is more than 15 ms; the medium-throat large-pore structure is used for displacement and pressureA force of less than 1.0-4.0MPa, nuclear magnetic resonance T2The geometric mean value is more than 10-15 ms; the displacement pressure of the medium-throat medium-pore-pattern pore structure is less than 4.0MPa, and the nuclear magnetic resonance T2The geometric mean value is more than 10 ms; the displacement pressure of the fine-throat small-hole type pore structure is less than 9.0MPa, and the nuclear magnetic resonance T is2The geometric mean is greater than 5 ms. Based on the above different pore structure phase types, the displacement pressure and the nuclear magnetic resonance T2The difference of the geometric mean value can be obtained according to the displacement pressure data, the maximum pore throat radius and the T obtained by the nuclear magnetic resonance experiment in the reservoir exploration data corresponding to the reservoir2And determining the pore structure phase type of the reservoir by the geometric mean value data, so as to facilitate the subsequent analysis of the reservoir quality.
The above example is described in connection with an application scenario. As shown in FIG. 5, resistivity data, three-dimensional lacunarity data, reservoir toughness data, and T are detected at different depths for a reservoir2And determining the pore structure phases corresponding to different regions according to the method based on the geometric mean value data, wherein the type I pore structure, the type II pore structure, the type III pore structure and the type IV pore structure respectively correspond to a coarse-throat large pore type, a medium-throat medium pore type and a fine-throat small pore type. As can be seen from the examples of determining pore structure phases shown in the drawings, the method can accurately determine the pore structure phase types corresponding to different regions of the reservoir according to the corresponding data.
S120: and determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by utilizing a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir.
The lithologic facies characterization parameters, the lithogenic facies characterization parameters and the pore structure facies characterization parameters are used for representing influence coefficients of the reservoir in lithologic facies types, lithogenic facies types and pore structure facies types on reservoir quality. The parameters of the reservoir corresponding to various types are determined, and the rock physical phase parameters of the reservoir can be better evaluated in the subsequent process.
The preset parameter determination rule sets parameter values corresponding to different lithologic facies types, lithomorphic facies types and pore structure facies types respectively. In a specific example, lithologic facies characterization parameters of the oil shale facies, the half-deep lake shale facies, the slumped fine sandstone facies, the turbid silty fine sandstone facies and the fine sandstone facies of the sandy debris flow can be set to be 2.2, 1.6, 1.5, 1.0 and 1.0 respectively; setting lithogenic phase characterization parameters respectively corresponding to the unstable component erosion phase, the clay mineral filling phase, the carbonate cementing phase and the compaction compact phase to be 3.5, 2.0, 1.5 and 1.0; and setting the pore structure phase characterization parameters respectively corresponding to the coarse throat macropore type, the middle throat mesopore type and the fine throat micropore type to be 4.0, 3.0, 2.0 and 1.0. Based on the parameter determination rule, for example, if the reservoir is evaluated to obtain a turbid silty fine sandstone phase, a clay mineral filling phase and a coarse-throat large pore type, the corresponding lithologic facies characterization parameters, lithogenic facies characterization parameters and pore structure facies characterization parameters are 1.6, 3.0 and 2.0 respectively, so that different lithologic facies types, lithogenic facies types and pore structure facies types are quantitatively represented in the process of evaluating the reservoir quality, and the evaluation on the rock physical facies is facilitated. The parameter determination rule set in the above example is only to better illustrate the parameter determination process, and the parameter determination rule in practical application may be adjusted according to specific situations, which is not limited to this.
S130: and calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters.
The petrophysical phase parameters are used to evaluate the petrophysical phase of the reservoir. And under the condition that the lithologic facies characterization parameters, the lithogenic facies characterization parameters and the pore structure facies characterization parameters are obtained, calculating to obtain the rock physical facies parameters by combining the parameters.
The petrophysical facies parameter may be obtained by adding the lithologic facies characterization parameter, the lithogenic facies characterization parameter, and the pore structure facies characterization parameter, for example, when the lithologic facies type, the lithogenic facies type, and the pore structure type of the reservoir are respectively a turbid silty fine sandstone phase, a clay mineral filling phase, and a coarse-throat large pore type, the corresponding characterization parameters are respectively 1.6, 3.0, and 2.0, and then the petrophysical facies parameter may be the sum of all the parameters, that is, the calculated petrophysical facies parameter is 6.6.
In one embodiment, different weights may be assigned to the lithologic facies characterization parameter, the lithogenic facies characterization parameter, and the pore structure type weight value, and the petrophysical facies parameter may be calculated using the lithologic facies characterization parameter, the lithogenic facies characterization parameter, and the pore structure facies characterization parameter based on the core lithologic facies type weight value, the lithogenic facies type weight value, and the pore structure type weight value.
By using a specific example, the core lithofacies type weight value, the lithogenic facies type weight value, and the pore structure type weight value are set to be 0.2, 0.5, and 0.3, respectively, and when the reservoir is evaluated, the lithological lithofacies type, the lithogenic facies type, and the pore structure type are half-deep lake sediment lithofacies, compacted dense facies, and fine-throat pore facies, respectively, and in combination with the above weight values, the calculated petrophysical facies parameter is 1.0 × 0.2+1.0 × 0.3+1.0 × 0.5 — 1.0.
Corresponding weight values are respectively set for the core lithofacies type, the lithofacies type and the pore structure type, so that the difference of the influence degrees of different factors on the rock physical facies is reflected, and the evaluation of the quality of the reservoir is facilitated under the condition based on the rock physical facies.
S140: and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
The reservoir evaluation criteria are criteria for evaluating the reservoir based on petrophysical phase parameters. According to the reservoir evaluation standard, specific rock physical facies types corresponding to the reservoir can be determined according to different parameters, and then evaluation is carried out according to the characteristics of different rock physical facies types.
In one embodiment, the reservoir evaluation criteria include at least one of: according to the size of the rock physical phase parameters, respectively evaluating the rock physical phases into a first rock physical phase, a second rock physical phase, a third rock physical phase and a fourth rock physical phase; the first type of rock physically corresponds to a water layer; the second type of petrophysical corresponds to an oil reservoir; the third class of rock corresponds physically to a dry layer; the fourth type of rock corresponds physically to a non-reservoir. After the rock physical phases corresponding to the reservoir are determined, the quality of the reservoir can be determined according to the types corresponding to different rock physical phases, and the reservoir is classified into a water layer, an oil layer, a dry layer or a non-reservoir layer.
Table 1 below is a specific example of four types of petrophysical facies divided by petrophysical facies parameters. As shown in table 1, for reservoirs in which lithologic facies are sandy clastic flow fine sandstone and turbid flow fine sandstone, lithogenic facies are unstable component corrosion, pore structure facies are coarse-throat large-pore type and medium-throat large-pore type, the calculated petrophysical phase parameter is generally 2.97-3.39, and the petrophysical facies of the petrophysical phase parameter in the interval are divided into first type petrophysical facies; for reservoirs with lithologic facies of turbid fine siltstone and slumped fine siltstone, lithogenic facies of unstable components and pore structure facies of medium-throat large pore type and medium-throat middle pore type, the calculated physical phase parameter of the rock is generally 2.65-2.97, and the physical phase of the rock with the physical phase parameter of the rock in the interval is divided into second type physical phases of the rock; for lithologic facies which are turbid fine siltstones and slumped fine siltstones, lithogenic facies which are unstable component erosion facies, clay mineral filling facies and carbonate cementing facies, a pore structure facies which is a medium-throat medium-pore reservoir, the calculated petrophysical facies parameters are generally 1.65-2.67, and the petrophysical facies of the petrophysical facies parameters in the interval are divided into third type petrophysical facies; and for lithologic lithofacies including deep lake-semi-deep lake shale lithofacies and oil shale lithofacies, lithoforming facies including compacted compact facies, carbonate cementing facies and clay mineral filling facies, and pore structure facies including reservoir with fine-throat and small-pore type, the calculated physical rock phase parameters are generally 1.00-1.50, and the physical rock phases with the physical rock phase parameters in the interval are divided into the fourth type of physical rock phases. The above example is only a better illustration of the reservoir evaluation criteria through specific data, and the reservoir evaluation criteria in practical application may be adjusted according to the situation, which is not limited in this respect.
TABLE 1
The reservoir evaluation method based on the petrophysical facies is described below with reference to specific scenario examples. As shown in fig. 6A and 6B, the physical phases of the rocks belonging to different regions are determined for exploration aiming at the regions of different basins, wherein the type i pore structure, the type ii pore structure, the type iii pore structure and the type iv pore structure respectively correspond to a coarse-throat large pore type, a medium-throat medium pore type and a fine-throat small pore type; PF1, PF2, PF3, PF4 correspond to the first, second, third and fourth petrophysical facies, respectively. According to the difference of lithologic lithofacies types, lithofacies types and pore structure facies types corresponding to the regions with different depths in the graph, the method can be used for determining the rock physical facies of different regions. As can be seen by combining the comparison of oil and gas data in the graph, the petrophysical phase parameters corresponding to the first type of petrophysical phase and the second type of petrophysical phase are higher and correspond to an oil layer and a water layer; the petrophysical facies parameters corresponding to the third type of petrophysical facies and the fourth type of petrophysical facies are lower, and correspond to dry layers and non-reservoir layers. According to the embodiments of the reservoir evaluation method based on the petrophysical facies in the description in fig. 6A and fig. 6B, the petrophysical facies corresponding to different regions can be accurately determined, so that the oil-bearing performance of the reservoir quality of a single well can be accurately and effectively evaluated.
The following describes an embodiment of the reservoir evaluation device based on petrophysical facies, which is arranged on the computer equipment. As shown in fig. 7, the reservoir evaluation apparatus based on petrophysical facies includes:
the reservoir type determining module 710 is used for determining the lithology lithofacies type, lithogenesis facies type and pore structure facies type of the reservoir based on reservoir exploration data;
the reservoir parameter determining module 720 is used for determining lithologic facies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determining rule based on the lithologic facies type, lithofacies formation type and pore structure facies type of the reservoir;
a petrophysical phase parameter calculating module 730, configured to calculate a petrophysical phase parameter according to the lithologic lithofacies characterization parameter, the lithogenic facies characterization parameter, and the pore structure facies characterization parameter;
and the reservoir evaluation module 740 is configured to evaluate the reservoir by using the petrophysical phase parameters based on a preset reservoir evaluation criterion.
An embodiment of the present specification of a reservoir evaluation apparatus based on petrophysical facies is described below. As shown in fig. 8, the apparatus may include a memory and a processor.
In this embodiment, the memory may be implemented in any suitable manner. For example, the memory may be a read-only memory, a mechanical hard disk, a solid state disk, a U disk, or the like. The memory may be used to store computer instructions.
In this embodiment, the processor may be implemented in any suitable manner. For example, the processor may take the form of, for example, a microprocessor or processor and a computer-readable medium that stores computer-readable program code (e.g., software or firmware) executable by the (micro) processor, logic gates, switches, an Application Specific Integrated Circuit (ASIC), a programmable logic controller, an embedded microcontroller, and so forth. The processor may execute the computer instructions to perform the steps of: determining lithologic lithofacies types, lithofacies formation types and pore structure facies types of the reservoir based on the reservoir exploration data; determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir; calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters; and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
The systems, devices, modules or units illustrated in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions. One typical implementation device is a computer. In particular, the computer may be, for example, a personal computer, a laptop computer, a cellular telephone, a camera phone, a smartphone, a personal digital assistant, a media player, a navigation device, an email device, a game console, a tablet computer, a wearable device, or a combination of any of these devices.
From the above description of the embodiments, it is clear to those skilled in the art that the present specification can be implemented by software plus a necessary general hardware platform. Based on such understanding, the technical solutions of the present specification may be essentially or partially implemented in the form of software products, which may be stored in a storage medium, such as ROM/RAM, magnetic disk, optical disk, etc., and include instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) to execute the methods described in the embodiments or some parts of the embodiments of the present specification.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, for the system embodiment, since it is substantially similar to the method embodiment, the description is simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The description is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
This description may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The specification may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
While the specification has been described with examples, those skilled in the art will appreciate that there are numerous variations and permutations of the specification that do not depart from the spirit of the specification, and it is intended that the appended claims include such variations and modifications that do not depart from the spirit of the specification.
Claims (11)
1. A reservoir evaluation method based on rock physical facies is characterized by comprising the following steps:
determining lithologic lithofacies types, lithofacies formation types and pore structure facies types of the reservoir based on the reservoir exploration data;
determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir;
calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters;
and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
2. The method of claim 1, wherein the reservoir exploration data comprises at least one of:
resistivity logging curve data, natural gamma logging curve data and imaging logging data;
the determining lithofacies types of the reservoir includes:
and determining the lithofacies type of the reservoir according to at least one of the resistivity log data, the natural gamma log data and the imaging log data.
3. The method of claim 1, wherein the lithofacies types include at least one of: oil shale phase, semi-deep lake shale phase, slumped fine sandstone phase, turbid powder fine sandstone phase, and sandy clastic flow fine sandstone phase.
4. The method of claim 1, wherein the reservoir exploration data comprises at least one of:
conventional logging data, acoustic time difference logging data, natural gamma logging data and compensated density logging data are scaled by the core slice;
the determining the lithogenic facies type of the reservoir comprises:
and determining the lithogenic facies type of the reservoir according to at least one of the conventional logging data, the acoustic time difference logging data, the natural gamma logging data and the compensated density logging data of the core slice scale.
5. The method of claim 1, wherein the lithofacies types include at least one of: an unstable component corrosion phase, a clay mineral filling phase, a carbonate cementing phase and a compaction compact phase.
6. The method of claim 1, wherein the reservoir exploration data comprises at least one of:
expulsion pressure data, nuclear magnetic resonance T2Geometric mean value data;
the determining of the pore structure phase type of the reservoir comprises the following steps:
from displacement pressure data and NMR T2Determining a pore of the reservoir based on at least one of the geometric mean dataA gap structure phase type.
7. The method of claim 1, wherein the pore structure phase type comprises at least one of: coarse-throat macroporous type, medium-throat mesoporous type and fine-throat microporous type.
8. The method of claim 1, wherein the calculating petrophysical phase parameters from the lithology facies characterization parameters, the lithogenic facies characterization parameters, and the pore structure facies characterization parameters comprises:
and calculating rock physical phase parameters by combining the lithologic facies characterization parameters, the lithogenic facies characterization parameters and the pore structure facies characterization parameters on the basis of the core lithofacies type weight value, the lithogenic facies type weight value and the pore structure facies type weight value.
9. The method of claim 1, wherein the reservoir evaluation criteria comprise at least one of:
the corresponding relation between the first rock physical phase and the water layer;
the corresponding relation between the second rock physical phase and the oil layer;
the corresponding relation between the third rock physical phase and the dry layer;
the corresponding relation between the fourth type of rock physical facies and the non-reservoir stratum;
the evaluating the reservoir with the petrophysical phase parameters comprises:
and classifying the reservoir into a water layer, an oil layer, a dry layer or a non-reservoir layer by using the rock physical phase parameters based on preset reservoir evaluation criteria.
10. A petrophysical facies-based reservoir evaluation apparatus, comprising:
the reservoir type determining module is used for determining the lithologic facies type, lithomorphic facies type and pore structure facies type of the reservoir based on the reservoir exploration data;
the reservoir parameter determination module is used for determining lithologic facies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by utilizing a preset parameter determination rule based on the lithologic facies type, lithofacies formation type and pore structure facies type of the reservoir;
the rock physical phase parameter calculation module is used for calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters;
and the reservoir evaluation module is used for evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
11. A petrophysical facies-based reservoir evaluation apparatus comprising a memory and a processor;
the memory to store computer instructions;
the processor to execute the computer instructions to implement the steps of: determining lithologic lithofacies types, lithofacies formation types and pore structure facies types of the reservoir based on the reservoir exploration data; determining lithologic lithofacies characterization parameters, lithofacies formation characterization parameters and pore structure facies characterization parameters of the reservoir by using a preset parameter determination rule based on the lithologic lithofacies type, lithofacies formation type and pore structure facies type of the reservoir; calculating rock physical phase parameters according to the lithology lithofacies characterization parameters, the lithogenesis facies characterization parameters and the pore structure facies characterization parameters; and evaluating the reservoir by utilizing the rock physical phase parameters based on a preset reservoir evaluation standard.
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