CN112698401B - Rock physical template construction method, device, equipment and storage medium - Google Patents
Rock physical template construction method, device, equipment and storage medium Download PDFInfo
- Publication number
- CN112698401B CN112698401B CN202011418723.5A CN202011418723A CN112698401B CN 112698401 B CN112698401 B CN 112698401B CN 202011418723 A CN202011418723 A CN 202011418723A CN 112698401 B CN112698401 B CN 112698401B
- Authority
- CN
- China
- Prior art keywords
- reservoir
- rock
- density
- parameter
- fluid
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 239000011435 rock Substances 0.000 title claims abstract description 151
- 238000010276 construction Methods 0.000 title claims abstract description 31
- 239000012530 fluid Substances 0.000 claims abstract description 99
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 84
- 230000035945 sensitivity Effects 0.000 claims abstract description 44
- 239000011148 porous material Substances 0.000 claims abstract description 34
- 238000000034 method Methods 0.000 claims abstract description 28
- 238000011160 research Methods 0.000 claims abstract description 9
- 229920006395 saturated elastomer Polymers 0.000 claims description 52
- 239000011159 matrix material Substances 0.000 claims description 38
- 230000002051 biphasic effect Effects 0.000 claims description 29
- 238000004364 calculation method Methods 0.000 claims description 18
- 230000015654 memory Effects 0.000 claims description 14
- 238000004590 computer program Methods 0.000 claims description 7
- 238000004891 communication Methods 0.000 description 8
- 230000008569 process Effects 0.000 description 8
- 238000011161 development Methods 0.000 description 5
- 230000000694 effects Effects 0.000 description 5
- 230000007246 mechanism Effects 0.000 description 5
- 238000010586 diagram Methods 0.000 description 4
- 230000006870 function Effects 0.000 description 4
- 230000004044 response Effects 0.000 description 4
- 239000004215 Carbon black (E152) Substances 0.000 description 3
- 230000008878 coupling Effects 0.000 description 3
- 238000010168 coupling process Methods 0.000 description 3
- 238000005859 coupling reaction Methods 0.000 description 3
- 229930195733 hydrocarbon Natural products 0.000 description 3
- 230000003287 optical effect Effects 0.000 description 3
- 239000003208 petroleum Substances 0.000 description 3
- 238000004458 analytical method Methods 0.000 description 2
- 230000008859 change Effects 0.000 description 2
- 125000001183 hydrocarbyl group Chemical group 0.000 description 2
- 238000012545 processing Methods 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 238000004422 calculation algorithm Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000001514 detection method Methods 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 230000014759 maintenance of location Effects 0.000 description 1
- 230000009466 transformation Effects 0.000 description 1
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
- G01V1/30—Analysis
- G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
- G01V1/282—Application of seismic models, synthetic seismograms
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/62—Physical property of subsurface
- G01V2210/622—Velocity, density or impedance
- G01V2210/6222—Velocity; travel time
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/62—Physical property of subsurface
- G01V2210/622—Velocity, density or impedance
- G01V2210/6224—Density
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/62—Physical property of subsurface
- G01V2210/624—Reservoir parameters
- G01V2210/6242—Elastic parameters, e.g. Young, Lamé or Poisson
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/62—Physical property of subsurface
- G01V2210/624—Reservoir parameters
- G01V2210/6246—Permeability
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A10/00—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE at coastal zones; at river basins
- Y02A10/40—Controlling or monitoring, e.g. of flood or hurricane; Forecasting, e.g. risk assessment or mapping
Landscapes
- Engineering & Computer Science (AREA)
- Remote Sensing (AREA)
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Acoustics & Sound (AREA)
- Environmental & Geological Engineering (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- General Physics & Mathematics (AREA)
- Geophysics (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
Provided herein are a petrophysical template construction method, apparatus, device and storage medium, wherein the method comprises: according to the physical parameters of the reservoir rock of the research work area and the physical theoretical model of the biphase medium rock, calculating to obtain elastic parameters of the reservoir rock, wherein the elastic parameters of the reservoir rock comprise reservoir longitudinal wave speed, transverse wave speed and density under different porosities and different water saturation conditions; according to the rock reservoir elasticity parameters, constructing and eliminating rock skeleton influence, and reserving a first reservoir sensitivity parameter and a second reservoir sensitivity parameter of pore and pore fluid influence; and constructing a petrophysical template according to the first reservoir sensitive parameter and the second reservoir sensitive parameter.
Description
Technical Field
The present disclosure relates to the field of geophysical prospecting for petroleum, and in particular, to a method, apparatus, device, and storage medium for constructing a petrophysical template.
Background
With the deep development of petroleum exploration and development, the reservoir prediction technology is continuously updated and iterated, and the exploration means are developed into methods such as pre-stack inversion, elastic parameter inversion, high-precision geostatistical inversion and the like from post-stack attribute analysis and post-stack wave impedance inversion. In the petroleum exploration and development process, petrophysical plays an important bridge role, the relation between reservoir physical parameters and earthquake response characteristics is established, the petrophysical templates established based on the petrophysical theoretical model describe the distribution rules of reservoirs with different lithologies, different porosities and water saturation in the petrophysical templates, and theoretical basis is provided for quantitative reservoir prediction. In the prior art, the petrophysical analysis generally carries out quantitative reservoir prediction based on a physical template constructed by a longitudinal wave impedance-longitudinal and transverse wave velocity ratio, the petrophysical theory considers that when the reservoir contains oil and gas, the corresponding longitudinal wave velocity and density can be reduced, and the transverse wave velocity only reflects the rock skeleton property without obvious transformation, so that the oil and gas-containing reservoir has independent distribution areas in the petrophysical template constructed by the longitudinal wave impedance-longitudinal and transverse wave velocity ratio, and the porosity and the water saturation of the reservoir can be effectively distinguished. The reservoir prediction factor constructed by combining the rock physical template based on the longitudinal wave impedance-longitudinal and transverse wave speed ratio and the pre-stack inversion parameter is used for quantitative detection of the oil and gas-containing reservoir, and a good application effect is achieved in the practical application process. Along with the continuous deep exploration, a high-porosity high-hydrocarbon-content high-quality reservoir is gradually discovered by exploration and is converted into a development stage, so that an exploration target is gradually converted into a middle-low-porosity water-containing reservoir, the conventional longitudinal wave impedance-longitudinal and transverse wave speed ratio rock physical template application is greatly limited, the distribution of water-containing and oil-containing reservoirs cannot be effectively distinguished, the phenomenon is generated because the conventional longitudinal wave impedance-longitudinal and transverse wave speed ratio rock physical template has relatively concentrated distribution areas of water-containing sandstone and oil-containing sandstone, and when the porosity is gradually reduced, the difference between the water-containing sandstone and the oil-containing sandstone is less obvious, so that the conventional rock physical template is difficult to effectively distinguish the distribution of the water-containing sandstone and the oil-containing sandstone under the condition of middle-low porosity, and the risk of reservoir prediction is increased.
Disclosure of Invention
The method is used for solving the problem that when the petrophysical template used in the prior art is applied to a middle-low pore water-containing oil layer, the distribution of the water-containing layer and the oil-containing layer cannot be effectively distinguished, so that the risk of reservoir prediction is increased.
To solve the above technical problem, a first aspect of the present disclosure provides a petrophysical template construction method, including:
according to the physical parameters of the reservoir rock of the research work area and the physical theoretical model of the biphase medium rock, calculating to obtain elastic parameters of the reservoir rock, wherein the elastic parameters of the reservoir rock comprise reservoir longitudinal wave speed, transverse wave speed and density under different porosities and different water saturation conditions;
according to the rock reservoir elasticity parameters, constructing and eliminating rock skeleton influence, and reserving a first reservoir sensitivity parameter and a second reservoir sensitivity parameter of pore and pore fluid influence;
and constructing a petrophysical template according to the first reservoir sensitive parameter and the second reservoir sensitive parameter.
In further embodiments herein, the study site reservoir rock physical parameters include: matrix bulk modulus, matrix shear modulus, matrix density, water bulk modulus, oil bulk modulus, water density, oil density, porosity, and water saturation.
In further embodiments herein, calculating the rock reservoir elasticity parameters from the study of the work area reservoir rock physical parameters and the biphasic medium rock physical theory model comprises: the following calculations are performed based on the biphase medium petrophysical theory model:
calculating the skeleton bulk modulus and the skeleton shear modulus according to the matrix bulk modulus, the matrix shear modulus and the porosity;
calculating the bulk modulus of the mixed fluid and the density of the mixed fluid according to the water saturation, the water bulk modulus, the oil bulk modulus, the water density and the oil density;
calculating the rock equivalent bulk modulus of the saturated biphase fluid according to the skeleton bulk modulus, the porosity, the matrix bulk modulus and the mixed fluid bulk modulus;
equating the skeletal shear modulus to the rock equivalent shear modulus of the saturated biphase fluid;
according to the matrix density, the porosity and the mixed fluid density, calculating the rock equivalent density of the saturated biphase fluid;
calculating the reservoir longitudinal wave speed and the transverse wave speed according to the rock equivalent bulk modulus of the saturated biphase fluid, the rock equivalent shear modulus of the saturated biphase fluid and the rock equivalent density of the saturated biphase fluid;
the rock equivalent density of the saturated biphasic fluid is taken as the reservoir density.
In further embodiments herein, calculating the reservoir compressional and shear wave velocities from the rock equivalent bulk modulus of the saturated biphasic fluid, the rock equivalent shear modulus of the saturated biphasic fluid, and the rock equivalent density of the saturated biphasic fluid comprises calculating the reservoir compressional and shear wave velocities using the formula:
wherein v is p For reservoir longitudinal wave velocity, v s For reservoir shear wave velocity, K sat Rock equivalent bulk modulus, μ, for saturated biphase fluid sat Rock equivalent shear modulus, ρ, for saturated biphase fluid sat Is the rock equivalent density of the biphasic fluid.
In a further embodiment herein, constructing a first reservoir sensitivity parameter and a second reservoir sensitivity parameter that reject rock skeletal effects, preserve pore and pore fluid effects, from the rock reservoir elasticity parameters, includes:
determining a first reservoir sensitivity parameter according to the ratio of the reservoir density to the reservoir shear wave speed;
and determining a second reservoir sensitive parameter according to the difference value obtained by multiplying the reservoir longitudinal wave speed and the reservoir transverse wave speed by the density.
In a further embodiment herein, determining the first reservoir sensitivity parameter based on the ratio of reservoir density and shear wave velocity includes calculating the first reservoir sensitivity parameter using the formula:
X＝ρ/v s ；
and determining a second reservoir sensitive parameter according to the difference value of the products of the longitudinal wave speed and the transverse wave speed and the density respectively, wherein the second reservoir sensitive parameter is determined by using the following formula:
where ρ is the reservoir density, v s For reservoir shear wave velocity, v p Is the reservoir longitudinal wave velocity.
In a further embodiment herein, constructing a petrophysical template from the first reservoir sensitivity parameter and the second reservoir sensitivity parameter comprises:
determining values of porosity and water saturation according to the values of the first reservoir sensing parameter and the values of the second reservoir sensing parameter;
setting the first reservoir sensitive parameter as an X axis, setting the second reservoir sensitive parameter as a Y axis, and constructing the petrophysical template according to the values of the first reservoir sensitive parameter, the second reservoir sensitive parameter, the corresponding porosity and the water saturation.
A second aspect herein provides a petrophysical template building apparatus comprising:
the elastic parameter calculation module is used for calculating and obtaining rock reservoir elastic parameters according to the research work area reservoir rock physical parameters and the biphase medium rock physical theoretical model, wherein the rock reservoir elastic parameters comprise reservoir longitudinal wave speed, transverse wave speed and density under the conditions of different porosities and different water saturation;
the sensitive parameter calculation module is used for constructing a first reservoir sensitive parameter and a second reservoir sensitive parameter which are used for eliminating the influence of a rock skeleton and retaining the influence of pores and pore fluid according to the elastic parameter of the rock reservoir;
and the construction module is used for constructing a rock physical template according to the first reservoir sensitive parameter and the second reservoir sensitive parameter.
A third aspect herein provides a computer apparatus comprising a memory, a processor and a computer program stored on the memory and executable on the processor, the processor implementing the petrophysical template construction method of any one of the preceding embodiments when the computer program is executed.
A fourth aspect herein provides a computer readable storage medium storing a computer program for executing a petrophysical template construction method according to any one of the preceding embodiments when executed by a processor.
According to the rock physical template construction method and device, rock Dan Wuli parameters of a reservoir in a work area are researched through combination of a biphase medium rock physical theory model, and elastic parameters of the rock reservoir are obtained through calculation; according to the elastic parameters of the rock reservoirs, constructing and eliminating the influence of the rock skeleton, and reserving the first reservoir sensitive parameters and the second reservoir sensitive parameters of the influences of pores and pore fluids; according to the first reservoir sensitive parameter and the second reservoir sensitive parameter, a petrophysical template is constructed, so that the water-bearing sandstone and the oil-bearing sandstone in the constructed petrophysical template have obvious distribution difference, have strong resolution even under the condition of medium and low porosity, improve the accuracy of reservoir prediction quantitative interpretation, and reduce the exploration risk.
The foregoing and other objects, features and advantages will be apparent from the following more particular description of preferred embodiments, as illustrated in the accompanying drawings.
Drawings
In order to more clearly illustrate the embodiments herein or the technical solutions in the prior art, the drawings that are required in the embodiments or the description of the prior art will be briefly described below, it being obvious that the drawings in the following description are only some embodiments herein and that other drawings may be obtained according to these drawings without inventive effort to a person skilled in the art.
FIG. 1 illustrates a flow chart of a petrophysical template construction method of embodiments herein;
FIG. 2 illustrates a flow chart of elastic parameter calculation of embodiments herein;
FIG. 3 illustrates a flow chart of a sensitive parameter construction process of embodiments herein;
FIG. 4 shows a distribution pattern of a first reservoir sensitivity parameter of embodiments herein;
FIG. 5 shows a distribution pattern of second reservoir sensing parameters of embodiments herein;
FIG. 6 shows a schematic diagram of a petrophysical template of embodiments herein;
FIG. 7 shows a schematic diagram of a petrophysical template of the prior art;
FIG. 8 illustrates a block diagram of a petrophysical template construction apparatus of embodiments herein;
fig. 9 shows a block diagram of a computer device of embodiments herein.
Description of the drawings:
810. an elasticity parameter calculation module;
820. a sensitive parameter calculation module;
830. constructing a module;
902. a computer device;
904. a processor;
906. a memory;
908. a driving mechanism;
910. an input/output module;
912. an input device;
914. an output device;
916. a presentation device;
918. a graphical user interface;
920. a network interface;
922. a communication link;
924. a communication bus.
Detailed Description
The following description of the embodiments of the present disclosure will be made clearly and fully with reference to the accompanying drawings, in which it is evident that the embodiments described are only some, but not all embodiments of the disclosure. All other embodiments, based on the embodiments herein, which a person of ordinary skill in the art would obtain without undue burden, are within the scope of protection herein.
In an embodiment herein, as shown in fig. 1, fig. 1 shows a flowchart of a petrophysical template construction method of the embodiment herein, where the petrophysical template construction method provided in the embodiment may be run on an intelligent terminal, including a smart phone, a tablet computer, a desktop computer, etc., may be a separate application program, an applet embedded in another program, etc., or may also be in a web page form, etc., and the specific implementation manner is not limited herein. The rock physical template used in the prior art is used for solving the problem that when the rock physical template is applied to a middle-low pore water-containing oil layer, the distribution of the water-containing layer and the oil-containing layer cannot be effectively distinguished, so that the risk of reservoir prediction is increased. Specifically, the rock physical template construction method comprises the following steps:
step 110, according to the physical parameters of the reservoir rock of the research work area and the physical theoretical model of the biphase medium rock, calculating to obtain the elastic parameters of the reservoir rock, wherein the elastic parameters of the reservoir rock comprise the longitudinal wave speed, the transverse wave speed and the density of the reservoir rock under the conditions of different porosities and different water saturation;
step 120, constructing and eliminating rock skeleton influence according to rock reservoir elastic parameters, and reserving first reservoir sensitive parameters and second reservoir sensitive parameters of pore and pore fluid influence;
and 130, constructing a petrophysical template according to the first reservoir sensitive parameter and the second reservoir sensitive parameter.
In detail, the research area reservoir is, for example, a sandstone reservoir, but may be another biphasic medium reservoir, which is not limited herein. The physical parameters of the reservoir rock of the study area include matrix bulk modulus, matrix shear modulus, matrix density, water bulk modulus, oil bulk modulus, water density, oil density, porosity and water saturation. The biphasic medium petrophysical theory model is used for calculating the longitudinal wave speed, the transverse wave speed and the density of the reservoir under the conditions of different porosities and different water saturation based on the research of the reservoir rock Dan Wuli parameters of a work area, and the specific implementation process is described in the following examples.
The first reservoir sensitive parameter and the second reservoir sensitive parameter are not specifically limited, and the parameters of which the rock skeleton influence is removed and only the pore and pore fluid influence are reserved can be used as the first reservoir sensitive parameter and the second reservoir sensitive parameter.
The water-bearing sandstone and the oil-bearing sandstone in the petrophysical template constructed based on the first reservoir sensitive parameter and the second reservoir sensitive parameter have obvious distribution difference, and have strong resolution even under the condition of medium and low porosity, so that the accuracy of reservoir prediction quantitative interpretation is improved, and the exploration risk is reduced.
In one embodiment, as shown in fig. 2, the step 110 of calculating the elastic parameters of the rock reservoir according to the physical parameters of the rock of the reservoir of the research work area and the two-phase medium petrophysical theoretical model includes: the following calculations are performed based on the biphase medium petrophysical theory model:
step 210, calculating the skeleton bulk modulus and the skeleton shear modulus according to the matrix bulk modulus, the matrix shear modulus and the porosity;
step 220, calculating the bulk modulus of the mixed fluid and the density of the mixed fluid according to the water saturation, the bulk modulus of the water, the bulk modulus of the oil, the water density and the oil density;
step 230, calculating the rock equivalent bulk modulus of the saturated biphase fluid according to the skeleton bulk modulus, the porosity, the matrix bulk modulus and the mixed fluid bulk modulus;
step 240, equating the skeleton shear modulus to the rock equivalent shear modulus of the saturated biphase fluid;
step 250, calculating the rock equivalent density of the saturated biphase fluid according to the matrix density, the porosity and the mixed fluid density;
step 260, calculating to obtain the reservoir longitudinal wave velocity and the transverse wave velocity according to the rock equivalent bulk modulus of the saturated biphasic fluid, the rock equivalent shear modulus of the saturated biphasic fluid and the rock equivalent density of the saturated biphasic fluid.
In the step 210, calculating the bulk modulus of the skeleton and the shear modulus of the skeleton according to the bulk modulus of the matrix, the shear modulus of the matrix and the porosity comprises calculating the bulk modulus of the skeleton and the shear modulus of the skeleton according to the following formula:
K m ＝K g (1-φ) 4/(1-φ) ,μ m ＝K m μ g /K g ；
wherein K is g Sum mu g Bulk and shear moduli of the matrix, respectively, phi being the porosity, K m Sum mu m The bulk modulus of the backbone and the shear modulus of the backbone, respectively.
In the step 220, the bulk modulus of the mixed fluid and the density of the mixed fluid are calculated according to the water saturation, the bulk modulus of the water, the bulk modulus of the oil, the density of the water and the density of the oil, and the bulk modulus of the mixed fluid and the density of the mixed fluid are calculated by using the following formulas:
ρ f ＝S w ρ w +(1-S w )ρ o ；
wherein S is w To water saturation, K w For the water bulk modulus, K o For the bulk modulus of oil ρ w Is water density ρ o Is of oil density, K f To mix the fluid bulk modulus ρ f Is the mixed fluid density.
In the step 230, the rock equivalent bulk modulus of the saturated biphasic fluid is calculated according to the skeleton bulk modulus, the porosity, the matrix bulk modulus, and the mixed fluid bulk modulus, including the rock equivalent bulk modulus of the saturated biphasic fluid is calculated by using the following formula:
wherein K is m For shelf bulk modulus, K g For bulk modulus of matrix, K f In order to mix the bulk modulus of the fluid,is porosity.
In step 240 above, the equivalent shear modulus of rock, which is equivalent to the shear modulus of a saturated biphase fluid, can be achieved using the following equation:
μ sat ＝μ m ；
wherein mu m Is the shear modulus of the framework.
In the above step 250, calculating the rock equivalent density of the saturated biphasic fluid according to the matrix density, the porosity, and the mixed fluid density, including calculating the rock equivalent density of the saturated biphasic fluid using the following formula:
ρ sat ＝(1-φ)ρ g +φρ f ；
wherein ρ is g For the density of the matrix, the matrix is,is the porosity ρ f Is the mixed fluid density.
In the step 260, the reservoir longitudinal wave velocity and the reservoir transverse wave velocity are calculated according to the rock equivalent bulk modulus of the saturated biphasic fluid, the rock equivalent shear modulus of the saturated biphasic fluid, and the rock equivalent density of the saturated biphasic fluid, which includes calculating the longitudinal wave velocity and the transverse wave velocity by using the following formulas:
wherein v is p For longitudinal wave velocity, v s For transverse wave velocity, K sat Rock equivalent bulk modulus, μ of saturated biphase fluid sat Rock equivalent shear modulus, ρ, for saturated biphase fluid sat Is the rock equivalent density of the biphasic fluid.
In one embodiment, as shown in fig. 3, the step 120 of constructing the first reservoir sensing parameter and the second reservoir sensing parameter for eliminating the rock skeleton influence and retaining the pore and pore fluid influence according to the rock reservoir elasticity parameter includes:
step 121, determining a first reservoir sensitivity parameter according to the ratio of the reservoir shear wave speed to the reservoir density;
step 122, determining a second reservoir sensitivity parameter according to the difference between the reservoir longitudinal wave velocity and the reservoir transverse wave velocity and the density product.
Specifically, the determining the first reservoir sensitivity parameter in step 121 includes calculating the first reservoir sensitivity parameter according to the ratio of the reservoir density to the reservoir shear wave velocity by using the following formula:
Xaρ/v s ；
wherein X is a first reservoir sensitivity parameter, a is a coefficient, ρ is reservoir density, v s Is the reservoir shear wave velocity. Where a may be any number greater than 0, in a preferred embodiment a=1.
Reservoir density ρ reflects the combined response of the rock framework, the rock pore, and the pore fluid; reservoir shear wave velocity v s The response of the rock matrix is reflected and therefore the first reservoir sensitivity parameter, which is formed by dividing the reservoir density by the shear wave velocity, can eliminate the common part of the two, i.e. the rock matrix, leaving only the pores active with the fluid.
Step 122 includes calculating a second sensitivity coefficient according to differences between the reservoir longitudinal wave velocity and the reservoir transverse wave velocity and the density products, respectively, using the following formula:
Y＝v p ρ-bv s ρ；
where ρ is the reservoir density, v s For reservoir shear wave velocity, v p Is the reservoir longitudinal wave velocity and b is the coefficient.
The reservoir longitudinal wave velocity reflects the combined response of the rock framework, the rock pore and the pore fluid as the same as the density, and the longitudinal wave velocity multiplied by the density-b transverse wave velocity multiplied by the density is also used for eliminating the common part of the two, so that the action of the pore and the fluid is reserved.
Preferably, the method comprises the steps of,the reason is as follows: the longitudinal wave velocity versus the transverse wave velocity of the hydrous sandstone is typically +.>In a coordinate system, if the abscissa is the shear wave velocity, the ordinate is the longitudinal wave velocity, when the slope is +.>And when the water-bearing sandstone longitudinal and transverse wave velocities are fitted, a water-bearing baseline can be obtained.
In a specific embodiment, as shown in fig. 4 and fig. 5, fig. 4 and fig. 4 respectively show distribution patterns of the first reservoir sensing parameter and the second reservoir sensing parameter in the embodiments herein, wherein the abscissa of the graph is porosity, the ordinate is water saturation, and the filling color in the graph represents the value of the sensing parameter, wherein the dark color represents the attribute high value, and the bright color represents the attribute low value. As can be seen from fig. 4, the value of the first reservoir sensitivity parameter increases monotonically as the porosity increases from 0 to 0.35, regardless of the change in water saturation; for a particular porosity, the value of the first reservoir sensitivity parameter does not change with changes in water saturation, which means that the first reservoir sensitivity parameter is insensitive to reservoir fluid, i.e. water saturation, and only very sensitive to porosity. As can be seen from fig. 5, as the porosity and water saturation increase, the value of the second reservoir sensitivity parameter increases, indicating that the second reservoir sensitivity parameter is sensitive to both reservoir porosity and water saturation.
In one embodiment herein, constructing a petrophysical template from the first reservoir sensitivity parameter and the second reservoir sensitivity parameter comprises:
determining values of porosity and water saturation according to the values of the first reservoir sensing parameter and the values of the second reservoir sensing parameter;
setting the first reservoir sensitive parameter as an X axis, setting the second reservoir sensitive parameter as a Y axis, and constructing the petrophysical template according to the values of the first reservoir sensitive parameter, the second reservoir sensitive parameter, the corresponding porosity and the water saturation.
In one embodiment, the constructed petrophysical template is shown in fig. 6 based on the calculated first reservoir sensing parameter and the second reservoir sensing parameter, wherein the X-axis is the first reservoir sensing parameter (X), the Y-axis is the second reservoir sensing parameter (Y), the porosity and the water saturation in the petrophysical template are both variable values, the porosity variation range is 0 to 0.35, and the water saturation variation range is 0 to 1. In fig. 6, the vertical solid line is an equal-porosity trend line, the porosities gradually increase from left to right, the porosities are 0,0.05,0.1,0.15,0.2,0.25,0.3,0.35 respectively, the horizontal solid line is an equal-water saturation trend line, the water saturation gradually increases from bottom to top, and the water saturation values are 0.0,0.1,0.2,0.3,0.4,0.5,0.6,0.7,0.8,0.9,1.0 respectively. The filling color in the figure characterizes the numerical value of the hydrocarbon-containing pores, and the calculation formula is HC=ρ (1-S) w ) Where HC is hydrocarbon-bearing pores, high HC values represent high porosity, low water saturation, high quality reservoirs, and low HC values represent dense or aqueous layers. From fig. 6 it can be seen that the high porosity, low water saturation, high quality reservoir is located in the lower right corner region of the new petrophysical template (petrophysical template constructed herein), and the dense layer is located in the upper left partial region of the new petrophysical template, indicating that the new petrophysical template is able to effectively distinguish between hydrocarbon-bearing reservoir, water layer, and dense layer. When the porosity is less than 0.15, the method corresponds to a middle-low porosity reservoir, at the moment, different water saturation trend lines in the new petrophysical template are uniformly distributed and dispersed, and the reservoir fluid property can still be effectively identified, so that the new petrophysical template is higher in reservoir porosity and water saturation sensitivity, the accuracy of quantitative reservoir prediction is improved, and the risk of exploration and development is reduced.
As shown in fig. 7, fig. 7 shows a conventional petrophysical template, the same data as fig. 6 is adopted in the construction process, the abscissa of the figure is the longitudinal wave impedance, and the ordinate is the longitudinal wave velocity ratio, so that the distribution of different water saturation trend lines in the conventional petrophysical template is concentrated, and in particular, for a medium-low porosity reservoir, the different water saturation trend lines are basically overlapped and distributed together, so that the water reservoir and the oil reservoir cannot be effectively identified, and the risk of quantitative prediction of the reservoir is increased.
Based on the same inventive concept, there is also provided herein a petrophysical template construction apparatus as described in the following examples. Since the principle of the rock physical template construction device for solving the problem is similar to that of the rock physical template construction method, the implementation of the rock physical template construction device can refer to the rock physical template construction method, and the repetition is not repeated. The petrophysical template construction device provided in this embodiment includes a plurality of functional modules, which may be implemented by a dedicated or general-purpose chip, or may be implemented by a software program, which is not limited herein.
Specifically, as shown in fig. 8, the petrophysical template constructing apparatus includes:
the elastic parameter calculation module 810 is configured to calculate a rock reservoir elastic parameter according to a study work area reservoir rock physical parameter and a two-phase medium rock physical theory model, where the rock reservoir elastic parameter includes a reservoir longitudinal wave velocity, a reservoir transverse wave velocity, and a reservoir density under different porosities and different water saturation conditions, and the study work area reservoir rock physical parameter includes a matrix bulk modulus, a matrix shear modulus, a matrix density, a water volume modulus, an oil bulk modulus, a water density, an oil density, a porosity, and a water saturation;
the sensitive parameter calculation module 820 constructs a first reservoir sensitive parameter and a second reservoir sensitive parameter which eliminate the influence of the rock skeleton and reserve the influence of pores and pore fluid according to the elastic parameters of the rock reservoir;
a construction module 830 is configured to construct a petrophysical template according to the first reservoir sensitivity parameter and the second reservoir sensitivity parameter.
The rock physical template constructed by the embodiment ensures that the water-bearing sandstone and the oil-bearing sandstone in the constructed rock physical template have obvious distribution difference, have strong resolvable property even under the condition of medium and low porosity, improve the accuracy of reservoir prediction quantitative interpretation and reduce the exploration risk.
In one embodiment herein, the elastic parameter calculation module 810 calculates the elastic parameters of the rock reservoirs based on the physical parameters of the reservoir rock of the research area and the physical theoretical model of the biphasic medium rock, including: the following calculations are performed based on the biphase medium petrophysical theory model:
calculating the skeleton bulk modulus and the skeleton shear modulus according to the matrix bulk modulus, the matrix shear modulus and the porosity;
calculating the bulk modulus of the mixed fluid and the density of the mixed fluid according to the water saturation, the water bulk modulus, the oil bulk modulus, the water density and the oil density;
calculating the rock equivalent bulk modulus of the saturated biphase fluid according to the skeleton bulk modulus, the porosity, the matrix bulk modulus and the mixed fluid bulk modulus;
equating the skeletal shear modulus to the rock equivalent shear modulus of the saturated biphase fluid;
according to the matrix density, the porosity and the mixed fluid density, calculating the rock equivalent density of the saturated biphase fluid;
calculating the reservoir longitudinal wave speed and the transverse wave speed according to the rock equivalent bulk modulus of the saturated biphase fluid, the rock equivalent shear modulus of the saturated biphase fluid and the rock equivalent density of the saturated biphase fluid;
the rock equivalent density of the saturated biphasic fluid is taken as the reservoir density.
The method comprises the steps of calculating the reservoir longitudinal wave speed and the transverse wave speed according to the rock equivalent bulk modulus of the saturated biphase fluid, the rock equivalent shear modulus of the saturated biphase fluid and the rock equivalent density of the saturated biphase fluid, and calculating the reservoir longitudinal wave speed and the reservoir transverse wave speed by utilizing the following formula:
wherein v is p For longitudinal wave velocity, v s For transverse wave velocity, K sat Rock equivalent bulk modulus, μ, for saturated biphase fluid sat Rock equivalent shear mode for saturated biphase fluidQuantity ρ sat Is the rock equivalent density of the biphasic fluid.
In one embodiment herein, the sensitivity parameter calculation module 820 constructs a first reservoir sensitivity parameter and a second reservoir sensitivity parameter that reject rock skeleton effects, preserve pore and pore fluid effects, according to the rock reservoir elasticity parameters, comprising:
determining a first reservoir sensitivity parameter according to the ratio of the reservoir density to the reservoir shear wave speed;
and determining a second reservoir sensitive parameter according to the difference value of the product of the reservoir longitudinal wave speed and the reservoir transverse wave speed and the density.
In one embodiment, determining the first reservoir sensitivity parameter based on the ratio of reservoir density and reservoir shear wave velocity includes calculating the first reservoir sensitivity parameter using the formula:
X＝ρ/v s ；
determining a second reservoir sensitivity parameter from differences in products of reservoir longitudinal wave velocity and reservoir transverse wave velocity, respectively, with reservoir density, including using the formula:
where ρ is the reservoir density, v s For reservoir shear wave velocity, v p Is the reservoir longitudinal wave velocity.
In one embodiment herein, the construction module 830 constructs a petrophysical template from the first reservoir sensitivity parameter and the second reservoir sensitivity parameter, including:
determining values of porosity and water saturation according to the values of the first reservoir sensing parameter and the values of the second reservoir sensing parameter;
setting the first reservoir sensitive parameter as an X axis, setting the second reservoir sensitive parameter as a Y axis, and constructing the petrophysical template according to the values of the first reservoir sensitive parameter, the second reservoir sensitive parameter, the corresponding porosity and the water saturation.
In the middle-low porosity sandstone reservoir prediction, the problem that the resolution capability of a water-bearing sandstone reservoir and an oil-bearing sandstone reservoir is limited is solved quantitatively by a conventional petrophysical template.
In an embodiment herein, a computer device is also provided, as shown in fig. 9, the computer device 902 may include one or more processors 904, such as one or more Central Processing Units (CPUs), each of which may implement one or more hardware threads. The computer device 902 may also include any memory 906 for storing any kind of information, such as code, settings, data, etc. For example, and without limitation, the memory 906 may include any one or more of the following combinations: any type of RAM, any type of ROM, flash memory devices, hard disks, optical disks, etc. More generally, any memory may store information using any technique. Further, any memory may provide volatile or non-volatile retention of information. Further, any memory may represent fixed or removable components of computer device 902. In one case, when the processor 904 executes associated instructions stored in any memory or combination of memories, the computer device 902 can perform any of the operations of the associated instructions. The computer device 902 also includes one or more drive mechanisms 908 for interacting with any memory, such as a hard disk drive mechanism, optical disk drive mechanism, and the like.
The computer device 902 may also include an input/output module 910 (I/O) for receiving various inputs (via input device 912) and for providing various outputs (via output device 914)). One particular output mechanism may include a presentation device 916 and an associated graphical user interface 918 (GUI). In other embodiments, input/output module 910 (I/O), input device 912, and output device 914 may not be included, but merely as a computer device in a network. The computer device 902 may also include one or more network interfaces 920 for exchanging data with other devices via one or more communication links 922. One or more communication buses 924 couple the above-described components together.
The communication link 922 may be implemented in any manner, for example, through a local area network, a wide area network (e.g., the internet), a point-to-point connection, etc., or any combination thereof. Communication link 922 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.
Embodiments herein also provide a computer readable storage medium having stored thereon a computer program which, when executed by a processor, performs the steps of the petrophysical template construction method of any one of the embodiments described above.
Embodiments herein also provide a computer readable instruction, wherein the program therein causes a processor to perform the petrophysical template construction method of any one of the embodiments described above when the processor executes the instruction.
It should be understood that, in the various embodiments herein, the sequence number of each process described above does not mean the sequence of execution, and the execution sequence of each process should be determined by its functions and internal logic, and should not constitute any limitation on the implementation process of the embodiments herein.
It should also be understood that in embodiments herein, the term "and/or" is merely one relationship that describes an associated object, meaning that three relationships may exist. For example, a and/or B may represent: a exists alone, A and B exist together, and B exists alone. In addition, the character "/" herein generally indicates that the front and rear associated objects are an "or" relationship.
Those of ordinary skill in the art will appreciate that the elements and algorithm steps described in connection with the embodiments disclosed herein may be embodied in electronic hardware, in computer software, or in a combination of the two, and that the elements and steps of the examples have been generally described in terms of function in the foregoing description to clearly illustrate the interchangeability of hardware and software. Whether such functionality is implemented as hardware or software depends upon the particular application and design constraints imposed on the solution. Skilled artisans may implement the described functionality in varying ways for each particular application, but such implementation decisions should not be interpreted as causing a departure from the scope of the present disclosure.
It will be clear to those skilled in the art that, for convenience and brevity of description, specific working procedures of the above-described systems, apparatuses and units may refer to corresponding procedures in the foregoing method embodiments, and are not repeated herein.
In the several embodiments provided herein, it should be understood that the disclosed systems, devices, and methods may be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative, e.g., the division of the units is merely a logical function division, and there may be additional divisions when actually implemented, e.g., multiple units or components may be combined or integrated into another system, or some features may be omitted or not performed. In addition, 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 elements, or may be an electrical, mechanical, or other form of connection.
The units described as separate units may or may not be physically separate, and units shown as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the elements may be selected according to actual needs to achieve the objectives of the embodiments herein.
In addition, each functional unit in the embodiments herein may be integrated in one processing unit, or each unit may exist alone physically, or two or more units may be integrated in one unit. The integrated units may be implemented in hardware or in software functional units.
The integrated units, if implemented in the form of software functional units and sold or used as stand-alone products, may be stored in a computer readable storage medium. Based on such understanding, the technical solutions herein are essentially or portions contributing to the prior art, or all or portions of the technical solutions may be embodied in the form of a software product stored in a storage medium, including several instructions to cause a computer device (which may be a personal computer, a server, or a network device, etc.) to perform all or part of the steps of the methods described in the embodiments herein. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a random access Memory (RAM, random Access Memory), a magnetic disk, or an optical disk, or other various media capable of storing program codes.
Specific examples are set forth herein to illustrate the principles and embodiments herein and are merely illustrative of the methods herein and their core ideas; also, as will be apparent to those of ordinary skill in the art in light of the teachings herein, many variations are possible in the specific embodiments and in the scope of use, and nothing in this specification should be construed as a limitation on the invention.
Claims (8)
1. A petrophysical template construction method, comprising:
according to the physical parameters of the reservoir rock of the research work area and the physical theoretical model of the biphase medium rock, calculating to obtain elastic parameters of the reservoir rock, wherein the elastic parameters of the reservoir rock comprise reservoir longitudinal wave speeds, reservoir transverse wave speeds and reservoir densities under different porosities and different water saturation conditions;
according to the rock reservoir elasticity parameters, constructing and eliminating rock skeleton influence, and reserving first reservoir sensitivity parameters and second reservoir sensitivity parameters of pore and pore fluid influence, wherein the method comprises the following steps: determining a first reservoir sensitivity parameter according to the ratio of the reservoir density to the reservoir shear wave speed; determining a second reservoir sensitive parameter according to the difference value obtained by multiplying the reservoir longitudinal wave speed and the reservoir transverse wave speed by the density;
constructing a petrophysical template according to the first reservoir sensitive parameter and the second reservoir sensitive parameter, comprising: determining values of porosity and water saturation according to the values of the first reservoir sensing parameter and the values of the second reservoir sensing parameter; setting the first reservoir sensitive parameter as an X axis, setting the second reservoir sensitive parameter as a Y axis, and constructing the petrophysical template according to the values of the first reservoir sensitive parameter, the second reservoir sensitive parameter, the corresponding porosity and the water saturation.
2. The method of claim 1, wherein the studying the work zone reservoir rock physical parameters comprises: matrix bulk modulus, matrix shear modulus, matrix density, water bulk modulus, oil bulk modulus, water density, oil density, porosity, and water saturation.
3. The method of claim 2, wherein calculating the rock reservoir elasticity parameters based on the study of the work area reservoir rock physical parameters and the biphasic medium rock physical theory model comprises: the following calculations are performed based on the biphase medium petrophysical theory model:
calculating the skeleton bulk modulus and the skeleton shear modulus according to the matrix bulk modulus, the matrix shear modulus and the porosity;
calculating the bulk modulus of the mixed fluid and the density of the mixed fluid according to the water saturation, the bulk modulus of the water, the bulk modulus of the oil, the water density and the oil density;
calculating the rock equivalent bulk modulus of the saturated biphase fluid according to the skeleton bulk modulus, the porosity, the matrix bulk modulus and the mixed fluid bulk modulus;
equating the skeletal shear modulus to the rock equivalent shear modulus of a saturated biphasic fluid;
calculating the rock equivalent density of the saturated biphase fluid according to the matrix density, the porosity and the mixed fluid density;
calculating the longitudinal wave speed and the transverse wave speed of the reservoir according to the rock equivalent bulk modulus of the saturated biphase fluid, the rock equivalent shear modulus of the saturated biphase fluid and the rock equivalent density of the saturated biphase fluid;
the rock equivalent density of the saturated biphasic fluid is taken as the reservoir density.
4. The method of claim 3, wherein calculating the reservoir compressional and shear wave velocities from the rock equivalent bulk modulus of the saturated biphasic fluid, the rock equivalent shear modulus of the saturated biphasic fluid, and the rock equivalent density of the saturated biphasic fluid comprises calculating the reservoir compressional and shear wave velocities using the formula:
wherein v is p For reservoir longitudinal wave velocity, v s For reservoir shear wave velocity, K sat Mu, the rock equivalent bulk modulus of the saturated biphasic fluid sat Rock equivalent shear modulus, ρ, for the saturated biphase fluid sat Is the rock equivalent density of the bi-phase fluid.
5. The method of claim 4, wherein determining the first reservoir sensitivity parameter based on the ratio of reservoir density and reservoir shear wave velocity comprises calculating the first reservoir sensitivity parameter using the formula:
X＝ρ/v s ；
determining a second reservoir sensitive parameter according to the difference value obtained by multiplying the reservoir longitudinal wave speed and the reservoir transverse wave speed by the reservoir density, wherein the method comprises the following steps of calculating the second reservoir sensitive parameter by utilizing the following formula:
where ρ is the reservoir density, v s For reservoir shear wave velocity, v p Is the reservoir longitudinal wave velocity.
6. A petrophysical template construction apparatus, comprising:
the elastic parameter calculation module is used for calculating and obtaining rock reservoir elastic parameters according to the study work area reservoir rock physical parameters and the biphase medium rock physical theoretical model, wherein the rock reservoir elastic parameters comprise reservoir longitudinal wave speeds, reservoir transverse wave speeds and reservoir densities under different porosities and different water saturation conditions;
the sensitive parameter calculation module constructs and eliminates the rock skeleton influence according to the rock reservoir elastic parameter, and reserves the first reservoir sensitive parameter and the second reservoir sensitive parameter of pore and pore fluid influence, and the sensitive parameter calculation module comprises: determining a first reservoir sensitivity parameter according to the ratio of the reservoir density to the reservoir shear wave speed; determining a second reservoir sensitive parameter according to the difference value obtained by multiplying the reservoir longitudinal wave speed and the reservoir transverse wave speed by the density;
the construction module is used for constructing a petrophysical template according to the first reservoir sensitive parameter and the second reservoir sensitive parameter, and the construction of the petrophysical template comprises the following steps: determining values of porosity and water saturation according to the values of the first reservoir sensing parameter and the values of the second reservoir sensing parameter; setting the first reservoir sensitive parameter as an X axis, setting the second reservoir sensitive parameter as a Y axis, and constructing the petrophysical template according to the values of the first reservoir sensitive parameter, the second reservoir sensitive parameter, the corresponding porosity and the water saturation.
7. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the processor implements the petrophysical template construction method of any one of claims 1 to 5 when the computer program is executed.
8. A computer readable storage medium, characterized in that the computer readable storage medium stores an executing computer program, which when executed by a processor implements the petrophysical template construction method of any one of claims 1 to 5.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011418723.5A CN112698401B (en) | 2020-12-07 | 2020-12-07 | Rock physical template construction method, device, equipment and storage medium |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN202011418723.5A CN112698401B (en) | 2020-12-07 | 2020-12-07 | Rock physical template construction method, device, equipment and storage medium |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN112698401A CN112698401A (en) | 2021-04-23 |
| CN112698401B true CN112698401B (en) | 2024-03-01 |
Family
ID=75506307
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN202011418723.5A Active CN112698401B (en) | 2020-12-07 | 2020-12-07 | Rock physical template construction method, device, equipment and storage medium |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN112698401B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN115201910B (en) * | 2022-07-07 | 2023-05-26 | 中国石油化工股份有限公司 | Rock physical dynamic template establishment method, system, storage medium and equipment |
Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109115987A (en) * | 2018-07-20 | 2019-01-01 | 中国石油天然气股份有限公司 | A kind of evaluation method and device of the fluid factor based on petrophysical model |
| CN111381292A (en) * | 2019-07-31 | 2020-07-07 | 中国石油天然气股份有限公司 | Logging interpretation method and device for predicting sandstone hydrocarbon-bearing reservoir |
-
2020
- 2020-12-07 CN CN202011418723.5A patent/CN112698401B/en active Active
Patent Citations (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109115987A (en) * | 2018-07-20 | 2019-01-01 | 中国石油天然气股份有限公司 | A kind of evaluation method and device of the fluid factor based on petrophysical model |
| CN111381292A (en) * | 2019-07-31 | 2020-07-07 | 中国石油天然气股份有限公司 | Logging interpretation method and device for predicting sandstone hydrocarbon-bearing reservoir |
Non-Patent Citations (4)
| Title |
|---|
| "A STUDY ON THE ROCK PHYSICS MODEL OF GAS RESERVOIR IN TIGHT SANDSTONE";WANG Da-Xing;《CHINESE JOURNAL OF GEOPHYSICS》;第60卷(第1期);第64-83页 * |
| "双相介质储层参数反演";何剑;中国优秀硕士学位论文全文数据库 基础科技辑》(第2期);第A011-819页 * |
| 基于叠前反演的流体敏感属性实验研究及应用;周水生;宜伟;郝召兵;黄为清;伍向阳;;地球物理学报(06);第1985-1992页 * |
| 敏感参数分析在叠前反演流体识别中的应用;黄捍东;汪佳蓓;郭飞;;物探与化探(06);第55-60页 * |
Also Published As
| Publication number | Publication date |
|---|---|
| CN112698401A (en) | 2021-04-23 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| Mohaghegh et al. | Permeability determination from well log data | |
| Balan et al. | State-of-the-art in permeability determination from well log data: Part 1-A comparative study, model development | |
| White et al. | Identifying and estimating significant geologic parameters with experimental design | |
| Williams et al. | The stratigraphie method: a structured approach to history-matching complex simulation models | |
| Dixit et al. | A pore-level investigation of relative permeability hysteresis in water-wet systems | |
| Gamal et al. | Predicting the rock sonic logs while drilling by random forest and decision tree-based algorithms | |
| AU2013402201A1 (en) | In-situ wellbore, core and cuttings information system | |
| CN112698401B (en) | Rock physical template construction method, device, equipment and storage medium | |
| CN110593857B (en) | Method for identifying oil-wetted compact sandstone nuclear magnetic resonance logging fluid and plate thereof | |
| Correia et al. | Multiscale integration for Karst-reservoir flow-simulation models | |
| Nakashima et al. | Accurate representation of near-well effects in coarse-scale models of primary oil production | |
| Hurst et al. | Sand-rich fairways in deep-water clastic reservoirs: genetic units, capturing uncertainty, and a new approach to reservoir modeling | |
| Kaczmaryk et al. | Interference pumping tests in a fractured limestone (Poitiers–France): Inversion of data by means of dual-medium approaches | |
| Ringrose et al. | Use of geology in the interpretation of core-scale relative permeability data | |
| CN112684503A (en) | Reservoir fluid identification method and device based on post-stack seismic attributes | |
| Nakashima et al. | Near-well upscaling for three-phase flows | |
| US20130262070A1 (en) | System and method for subsurface reservoir characterization | |
| CN111381279B (en) | Reservoir porosity quantitative prediction method and device | |
| Rodríguez | Tracer-test interpretation in naturally fractured reservoirs | |
| Brun et al. | Use of prior information in gradient-based history-matching | |
| Larsen et al. | Water Saturation Modeling Challenges in Oil-Down-to Wells: An Example from a Multidarcy North Sea Reservoir | |
| CN107816349A (en) | A kind of method for analyzing tight sand pore structure state | |
| Bahar et al. | Methodology to incorporate geological knowledge in variogram modeling | |
| Thomas et al. | Effect of scaleup and aggregation on the use of well tests to identify geological properties | |
| NO20210279A1 (en) | Distributed Sequencial Gaussian Simulation |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PB01 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| GR01 | Patent grant | ||
| GR01 | Patent grant |