CN116335652B - Method and device for determining reserve utilization degree of carbonate fracture-cave system - Google Patents
Method and device for determining reserve utilization degree of carbonate fracture-cave system Download PDFInfo
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- 238000000034 method Methods 0.000 title claims abstract description 41
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 23
- 230000003068 static effect Effects 0.000 claims abstract description 61
- 238000004519 manufacturing process Methods 0.000 claims abstract description 54
- 239000003921 oil Substances 0.000 claims description 83
- 239000010779 crude oil Substances 0.000 claims description 49
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 claims description 45
- 229910000037 hydrogen sulfide Inorganic materials 0.000 claims description 45
- 238000010422 painting Methods 0.000 claims description 21
- 239000011148 porous material Substances 0.000 claims description 19
- 238000012512 characterization method Methods 0.000 claims description 16
- 238000007476 Maximum Likelihood Methods 0.000 claims description 13
- 239000007788 liquid Substances 0.000 claims description 13
- 238000012360 testing method Methods 0.000 claims description 13
- 238000004364 calculation method Methods 0.000 claims description 5
- 208000010392 Bone Fractures Diseases 0.000 description 105
- 206010017076 Fracture Diseases 0.000 description 105
- 239000007789 gas Substances 0.000 description 37
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- 230000006870 function Effects 0.000 description 19
- 230000015572 biosynthetic process Effects 0.000 description 8
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- 239000004215 Carbon black (E152) Substances 0.000 description 4
- 229930195733 hydrocarbon Natural products 0.000 description 4
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Abstract
The specification provides a method and a device for determining reserve utilization degree of a carbonate fracture-cave system. The method comprises the following steps: acquiring seismic data, production dynamic data and reservoir property data of a target well; determining static parameters according to the seismic data; determining dynamic parameters according to the production dynamic data; determining reservoir property parameters according to the reservoir property data; and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir. Based on the method, the index for reserve utilization can be accurately determined from three dimensions of static characteristics, dynamic characteristics and reservoir property characteristics, and a data basis is provided for making reservoir exploitation measures.
Description
Technical Field
The specification belongs to the technical field of oil and gas reservoir exploration and development, and particularly relates to a method and a device for determining reserve utilization degree of a carbonate fracture-cave system.
Background
The ultra-deep fracture-control fracture-cavity carbonate rock is subjected to superposition transformation of multiple times, multiple types of fracture and karst actions, the formed fracture-cavity system is complex in internal structure and strong in spatial heterogeneity, the communication relation among the fracture-cavity systems is difficult to judge, the reserve utilization degree of a reservoir in the fracture-cavity system is difficult to calculate, and the efficient development of fracture-control fracture-cavity type oil and gas reservoirs is severely restricted.
In the prior art, a single factor is generally adopted to judge the reserve utilization degree, which results in lower calculation accuracy of the reserve utilization degree and influences the later establishment of the oil and gas reservoir exploitation measures.
In view of the above technical problems, no effective solution has been proposed at present.
Disclosure of Invention
The specification provides a method and a device for determining reserve utilization degree of a carbonate fracture-cave system, which can solve the technical problem that reserve utilization indexes cannot be accurately determined in the prior art and provide a data basis for formulating oil and gas reservoir exploitation measures.
An object of an embodiment of the present specification is to provide a carbonate fracture-cave system reserve usage degree determination method, including:
acquiring seismic data, production dynamic data and reservoir property data of a target well;
determining static parameters according to the seismic data;
determining dynamic parameters according to the production dynamic data;
determining reservoir property parameters according to the reservoir property data;
and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir.
Further, in another embodiment of the method, the determining the reserve utilization index based on the static parameter, the dynamic parameter, and the reservoir property parameter includes:
Determining a first component of a reserve use indicator based on the static parameter;
determining a second component of the reserve use indicator based on the dynamic parameter;
determining a third component of a reserve use indicator from the reservoir property parameter;
a reserve utilization index is determined based on the first component, the second component, and the third component.
Further, in another embodiment of the method, the determining the first component of the reserve use indicator includes:
determining a corresponding plurality of first sub-components according to the plurality of static parameters;
adding the first sub-components to obtain a first component of the reserve index;
the determining a second component of the reserve use indicator includes:
determining a corresponding plurality of second sub-components according to the plurality of dynamic parameters;
adding the plurality of second sub-components to obtain a second component of the reserve use index;
the determining a third component of the reserve use indicator includes:
determining a corresponding plurality of third subcomponents according to the plurality of reservoir property parameters;
and adding the plurality of third sub-components to obtain a third component of the reserve index.
Further, in another embodiment of the method, the determining the reserve use indicator includes:
Determining a reserve fraction from the first component, the second component, and the third component;
and according to the reserve use score, matching is conducted in the reserve use degree grade set, and a reserve use index is obtained.
Further, in another embodiment of the method, the determining the static parameter includes:
obtaining a maximum likelihood attribute body according to the seismic data;
carrying out fracture piece painting on the maximum likelihood attribute body to obtain a fracture piece painting result;
performing post-stack reservoir inversion on the seismic data to obtain a post-stack inversion pore body;
performing fracture-cavity reservoir characterization on the post-stack inversion pore body to obtain a fracture-cavity reservoir characterization result;
and taking the fracture piece painting result and the fracture hole reservoir layer painting result as static parameters.
Further, in another embodiment of the method, the determining the dynamic parameter includes:
constructing a fitting function between the engraving volume and the dynamic reserves according to the post-stack inversion pore body and the production dynamic data;
obtaining a first curve and a second curve according to the production dynamic data; wherein the first curve is a relation curve between the accumulated pressure drop and the accumulated liquid production amount; the second curve is a well test data curve;
And taking the fitting function between the engraving volume and the dynamic reserve, the first curve and the second curve as dynamic parameters.
Further, in another embodiment of the method, the reservoir property data comprises at least one of: the hydrogen sulfide content of the target well, the stratum mean hydrogen sulfide content, the crude oil density of the target well, the stratum mean crude oil density, the gas-oil ratio of the target well, the stratum mean gas-oil ratio, the phase type of the target well, and the phase type of the stratum.
Further, in another embodiment of the method, the determining reservoir property parameters includes:
determining a difference between the hydrogen sulfide content of the target well and the average hydrogen sulfide content of the formation as a hydrogen sulfide content parameter;
determining a difference between the crude oil density of the target well and the average crude oil density of the formation as a crude oil density parameter;
determining a difference between the gas-oil ratio of the target well and the stratum average gas-oil ratio as a gas-oil ratio parameter;
comparing whether the phase type of the target well is the same as the phase type of the stratum; and taking the comparison result as a phase type parameter;
and taking the hydrogen sulfide content parameter, the crude oil density parameter, the gas-oil ratio parameter and the phase state type parameter as the oil-gas reservoir property parameter.
On the other hand, the embodiment of the specification also provides a carbonate fracture-cave system reserve utilization degree determining device, which comprises:
the acquisition module is used for acquiring seismic data, production dynamic data and reservoir property data of the target well;
the first determining module is used for determining static parameters according to the seismic data;
the second determining module is used for determining dynamic parameters according to the production dynamic data;
the third determining module is used for determining the reservoir property parameters according to the reservoir property data;
and the calculation module is used for determining an reserve use index according to the static parameter, the dynamic parameter and the reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the reservoir.
In still another aspect, embodiments of the present disclosure further provide a computer readable storage medium having stored thereon computer instructions that when executed implement the above-described carbonate fracture and cave system reserve utilization determination method.
According to the method for determining the reserve utilization degree of the carbonate fracture-cave system, provided by the embodiment of the specification, seismic data, production dynamic data and reservoir property data of a target well are obtained; determining static parameters according to the seismic data; determining dynamic parameters according to the production dynamic data; determining reservoir property parameters according to the reservoir property data; and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir. According to the embodiment of the specification, the reserve utilization degree of the oil and gas reservoir is comprehensively determined according to static data such as seismic data of the target well, dynamic data such as production dynamic data and the like, and the oil and gas reservoir property data, so that the accuracy of a reserve utilization degree judgment result is improved. In addition, the reserve utilization degree can be represented in a quantitative mode by adopting reserve utilization indexes, the practicability is high, and a reliable basis is provided for measure of digging residual oil gas and improving the reserve utilization degree of a fracture-cavity system.
And determining a first component of the reserve use indicator based on the static parameter when determining the reserve use indicator based on the static parameter, the dynamic parameter, and the reservoir property parameter; determining a second component of the reserve use indicator based on the dynamic parameter; determining a third component of a reserve use indicator from the reservoir property parameter; a reserve utilization index is determined based on the first component, the second component, and the third component.
Further, determining a corresponding plurality of first subcomponents according to the plurality of static parameters; adding the first sub-components to obtain a first component of the reserve index; determining a corresponding plurality of second sub-components according to the plurality of dynamic parameters; adding the plurality of second sub-components to obtain a second component of the reserve use index; determining a corresponding plurality of third subcomponents according to the plurality of reservoir property parameters; and adding the plurality of third sub-components to obtain a third component of the reserve index.
Drawings
In order to more clearly illustrate the embodiments of the present disclosure, the drawings that are required for the embodiments will be briefly described below, and the drawings described below are only some embodiments described in the present disclosure, and other drawings may be obtained according to these drawings without inventive effort for a person of ordinary skill in the art.
FIG. 1 is a flow chart of one embodiment of a method for determining reserve utilization of a carbonate fracture-cave system provided herein;
FIG. 2 is a schematic block diagram showing an embodiment of a device for determining the reserve utilization of a carbonate fracture-cave system according to the present disclosure;
FIG. 3 is a schematic diagram of the structural composition of a server provided in the present specification;
fig. 4 is a schematic diagram of the extent to which the carbonate fracture and cave system reserves are obtained in one specific example of the scenario provided herein.
Detailed Description
In order to make the technical solutions in the present specification better understood by those skilled in the art, the technical solutions in the embodiments of the present specification will be clearly and completely described below with reference to the drawings in the embodiments of the present specification, and it is obvious that the described embodiments are only some embodiments of the present specification, not all embodiments. All other embodiments, which can be made by one of ordinary skill in the art without undue burden from the present disclosure, are intended to be within the scope of the present disclosure.
Considering that ultra-deep fracture-controlled fracture-cavity carbonate rock is subjected to superposition transformation of multiple times, multiple types of fracture and karst actions, the formed fracture-cavity system is complex in internal structure, strong in spatial heterogeneity and difficult to judge in communication relation among the fracture-cavity systems, so that the reserve utilization degree of a reservoir in the fracture-cavity system is difficult to calculate, and the efficient development of fracture-controlled fracture-cavity type oil and gas reservoirs is severely restricted. In the prior art, a single factor is generally adopted to judge the reserve utilization degree, which results in lower calculation accuracy of the reserve utilization degree and influences the later establishment of the oil and gas reservoir exploitation measures.
Aiming at the problems and the specific reasons for generating the problems in the prior method, the application introduces a carbonate fracture-cavity system reserve utilization degree determining method based on static parameters, dynamic parameters and reservoir property parameters so as to accurately calculate reserve utilization indexes.
Based on the thought, the specification provides a method for determining the reserve utilization degree of a carbonate fracture-cave system. Firstly, obtaining seismic data, production dynamic data and reservoir property data of a target well; then, determining static parameters according to the seismic data; determining dynamic parameters according to the production dynamic data; determining reservoir property parameters according to the reservoir property data; and finally, determining an reserve use index according to the static parameter, the dynamic parameter and the reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the reservoir.
Referring to fig. 1, an embodiment of the present disclosure provides a method for determining a reserve utilization degree of a carbonate fracture-cave system. In particular implementations, the method may include the following.
S101: and obtaining seismic data, production dynamic data and reservoir property data of the target well.
In some embodiments, the production dynamics data specifically includes: oil pressure data, oil gas yield data, oil nozzle opening data, accumulated pressure drop data, accumulated liquid production amount data and well test data.
In some embodiments, the reservoir property data specifically includes at least one of: the hydrogen sulfide content of the target well, the stratum average hydrogen sulfide content, the crude oil density of the target well, the stratum average crude oil density, the gas-oil ratio of the target well, the stratum average gas-oil ratio, the phase type of the target well and the phase type of the stratum; wherein the stratum is the stratum where the target well is located; the phase type includes at least one of: reservoir temperature, reservoir pressure, reservoir dew point pressure, reservoir saturation pressure, and the like.
S102: and determining static parameters according to the seismic data.
In some embodiments, the static parameter is a plurality; static parameters are understood to be parameters which do not change significantly over time.
In some embodiments, determining static parameters from the seismic data, when embodied, may include:
s1021: obtaining a maximum likelihood attribute body according to the seismic data;
s1022: carrying out fracture piece painting on the maximum likelihood attribute body to obtain a fracture piece painting result;
S1023: performing post-stack reservoir inversion on the seismic data to obtain a post-stack inversion pore body;
s1024: performing fracture-cavity reservoir characterization on the post-stack inversion pore body to obtain a fracture-cavity reservoir characterization result;
s1025: and taking the fracture piece painting result and the fracture hole reservoir layer painting result as static parameters.
In some embodiments, the seismic data may be three-dimensional seismic data, the maximum likelihood attribute is extracted from the three-dimensional seismic data, and then three-dimensional construction is performed on the maximum likelihood attribute to obtain a three-dimensional maximum likelihood attribute body.
In some embodiments, fracture plate characterization is to describe fracture space spread characteristics of the stratum where the target well is located, fracture space spread conditions of the stratum where the target well is located can be known by means of fracture plate characterization results, and spatial position relations among the fracture plates can be obtained.
In some embodiments, the post-stack inversion void volume is a three-dimensional structure that is used to characterize the porosity of the rock of the target well.
In some embodiments, the spatial positional relationship between the fracture-cavity bodies may be determined from fracture-cavity reservoir characterization results.
S103: and determining dynamic parameters according to the production dynamic data.
In some embodiments, the dynamic parameter is a plurality of; dynamic parameters are understood to be parameters that vary significantly over time.
In some embodiments, determining the dynamic parameter according to the production dynamic data may include, when implemented:
s1031: constructing a fitting function between the engraving volume and the dynamic reserves according to the post-stack inversion pore body and the production dynamic data;
s1032: obtaining a first curve and a second curve according to the production dynamic data; wherein the first curve is a relation curve between the accumulated pressure drop and the accumulated liquid production amount; the second curve is a well test data curve;
s1033: and taking the fitting function between the engraving volume and the dynamic reserve, the first curve and the second curve as dynamic parameters.
In some embodiments, constructing a fitting function between the engraved volume and the dynamic reserve from the post-stack inverted pore volume and the production dynamic data, may include, when embodied:
s10311: performing three-dimensional carving on the post-stack inversion pore body to obtain a target fracture-cavity reservoir carving volume;
s10312: calculating a target dynamic reserve according to the production dynamic data;
S10313: acquiring the carving volume of a fracture-cave reservoir layer of an adjacent well and the dynamic reserve of the adjacent well;
s10314: and fitting the target fracture-cavity reservoir carving volume, the target dynamic reserve, the fracture-cavity reservoir carving volume of the adjacent well and the dynamic reserve of the adjacent well to obtain a fitting function between the carving volume and the dynamic reserve.
In some embodiments, the post-stack inversion pore body is three-dimensionally engraved, which may specifically be: and (3) performing integral operation on the post-stack inversion pore volume, wherein the result of the integral operation is the carving volume of the target fracture-cave reservoir.
In some embodiments, data for oil pressure, oil and gas production, and choke opening, etc. may be extracted from the production dynamics data and used to calculate a target dynamic reserve.
In some embodiments, the method can be used for obtaining the fracture-cave reservoir engraving volume of the adjacent well and the dynamic reserve of the adjacent well according to the above embodiments; wherein the adjacent well is a well that is located in the same formation as the target well and is located adjacent thereto.
In some embodiments, the accumulated pressure drop data and the accumulated liquid production amount data can be extracted from the production dynamic data, and a relation curve between the accumulated pressure drop and the accumulated liquid production amount is obtained according to the accumulated pressure drop data and the accumulated liquid production amount data, and the relation curve between the accumulated pressure drop and the accumulated liquid production amount is taken as a first curve.
In some embodiments, well test data may be extracted from the production dynamics data and a well test data curve may be derived from the well test data, with the well test data curve being the second curve.
S104: and determining the reservoir property parameters according to the reservoir property data.
In some embodiments, the reservoir property parameter is a plurality.
In some embodiments, determining the reservoir property parameter according to the reservoir property data may include, when implemented:
s1041: determining a difference between the hydrogen sulfide content of the target well and the average hydrogen sulfide content of the formation as a hydrogen sulfide content parameter;
s1042: determining a difference between the crude oil density of the target well and the average crude oil density of the formation as a crude oil density parameter;
s1043: determining a difference between the gas-oil ratio of the target well and the stratum average gas-oil ratio as a gas-oil ratio parameter;
s1044: comparing whether the phase type of the target well is the same as the phase type of the stratum; and taking the comparison result as a phase type parameter;
s1045: and taking the hydrogen sulfide content parameter, the crude oil density parameter, the gas-oil ratio parameter and the phase state type parameter as the oil-gas reservoir property parameter.
In some embodiments, taking the example of the phase type being reservoir temperature, the comparing whether the phase type of the target well and the phase type of the formation are the same comprises: calculating a difference value between the reservoir temperature of the target well and the reservoir temperature of the stratum, detecting whether the difference value is smaller than a preset temperature threshold value, and determining that the phase type of the target well is the same as the phase type of the stratum under the condition that the difference value is smaller than the preset temperature threshold value; and under the condition that the difference value is larger than or equal to a preset temperature threshold value, determining that the phase type of the target well is different from the phase type of the stratum. It should be noted that, the present specification is exemplified by taking the phase type as the temperature of the oil and gas reservoir as an example, and when the phase type is other data, the comparison result may be determined by referring to the above embodiment, and the kind of the phase type is not limited in the present specification.
S105: and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir.
In some embodiments, determining the reserve use indicator based on the static parameter, the dynamic parameter, and the reservoir property parameter, may include, when implemented:
S1051: determining a first component of a reserve use indicator based on the static parameter;
s1052: determining a second component of the reserve use indicator based on the dynamic parameter;
s1053: determining a third component of a reserve use indicator from the reservoir property parameter;
s1054: a reserve utilization index is determined based on the first component, the second component, and the third component.
In some embodiments, the determining the first component of the reserve use indicator, when embodied, may include:
s10511: determining a corresponding plurality of first sub-components according to the plurality of static parameters;
s10512: the first sub-components are added to obtain a first component of the reserve index.
In some embodiments, the plurality of first subcomponents includes: fracture fraction, fracture-cavity reservoir fraction.
In some embodiments, determining a corresponding plurality of first subcomponents based on a plurality of static parameters may include, in particular:
s11: detecting the space position of the breaking piece painting result;
s12: under the condition that the fracture piece intersection is determined, determining that the fracture piece component is equal to a first preset value; or, in the case of determining that the fracture pieces do not intersect, determining that the fracture piece component is equal to a second preset value;
S13: detecting the spatial position of the fracture-cavity reservoir in the fracture-cavity reservoir characterization result;
s14: under the condition that the fracture-cavity reservoir superposition is determined, determining that the fracture-cavity reservoir component is equal to a third preset value; alternatively, in the event that it is determined that the fracture-cave reservoirs are not stacked, it is determined that the fracture-cave reservoir component is equal to a fourth preset value.
In some embodiments, adding the plurality of first sub-components to obtain the first component of the reserve use indicator, when embodied, includes: and summing the fracture piece component and the fracture hole reservoir layer component to obtain a first component of the reserve use index.
In some embodiments, the first preset value may be set to 0, the second preset value to 1, the third preset value to 0, and the fourth preset value to 1.
In some embodiments, the determining the second component of the reserve use indicator, when embodied, may include:
s10521: determining a corresponding plurality of second sub-components according to the plurality of dynamic parameters;
s10522: and adding the second sub-components to obtain a second component of the reserve index.
In some embodiments, the plurality of second subcomponents includes: fitting coefficient component, first curve component, second curve component.
In some embodiments, determining a respective plurality of second sub-components from the plurality of dynamic parameters includes:
s21: determining a fitting coefficient of a fitting function between the engraving volume and the dynamic reserve according to the fitting function between the engraving volume and the dynamic reserve;
s22: determining fitting coefficient components according to the fitting coefficients;
s23: determining the curve type of the first curve according to the first curve;
s24: determining a first curve component according to the curve type of the first curve;
s25: determining the curve type of the second curve according to the second curve;
s26: and determining a second curve component according to the curve type of the second curve.
In some embodiments, adding the plurality of second sub-components to obtain the second component of the reserve use indicator, when embodied, includes: and summing the fitting coefficient component, the first curve component and the second curve component to obtain a second component of the reserve use index.
In some embodiments, it may be detected whether the fit coefficient is greater than a preset fit coefficient threshold; under the condition that the fitting coefficient is larger than or equal to a preset fitting coefficient threshold value, determining that the fitting coefficient component is equal to a fifth preset value; or under the condition that the fitting coefficient is smaller than a preset fitting coefficient threshold value, determining that the fitting coefficient component is equal to a sixth preset value; the preset fitting coefficient threshold may be 0.8, the fifth preset value may be 1, and the sixth preset value may be 0.
In some embodiments, when the curve type of the first curve is a monotonically increasing type curve or a monotonically decreasing type curve, determining that the first curve component is equal to a seventh preset value; or when the curve type of the first curve is a non-monotonic curve, determining that the first curve component is equal to an eighth preset value; wherein a non-monotonic curve means that the curve does not have monotonicity within the defined domain; the seventh preset value may be 1 and the eighth preset value may be 0.
In some embodiments, when the curve type of the second curve is a single-hole type, determining that the second curve component is equal to a ninth preset value; or when the curve type of the second curve is multi-slot type, determining that the second curve component is equal to a tenth preset value; wherein, the single fracture-cavity type refers to that only one fracture-cavity body is arranged at the periphery of the target well to supply oil gas; the multi-fracture-cavity type is characterized in that a plurality of fracture-cavity bodies are arranged at the periphery of a target well and used for supplying oil gas; the ninth preset value may be 1 and the tenth preset value may be 0.
In some embodiments, the determining the third component of the reserve use indicator, when embodied, may include:
s10331: determining a corresponding plurality of third subcomponents according to the plurality of reservoir property parameters;
S10532: and adding the plurality of third sub-components to obtain a third component of the reserve index.
In some embodiments, the plurality of third subcomponents includes: hydrogen sulfide content component, crude oil density component, gas-oil ratio component, and phase type component.
In some embodiments, determining a corresponding plurality of third sub-components to implement based on the plurality of reservoir property parameters comprises:
s31: calculating the absolute value of the hydrogen sulfide content parameter; determining the hydrogen sulfide content component according to the absolute value of the hydrogen sulfide content parameter;
s32: calculating the absolute value of the crude oil density parameter; determining the density component of the crude oil according to the absolute value of the density parameter of the crude oil;
s33: calculating the absolute value of the gas-oil ratio parameter; determining a gas-oil ratio component according to the absolute value of the gas-oil ratio parameter;
s34: and determining a phase type component according to the phase type parameter.
In some embodiments, adding the plurality of third sub-components to obtain a third component of the reserve use indicator, when embodied, includes: and summing the hydrogen sulfide content component, the crude oil density component, the gas-oil ratio component and the phase type component to obtain a third component of the reserve use index.
In some embodiments, it may be detected whether the absolute value of the hydrogen sulfide content parameter is equal to or less than a preset hydrogen sulfide content threshold; determining that the hydrogen sulfide content component is equal to an eleventh preset value under the condition that the absolute value of the hydrogen sulfide content parameter is smaller than or equal to a preset hydrogen sulfide content threshold value; or determining that the hydrogen sulfide content component is equal to a twelfth preset value under the condition that the absolute value of the hydrogen sulfide content parameter is larger than a preset hydrogen sulfide content threshold value; wherein the preset hydrogen sulfide content threshold may be 300ppm, the eleventh preset value may be 1, and the twelfth preset value may be 0.
In some embodiments, it may be detected whether the absolute value of the crude oil density parameter is less than or equal to a preset crude oil density threshold; in the case that the absolute value of the crude oil density parameter is smaller than or equal to a preset valueDetermining that the crude oil density component is equal to a thirteenth preset value in the case of the crude oil density threshold; or, in the case that the absolute value of the crude oil density parameter is greater than the preset crude oil density threshold, determining that the crude oil density component is equal to a fourteenth preset value; wherein the preset crude oil density threshold value can be 0.02g/cm 3 The thirteenth preset value may be 1 and the fourteenth preset value may be 0.
In some embodiments, it may be detected whether the absolute value of the gas-oil ratio parameter is equal to or less than a preset gas-oil ratio threshold; under the condition that the absolute value of the gas-oil ratio parameter is smaller than or equal to a preset gas-oil ratio threshold value, determining that the gas-oil ratio component is equal to a fifteenth preset value; or under the condition that the absolute value of the crude oil density parameter is larger than a preset gas-oil ratio threshold value, determining that the gas-oil ratio component is equal to a sixteenth preset value; wherein the preset gas-oil ratio threshold value can be 100m 3 /m 3 The fifteenth preset value may be 1 and the sixteenth preset value may be 0.
In some embodiments, in the event that the phase type parameters are the same, determining that the phase type component is equal to a seventeenth preset value; or under the condition that the phase state type parameters are different, determining that the phase state type component is equal to an eighteenth preset value; wherein, the seventeenth preset value may be 1, and the eighteenth preset value may be 0.
In some embodiments, the determining the reserve use indicator, when embodied, may include:
s10541: determining a reserve fraction from the first component, the second component, and the third component;
s10542: and according to the reserve use score, matching is conducted in the reserve use degree grade set, and a reserve use index is obtained.
In some embodiments, the first, second, and third components may be summed, with the result of the summation being used as the reserve fraction.
In some embodiments, the first weight value, the second weight value, the third weight value may be preset, and the reserve fraction may be determined according to the following formula:
P＝a 1 ·q 1 +a 2 ·q 2 +a 3 ·q 3
wherein P represents a reserve fraction, a 1 Represents a first weight value, q 1 Representing the first component, a 2 Represents a second weight value, q 2 Representing the second component, a 3 Represents a third weight value, q 3 Representing the third component.
In some embodiments, the first component, the second component, and the third component may also be input into a pre-built machine learning model, and an output result of the pre-built machine learning model is used as a reserve fraction; the pre-constructed machine learning model is obtained through training according to historical first component data, historical second component data, historical third component data and historical reserve utilization score data and is used for predicting and outputting reserve utilization scores.
In some embodiments, a higher reserve fraction indicates a greater probability of reserve not being used by the hydrocarbon reservoir, and a greater probability of hydrocarbon production by the late stage measure; the reserve usage level set may be set as follows: in the case where the reserve usage score is less than 4, the reserve usage index is equal to one level; when the reserve use score is equal to or greater than 4, the reserve use index is equal to two levels; the primary level indicates that the reserve utilization degree of the oil and gas reservoir is poor, and the probability of obtaining oil and gas by continuous exploitation in the later period is low; the second level shows that the reserve utilization degree of the oil and gas reservoir is good, and the probability of obtaining oil and gas by continuous exploitation in the later period is high.
In some embodiments, under the condition that the reserve utilization index is equal to the second level, the submerged modes such as old well sidetracking, acid fracturing transformation, hydraulic expansion and the like can be adopted, so that the oil and gas recovery ratio and the reserve utilization degree of the oil and gas reservoir are further improved.
Through the embodiment, the reserve utilization index can be accurately determined from the three dimensions of the static characteristic, the dynamic characteristic and the reservoir property characteristic, a data basis is provided for the subsequent establishment of reservoir exploitation measures, and a reliable basis is provided for the subsequent measures to excavate residual oil and improve the reserve utilization degree.
Please refer to table 1. One specific example of a scenario for this specification is presented below.
Step 1: assigning a numerical value to the reserve consumption situation judged by the fracture piece painting according to the fracture piece painting result, and if the fracture pieces are not intersected (namely the fracture pieces are independent), enabling the numerical value to be equal to a second preset value; if the fracture pieces are intersected, the numerical value is equal to a first preset value;
step 2: giving a numerical value to the seam hole reservoir layer depiction judging reserve consumption condition according to the seam hole reservoir layer depiction result, and if the seam hole reservoir layers are not overlapped (namely the seam hole reservoir layers are independent), enabling the numerical value to be equal to a fourth preset value; if the fracture and cave storage layers are stacked, the numerical value is equal to a third preset value;
step 3: summing the fracture moment painting judgment reserve utilization condition assignment result obtained in the step 1 and the fracture hole reservoir painting judgment reserve utilization condition assignment result obtained in the step 2 to obtain an evaluation parameter of the static characteristic of the fracture hole system;
step 4: utilizing the fitting coefficient of the carving volume and the dynamic reserve fitting function to give a numerical value to the reserve utilization condition judged by the fitting coefficient, and if the fitting coefficient is more than or equal to 0.8, the numerical value is equal to a fifth preset value; if the fitting coefficient is smaller than 0.8, the numerical value is equal to a sixth preset value.
Step 5: judging the reserve utilization condition by utilizing the curve type of the first curve to give a numerical value to the accumulated pressure drop-accumulated liquid yield relation curve type, and if the curve type of the first curve is a monotonically increasing curve or a monotonically decreasing curve, making the numerical value equal to a seventh preset value; if the curve type of the first curve is a non-monotonic curve, the value is equal to an eighth preset value;
Step 6: utilizing the curve type of the second curve to judge the reserve consumption situation and giving a value to the well test curve type, and if the curve type of the second curve is single-slot type, enabling the value to be equal to a ninth preset value; if the curve type of the second curve is a multi-slit hole type, the numerical value is equal to a tenth preset value;
step 7: summing the fit coefficient judgment reserve utilization condition assignment result obtained in the step 4, the cumulative pressure drop-cumulative liquid production amount relation curve type judgment reserve utilization condition assignment result obtained in the step 5 and the well test curve type judgment reserve utilization condition assignment result obtained in the step 6 to obtain an evaluation parameter of the dynamic characteristics of the fracture-cavity system;
step 8: utilizing the hydrogen sulfide content parameter to judge the reserve consumption situation and giving a numerical value, and if the absolute value of the hydrogen sulfide content parameter is less than or equal to 300ppm, the numerical value is equal to an eleventh preset value; if the absolute value of the hydrogen sulfide content parameter is 300ppm, the value is equal to an eleventh preset value;
step 9: giving a value to the crude oil density determination reserve using the crude oil density parameter, if the absolute value of the crude oil density parameter is 0.02g/cm or less 3 The value is equal to the thirteenth preset value; if the absolute value of the crude oil density parameter is greater than 0.02g/cm 3 The value is equal to the fourteenth preset value;
step 10: the gas-oil ratio parameter is used to give a value to the gas-oil ratio determination reserve use, and if the absolute value of the gas-oil ratio parameter is 100m or less 3 /m 3 The value is equal to the fifteenth preset value; if the absolute value of the gas-oil ratio parameter is more than 100m 3 /m 3 The value is equal to the sixteenth preset value;
step 11: utilizing the phase type parameter to assign a numerical value to the phase type judgment reserve utilization condition, and if the phase type parameter is the same, enabling the numerical value to be equal to a seventeenth preset value; if the phase type parameters are different, the numerical value is equal to an eighteenth preset value;
step 12: summing the hydrogen sulfide content judgment reserve utilization condition assignment result obtained in the step 8, the crude oil density judgment reserve utilization condition assignment result obtained in the step 9, the gas-oil ratio judgment reserve utilization condition assignment result obtained in the step 10 and the phase state type judgment reserve utilization condition assignment result obtained in the step 11 to obtain evaluation parameters of the hydrocarbon reservoir property characteristics of the fracture-cavity system;
step 13: summing the evaluation parameters of the static characteristics of the fracture-cavity system obtained in the step 3, the evaluation parameters of the dynamic characteristics of the fracture-cavity system obtained in the step 7 and the evaluation parameters of the hydrocarbon reservoir property characteristics of the fracture-cavity system obtained in the step 12 to obtain final evaluation parameters of the reserve utilization degree of the fracture-cavity system; the larger the final evaluation parameter of the reserve utilization degree of the fracture-cavity system is, the larger the non-utilization probability of the reserve of the fracture-cavity system is, and the larger the probability of oil and gas increase by the later measures is.
TABLE 1
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Referring to fig. 4, another specific example of a scenario of the present specification is described below. In FIG. 4, the static characteristics of the fracture-cave system may be described by fracture-zone characterization results, fracture-cave reservoir characterization results; describing the dynamic characteristics of the fracture-cavity system through a relation curve between the engraved volume and the dynamic reserve fitting function, the accumulated pressure drop and the accumulated liquid production amount and a well test data curve; describing the oil and gas reservoir property characteristics of the fracture-cavity system through the content of hydrogen sulfide, the density of crude oil, the gas-oil ratio and the phase type; and finally, integrating static characteristics, dynamic characteristics and reservoir property characteristics to obtain the reserve utilization degree.
Based on the above method for determining the reserve usage degree of the carbonate fracture-cavity system, the present disclosure further provides an embodiment of a device for determining the reserve usage degree of the carbonate fracture-cavity system, as shown in fig. 2, where the device for determining the reserve usage degree of the carbonate fracture-cavity system specifically includes the following modules:
an acquisition module 201, configured to acquire seismic data, production dynamic data, and reservoir property data of a target well;
a first determining module 202, configured to determine static parameters according to the seismic data;
a second determining module 203, configured to determine a dynamic parameter according to the production dynamic data;
A third determining module 204, configured to determine a reservoir property parameter according to the reservoir property data;
a calculation module 205, configured to determine a reserve usage index according to the static parameter, the dynamic parameter, and the reservoir property parameter, where the reserve usage index is used to represent a reserve usage degree of the reservoir.
In some embodiments, the first determining module 202 is specifically configured to obtain a maximum likelihood attribute volume according to the seismic data; carrying out fracture piece painting on the maximum likelihood attribute body to obtain a fracture piece painting result; performing post-stack reservoir inversion on the seismic data to obtain a post-stack inversion pore body; performing fracture-cavity reservoir characterization on the post-stack inversion pore body to obtain a fracture-cavity reservoir characterization result; and taking the fracture piece painting result and the fracture hole reservoir layer painting result as static parameters.
In some embodiments, the second determining module 203 is specifically configured to construct a fitting function between the engraved volume and the dynamic reserves according to the post-stack inversion pore volume and the production dynamic data; obtaining a first curve and a second curve according to the production dynamic data; wherein the first curve is a relation curve between the accumulated pressure drop and the accumulated liquid production amount; the second curve is a well test data curve; and taking the fitting function between the engraving volume and the dynamic reserve, the first curve and the second curve as dynamic parameters.
In some embodiments, the reservoir property data includes at least one of: the hydrogen sulfide content of the target well, the stratum mean hydrogen sulfide content, the crude oil density of the target well, the stratum mean crude oil density, the gas-oil ratio of the target well, the stratum mean gas-oil ratio, the phase type of the target well, and the phase type of the stratum.
In some embodiments, the third determining module 204 is specifically configured to determine a difference between the hydrogen sulfide content of the target well and the average hydrogen sulfide content of the formation as the hydrogen sulfide content parameter; determining a difference between the crude oil density of the target well and the average crude oil density of the formation as a crude oil density parameter; determining a difference between the gas-oil ratio of the target well and the stratum average gas-oil ratio as a gas-oil ratio parameter; comparing whether the phase type of the target well is the same as the phase type of the stratum; and taking the comparison result as a phase type parameter; and taking the hydrogen sulfide content parameter, the crude oil density parameter, the gas-oil ratio parameter and the phase state type parameter as the oil-gas reservoir property parameter.
In some embodiments, the calculating module 205 is specifically configured to determine a first component of the reserve utilization index based on the static parameter; determining a second component of the reserve use indicator based on the dynamic parameter; determining a third component of a reserve use indicator from the reservoir property parameter; a reserve utilization index is determined based on the first component, the second component, and the third component.
It should be noted that, the units, devices, or modules described in the above embodiments may be implemented by a computer chip or entity, or may be implemented by a product having a certain function. For convenience of description, the above devices are described as being functionally divided into various modules, respectively. Of course, when the present description is implemented, the functions of each module may be implemented in the same piece or pieces of software and/or hardware, or a module that implements the same function may be implemented by a plurality of sub-modules or a combination of sub-units, or the like. The above-described apparatus embodiments are merely illustrative, for example, the division of the units is merely a logical function division, and there may be additional divisions when actually implemented, for example, multiple units or components may be combined or integrated into another system, or some features may be omitted or not performed. Alternatively, the coupling or direct coupling or communication connection shown or discussed with each other may be an indirect coupling or communication connection via some interfaces, devices or units, which may be in electrical, mechanical or other form.
The embodiments of the present specification also provide a computer storage medium storing computer program instructions for a carbonate fracture and cave system reserve utilization determination method, the computer program instructions when executed implementing: acquiring seismic data, production dynamic data and reservoir property data of a target well; determining static parameters according to the seismic data; determining dynamic parameters according to the production dynamic data; determining reservoir property parameters according to the reservoir property data; and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir.
In the present embodiment, the storage medium includes, but is not limited to, a random access Memory (Random Access Memory, RAM), a Read-Only Memory (ROM), a Cache (Cache), a Hard Disk (HDD), or a Memory Card (Memory Card). The memory may be used to store computer program instructions. The network communication unit may be an interface for performing network connection communication, which is set in accordance with a standard prescribed by a communication protocol.
In this embodiment, the functions and effects of the program instructions stored in the computer storage medium may be explained in comparison with other embodiments, and are not described herein.
The present disclosure also provides a server comprising a processor and a memory for storing processor-executable instructions, the processor, when embodied, being operable to perform the following steps according to the instructions: acquiring seismic data, production dynamic data and reservoir property data of a target well; determining static parameters according to the seismic data; determining dynamic parameters according to the production dynamic data; determining reservoir property parameters according to the reservoir property data; and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir.
In order to more accurately complete the above instructions, referring to fig. 3, another specific server is further provided in this embodiment of the present disclosure, where the server includes a network communication port 301, a processor 302, and a memory 303, and the above structures are connected by an internal cable, so that each structure may perform specific data interaction.
The network communication port 301 may be specifically used to obtain seismic data, production dynamic data, and reservoir property data of the target well.
The processor 302 may be configured to determine static parameters from the seismic data; determining dynamic parameters according to the production dynamic data; determining reservoir property parameters according to the reservoir property data; and determining an reserve use index according to the static parameter, the dynamic parameter and the oil and gas reservoir property parameter, wherein the reserve use index is used for representing the reserve use degree of the oil and gas reservoir.
The memory 303 may be used for storing a corresponding program of instructions.
In this embodiment, the network communication port 301 may be a virtual port that binds with different communication protocols, so that different data may be sent or received. For example, the network communication port may be a port responsible for performing web data communication, a port responsible for performing FTP data communication, or a port responsible for performing mail data communication. The network communication port may also be an entity's communication interface or a communication chip. For example, it may be a wireless mobile network communication chip, such as GSM, CDMA, etc.; it may also be a Wifi chip; it may also be a bluetooth chip.
In this embodiment, the processor 302 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 storing computer-readable program code (e.g., software or firmware) executable by the (micro) processor, logic gates, switches, an application specific integrated circuit (Application Specific Integrated Circuit, ASIC), a programmable logic controller, and an embedded microcontroller, among others. The description is not intended to be limiting.
In this embodiment, the memory 303 may include a plurality of layers, and in a digital system, the memory may be any memory as long as it can hold binary data; in an integrated circuit, a circuit with a memory function without a physical form is also called a memory, such as a RAM, a FIFO, etc.; in the system, the storage device in physical form is also called a memory, such as a memory bank, a TF card, and the like.
Although the present description provides method operational steps as described in the examples or flowcharts, more or fewer operational steps may be included based on conventional or non-inventive means. The order of steps recited in the embodiments is merely one way of performing the order of steps and does not represent a unique order of execution. When implemented by an apparatus or client product in practice, the methods illustrated in the embodiments or figures may be performed sequentially or in parallel (e.g., in a parallel processor or multi-threaded processing environment, or even in a distributed data processing environment). The terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, it is not excluded that additional identical or equivalent elements may be present in a process, method, article, or apparatus that comprises a described element. The terms first, second, etc. are used to denote a name, but not any particular order.
Those skilled in the art will also appreciate that, in addition to implementing the controller in a pure computer readable program code, it is well possible to implement the same functionality by logically programming the method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers, etc. Such a controller can be regarded as a hardware component, and means for implementing various functions included therein can also be regarded as a structure within the hardware component. Or even means for achieving the various functions may be regarded as either software modules implementing the methods or structures within hardware components.
The 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, classes, 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.
From the above description of embodiments, it will be apparent to those skilled in the art that the present description may be implemented in software plus a necessary general hardware platform. Based on such understanding, the technical solutions of the present specification may be embodied essentially in the form of a software product, which may be stored in a storage medium, such as a ROM/RAM, a magnetic disk, an optical disk, etc., and include several instructions to cause a computer device (which may be a personal computer, a mobile terminal, a server, or a network device, etc.) to perform the methods described in the various embodiments or portions of the embodiments of the present specification.
Various embodiments in this specification are described in a progressive manner, and identical or similar parts are all provided for each embodiment, each embodiment focusing on differences from other embodiments. The specification is operational with numerous general purpose or special purpose computer system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable electronic devices, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
Although the present specification has been described by way of example, it will be appreciated by those skilled in the art that there are many variations and modifications to the specification without departing from the spirit of the specification, and it is intended that the appended claims encompass such variations and modifications as do not depart from the spirit of the specification.
Claims (5)
1. A method for determining reserve utilization level of a carbonate fracture-cave system, comprising:
acquiring seismic data, production dynamic data and reservoir property data of a target well;
determining static parameters according to the seismic data;
determining dynamic parameters according to the production dynamic data;
determining reservoir property parameters according to the reservoir property data;
determining reserve use indexes according to the static parameters, the dynamic parameters and the reservoir property parameters, wherein the reserve use indexes are used for representing reserve use degrees of a reservoir;
wherein determining a reserve utilization index based on the static parameter, the dynamic parameter, and the reservoir property parameter comprises: determining a first component of a reserve use indicator based on the static parameter; determining a second component of the reserve use indicator based on the dynamic parameter; determining a third component of a reserve use indicator from the reservoir property parameter; determining a reserve use indicator from the first component, the second component, and the third component;
The determining static parameters includes: obtaining a maximum likelihood attribute body according to the seismic data; carrying out fracture piece depiction on the maximum likelihood attribute body to obtain fracture piece depiction results as intersecting or non-intersecting; if the intersection gives a score of a first preset value, if the intersection gives a score of a second preset value; performing post-stack reservoir inversion on the seismic data to obtain a post-stack inversion pore body; performing fracture-cavity reservoir characterization on the post-stack inversion pore body to obtain a fracture-cavity reservoir characterization result which is superposition or non-superposition; if the stacking assignment score is a third preset value, if the stacking assignment score is not a fourth preset value; taking the fracture piece painting result and the fracture hole reservoir painting result as static parameters, summing all scores of the static parameters, and taking the summed result as a first component of a reserve utilization index;
the determining the dynamic parameters includes: constructing a fitting function between the engraving volume and the dynamic reserve according to the post-stack inversion pore body and the production dynamic data to obtain a fitting coefficient, if the fitting coefficient is more than or equal to 0.8, giving a score as a fifth preset value, otherwise giving the score as a sixth preset value; obtaining a first curve and a second curve according to the production dynamic data; the first curve is a relation curve between the accumulated pressure drop and the accumulated liquid yield, if the first curve type is a monotonic curve, the score is given as a seventh preset value, otherwise, the score is given as an eighth preset value; the second curve is a well test data curve, the score is given as a ninth preset value if the second curve is of a single fracture-hole type, and the score is given as a tenth preset value if the second curve is of a multi-fracture-hole type; taking a fitting function between the engraved volume and the dynamic reserve, the first curve and the second curve as dynamic parameters, summing all scores of the dynamic parameters, and taking the summation result as a second component of a reserve utilization index;
The determining of reservoir property parameters comprises: determining the difference between the hydrogen sulfide content of the target well and the average hydrogen sulfide content of the stratum, and if the absolute value of the hydrogen sulfide content parameter is smaller than or equal to a first threshold value, giving the score as an eleventh preset value, otherwise, giving the score as a twelfth preset value; determining the difference between the crude oil density of the target well and the stratum average crude oil density as a crude oil density parameter, if the absolute value of the crude oil density parameter is smaller than or equal to a second threshold value, giving a score as a thirteenth preset value, otherwise, giving a score as a fourteenth preset value; determining a difference value between the gas-oil ratio of the target well and the stratum average gas-oil ratio, and if the absolute value of the gas-oil ratio parameter is smaller than or equal to a third threshold value, giving a score as a fifteenth preset value, otherwise, giving the score as a sixteenth preset value; comparing whether the phase type of the target well is the same as the phase type of the stratum; the comparison result is used as a phase type parameter, if the phase type parameters are the same, a seventeenth preset value is given to the score, and otherwise, an eighteenth preset value is given to the score; taking the hydrogen sulfide content parameter, the crude oil density parameter, the gas-oil ratio parameter and the phase state type parameter as reservoir property parameters, summing all scores of the reservoir property parameters, and taking the sum result as a third component of the index for reserve.
2. The method of claim 1, wherein determining the first component of the reserve use indicator comprises:
determining a corresponding plurality of first sub-components according to the plurality of static parameters;
adding the first sub-components to obtain a first component of the reserve index;
the determining a second component of the reserve use indicator includes:
determining a corresponding plurality of second sub-components according to the plurality of dynamic parameters;
adding the plurality of second sub-components to obtain a second component of the reserve use index;
the determining a third component of the reserve use indicator includes:
determining a corresponding plurality of third subcomponents according to the plurality of reservoir property parameters;
and adding the plurality of third sub-components to obtain a third component of the reserve index.
3. The method of claim 1, wherein the determining a reserve utilization index comprises:
determining a reserve fraction from the first component, the second component, and the third component;
and according to the reserve use score, matching is conducted in the reserve use degree grade set, and a reserve use index is obtained.
4. A carbonate fracture-cave system reserve utilization degree determining apparatus, comprising:
The acquisition module is used for acquiring seismic data, production dynamic data and reservoir property data of the target well;
the first determining module is used for determining static parameters according to the seismic data;
the second determining module is used for determining dynamic parameters according to the production dynamic data;
the third determining module is used for determining the reservoir property parameters according to the reservoir property data;
the calculation module is used for determining reserve use indexes according to the static parameters, the dynamic parameters and the reservoir property parameters, wherein the reserve use indexes are used for representing reserve use degrees of a reservoir;
wherein determining a reserve utilization index based on the static parameter, the dynamic parameter, and the reservoir property parameter comprises: determining a first component of a reserve use indicator based on the static parameter; determining a second component of the reserve use indicator based on the dynamic parameter; determining a third component of a reserve use indicator from the reservoir property parameter; determining a reserve use indicator from the first component, the second component, and the third component;
the determining static parameters includes: obtaining a maximum likelihood attribute body according to the seismic data; carrying out fracture piece depiction on the maximum likelihood attribute body to obtain fracture piece depiction results as intersecting or non-intersecting; if the intersection gives a score of a first preset value, if the intersection gives a score of a second preset value; performing post-stack reservoir inversion on the seismic data to obtain a post-stack inversion pore body; performing fracture-cavity reservoir characterization on the post-stack inversion pore body to obtain a fracture-cavity reservoir characterization result which is superposition or non-superposition; if the stacking assignment score is a third preset value, if the stacking assignment score is not a fourth preset value; taking the fracture piece painting result and the fracture hole reservoir painting result as static parameters, summing all scores of the static parameters, and taking the summed result as a first component of a reserve utilization index;
The determining the dynamic parameters includes: constructing a fitting function between the engraving volume and the dynamic reserve according to the post-stack inversion pore body and the production dynamic data to obtain a fitting coefficient, if the fitting coefficient is more than or equal to 0.8, giving a score as a fifth preset value, otherwise giving the score as a sixth preset value; obtaining a first curve and a second curve according to the production dynamic data; the first curve is a relation curve between the accumulated pressure drop and the accumulated liquid yield, if the first curve type is a monotonic curve, the score is given as a seventh preset value, otherwise, the score is given as an eighth preset value; the second curve is a well test data curve, the score is given as a ninth preset value if the second curve is of a single fracture-hole type, and the score is given as a tenth preset value if the second curve is of a multi-fracture-hole type; taking a fitting function between the engraved volume and the dynamic reserve, the first curve and the second curve as dynamic parameters, summing all scores of the dynamic parameters, and taking the summation result as a second component of a reserve utilization index;
the determining of reservoir property parameters comprises: determining the difference between the hydrogen sulfide content of the target well and the average hydrogen sulfide content of the stratum, and if the absolute value of the hydrogen sulfide content parameter is smaller than or equal to a first threshold value, giving the score as an eleventh preset value, otherwise, giving the score as a twelfth preset value; determining the difference between the crude oil density of the target well and the stratum average crude oil density as a crude oil density parameter, if the absolute value of the crude oil density parameter is smaller than or equal to a second threshold value, giving a score as a thirteenth preset value, otherwise, giving a score as a fourteenth preset value; determining a difference value between the gas-oil ratio of the target well and the stratum average gas-oil ratio, and if the absolute value of the gas-oil ratio parameter is smaller than or equal to a third threshold value, giving a score as a fifteenth preset value, otherwise, giving the score as a sixteenth preset value; comparing whether the phase type of the target well is the same as the phase type of the stratum; the comparison result is used as a phase type parameter, if the phase type parameters are the same, a seventeenth preset value is given to the score, and otherwise, an eighteenth preset value is given to the score; taking the hydrogen sulfide content parameter, the crude oil density parameter, the gas-oil ratio parameter and the phase state type parameter as reservoir property parameters, summing all scores of the reservoir property parameters, and taking the sum result as a third component of the index for reserve.
5. A computer readable storage medium, having stored thereon computer instructions which, when executed by a processor, implement the steps of the method of any of claims 1 to 3.
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