CN108008117B - Fracture development mode and reservoir matrix-fracture permeability sensitivity prediction method - Google Patents
Fracture development mode and reservoir matrix-fracture permeability sensitivity prediction method Download PDFInfo
- Publication number
- CN108008117B CN108008117B CN201711389879.3A CN201711389879A CN108008117B CN 108008117 B CN108008117 B CN 108008117B CN 201711389879 A CN201711389879 A CN 201711389879A CN 108008117 B CN108008117 B CN 108008117B
- Authority
- CN
- China
- Prior art keywords
- permeability
- fracture
- crack
- cracks
- matrix
- 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.)
- Expired - Fee Related
Links
Images
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N33/00—Investigating or analysing materials by specific methods not covered by groups G01N1/00 - G01N31/00
- G01N33/24—Earth materials
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/30—Circuit design
- G06F30/36—Circuit design at the analogue level
- G06F30/367—Design verification, e.g. using simulation, simulation program with integrated circuit emphasis [SPICE], direct methods or relaxation methods
Landscapes
- Engineering & Computer Science (AREA)
- Computer Hardware Design (AREA)
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- Theoretical Computer Science (AREA)
- Chemical & Material Sciences (AREA)
- Health & Medical Sciences (AREA)
- General Physics & Mathematics (AREA)
- Geology (AREA)
- Microelectronics & Electronic Packaging (AREA)
- Environmental & Geological Engineering (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geometry (AREA)
- Remote Sensing (AREA)
- Evolutionary Computation (AREA)
- General Engineering & Computer Science (AREA)
- Food Science & Technology (AREA)
- Medicinal Chemistry (AREA)
- Analytical Chemistry (AREA)
- Biochemistry (AREA)
- General Health & Medical Sciences (AREA)
- Immunology (AREA)
- Pathology (AREA)
- Geophysics And Detection Of Objects (AREA)
Abstract
The invention relates to the field of oil and gas field exploration and development, in particular to a method for predicting fracture development mode and reservoir matrix-fracture permeability sensitivity. On the basis of establishing a double-hole double-permeability representation model of the small unit bodies of the fractured reservoir, simulating to obtain hole permeability parameter distribution of the fractures, carrying out fracture multi-parameter simulation through a fine small block geological model, and dividing development modes of the fractures in different regions; establishing a reservoir matrix-fracture permeability sensitivity mathematical model by using the pore permeability parameter distribution of the matrix; and finally, optimizing a reservoir exploration and development block. The method has high practical value for predicting the sensitivity of the multi-fracture development mode and the matrix-fracture permeability of the reservoir stratum, is low in prediction cost and high in operability, and has practical significance for the exploration and development of the fractured reservoir stratum.
Description
Technical Field
The invention relates to the field of oil and gas field exploration and development, in particular to a method for predicting fracture development mode and reservoir matrix-fracture permeability sensitivity.
Background
Along with the continuous progress of oil and gas exploration and development, low-porosity and low-permeability fractured reservoirs are more and more valued by people. Because the problems of over-fast productivity failure and the like often occur in the development process of the reservoirs, in order to reduce the damage of the reservoirs caused by the permeability sensitivity of the matrix and the cracks of the reservoirs as much as possible, it is necessary to establish a development mode of the cracks according to the pore permeation distribution of the cracks and predict the permeability sensitivity of the matrix and the cracks of the reservoirs, and reservoir exploration and development areas are optimized.
In the research of quantitative crack prediction, many scholars focus on the research of the development sequence, development type (distribution), causative mechanism and evolution process of cracks, regarding the research of the crack development mode. In the invention patent, fracture surface densities of different scales are described based on fault-fracture similarity, and opening capacities of the fractures of different scales in the underground are analyzed by means of the existing stress field through establishing a core opening degree partial normal model; quantitative description of multi-stage and multi-scale fracture permeability parameters is realized by establishing a fracture permeability parameter mathematical representation model; according to the development relationship of the opening degree and the density of the crack, the development mode of the crack is divided by referring to the relative numerical values of the porosity and the permeability of the crack, so that the development mode of the crack is closer to the actual demand of exploration and development of the oil field.
Disclosure of Invention
The invention aims to solve the problems and provides a method for predicting a fracture development mode and reservoir matrix-fracture permeability sensitivity, which solves the problems of how to predict the development mode of a fracture based on fracture permeability parameters, evaluate the reservoir matrix-fracture permeability sensitivity and preferably select reservoir exploration and development blocks.
The technical scheme of the invention is as follows: the method for predicting the sensitivity of a fracture development mode and a reservoir matrix-fracture permeability comprises the following specific steps:
firstly, establishing a double-hole double-permeability representation model of a fractured reservoir tiny unit body;
establishing a conceptual model of the distribution of the cracks and the matrixes in the research area by utilizing the distribution of the faults or the cracks; and determining the porosity and permeability range of the matrix in the cell block through well logging interpretation.
New cracks are generally not generated in the current stress field, the linear density, the occurrence shape and the set system characteristics of the cracks basically remain unchanged, but under the influence of three-way extrusion stress, the cracks are closed to a certain extent, and the seepage capability is deteriorated; the formula for calculating the opening of the crack after the transformation of the ground stress field at present:
in the formula (1), b0B is the original, present opening, m, of the crack, respectively; sigma'nEffective positive stress, MPa; bresIs the residual opening of the crack, m; sigmanrefWhen the opening of the crack is reduced by 90%, corresponding effective positive stress is MPa.
For a single statistical unit, the fracture conductivity of different scales is different, the fracture with long extension and large opening degree usually plays a leading role in the conductivity, the fracture conductivity of different scales is evaluated by means of a proper model, and the pore permeability parameter of the fracture is calculated by establishing a micro unit model; porosity calculation model of fracture:
permeability tensor calculation model for fracture:
in the unit body, the permeability K is larger than that of the crack in the maximum permeability direction of the crackmaxExpressed as:
in formulas (2) to (4), R is the side length of a statistical unit, m; rhorminFracture surface density of flake size, m/m2；ρrmaxDensity of fracture line in core size, m/m2(ii) a m is the number of fracture sections, which is the number of crack permeability in the unit body; n isxi、nyiThe components of the unit normal vector of the ith group of fracture surfaces on the coordinate axis of the X, Y axis respectively; calculating porosity by using the fracture surface density of the sheet scale, wherein the parameter reflects the storage and corrosion capacities of the fracture to a certain extent, and the fracture of the sheet scale is the length d of the fracture>10-5m is a crack; calculating the size and the direction of permeability by using the density of the crack line of the core scale, wherein the crack of the core scale is the length d of the crack>0.5m crack; kiParallel permeability value for cracks, 10-3μm2；nxi、nyiThe components of the unit normal vector of the ith group of fracture surfaces on the coordinate axis of the X, Y axis respectively; establishing a static coordinate system O-EENWS by taking the crack as a reference object, establishing a dynamic coordinate system O-XY by taking a geodetic coordinate as a reference object, defining theta as an included angle between an OX axis and the east-ward direction in a horizontal plane, namely a rotation angle of the dynamic coordinate system, and solving the permeability of the crack in different directions in the dynamic coordinate system by adjusting the size of the theta; defining theta as a negative value when the OX axis is positioned in the northeast direction; and when the position is in the southeast direction, theta is a positive value.
Secondly, establishing a crack development mode division model;
carrying out multi-parameter simulation on the cracks by using a fine small block geological model, determining the density, the opening degree, the porosity and the permeability of the cracks by simulating the ancient and modern stress fields, and using the parameters b/rho,
And establishing critical values of the development modes of the low-pore hypotonic type, the high-pore hypertonic type, the low-pore hypertonic type, the high-pore hypotonic type and the intermediate transition type cracks, and establishing the development modes of the cracks in different regions.
Thirdly, establishing a reservoir matrix-fracture permeability sensitivity mathematical model;
determining within a small block using well log interpretationThe porosity and permeability range of the matrix and the permeability of the crack have strong anisotropy, and an evaluation parameter for evaluating the anisotropy of the permeability of the crack, namely a permeability variation coefficient tau, is provided by adjusting the size of thetay。
In formulae (5) to (6), KθiIs theta in a unit bodyiPermeability value in the direction, 10-3μm2(ii) a n is the number of permeability of cracks in different directions in the unit body; krPermeability as a matrix, 10-3μm2；
Average permeability of the cell body in different directions, 10-3μm2；nxi、nyiThe components of the unit normal vector of the ith group of fracture surfaces on the coordinate axis of the X, Y axis respectively; rhormaxFracture surface density of core size, m/m2。
By continuously adjusting the value of theta in the dynamic coordinate system, the heterogeneity of the crack permeability of different regions can be analyzed by using the formula (6). The reservoir influence of the cracks on different matrix permeability is different, the matrix permeability is increased, the heterogeneity of the cracks is reduced, but the change trends of different regions are inconsistent.
Fourthly, optimizing reservoir exploration and development blocks;
and (3) optimizing fracture development mode areas of low pore hyperosmotic property and high pore hyperosmotic property and blocks with weak fracture sensitivity to the matrix as optimized exploration and development areas by utilizing the divided fracture development modes and the reservoir influences of the fractures on different matrix permeabilities.
The invention has the beneficial effects that: the method simulates to obtain the fracture on the basis of establishing a double-hole double-permeability representation model of the small unit body of the fractured reservoirThe pore-permeability parameter distribution is realized by carrying out fracture multi-parameter simulation through a fine small block geological model and utilizing the parameters b/rho,
Establishing critical values of development modes of low-pore hypotonic type, high-pore hypertonic type, low-pore hypertonic type, high-pore hypotonic type and intermediate transition type cracks, and dividing the development modes of cracks in different regions; establishing a reservoir matrix-fracture permeability sensitivity mathematical model by using the pore permeability parameter distribution of the matrix; and finally, optimizing a reservoir exploration and development block. The method has high practical value for predicting the sensitivity of the multi-fracture development mode and the matrix-fracture permeability of the reservoir stratum, is low in prediction cost and high in operability, and has practical significance for the exploration and development of the fractured reservoir stratum.
Drawings
FIG. 1 is a flow chart of a method for predicting fracture development patterns and reservoir matrix-fracture permeability sensitivity.
FIG. 2 is a graph of fracture porosity distribution of the gold lake depressed Fuzhai two-section.
FIG. 3 is the magnitude distribution of the permeability of two-stage fracture of the Venu Funiu in the gold lake.
FIG. 4 is the maximum permeability direction distribution of two cracks of the Venu Fuliang of the gold lake.
FIG. 5 shows the prediction results of crack opening and linear density in Minbridge region.
Fig. 6 shows the prediction results of the crack opening and linear density in the stone bridge region.
FIG. 7 is a graph showing the relationship between crack opening and linear density of day 33 fracture.
FIG. 8 is the relationship between the density and opening of the fracture surface and the development pattern.
FIG. 9 shows the development pattern of cracks in different areas of the pit of gold lake.
FIG. 10 shows the results of the heterogeneity evaluation of the permeability of the fracture of the Jinhuumu second-stage reservoir (matrix permeability 0.1X 10)-3μm2)。
FIG. 11 shows the results of the heterogeneity evaluation of the permeability of the fracture of the Jinhuumu second-stage reservoir (matrix permeability 0.5X 10)-3μm2)。
FIG. 12 shows goldEvaluation result of heterogeneity of permeability of fracture of two-stage reservoir of Funiu lake (matrix permeability is 1.0 multiplied by 10)-3μm2)。
FIG. 13 shows the results of heterogeneity evaluation of permeability of fracture of two-stage reservoir in Jinhu Fufan (matrix permeability 5.0X 10)-3μm2)。
FIG. 14 shows the results of heterogeneity evaluation of permeability of fracture of two reservoir segments of Jinhuumu (matrix permeability 10.0X 10)-3μm2)。
FIG. 15 shows the results of heterogeneity evaluation of permeability of fracture of two-stage reservoir in Jinhu Fufan (matrix permeability 20.0X 10)-3μm2)。
FIG. 16 shows the results of heterogeneity evaluation of permeability of fracture of two-stage reservoir in Jinhu Fufan (matrix permeability 60.0X 10)-3μm2)。
FIG. 17 shows the results of heterogeneity evaluation of permeability of two reservoir fractures in Venus-3μm2)。
FIG. 18 shows the relative heterogeneity of crack permeability in different regions of the gold lake pits.
Detailed Description
The following description of the embodiments of the present invention refers to the accompanying drawings:
the specific technical scheme of the invention is illustrated by taking the second David Funing group of Jinhu lake in the northern Suzhou province (called Fudui for short):
the golden lake depression was primarily subjected to wuberg and three-buttress two-phase tectonic movements since mons second deposition. The main fracture period of the Fulian second stratum in the research region is Wu Bao period, and the fault in the period is strongly active and mainly appears as near-south-north tension, so that a complex fracture system in the depression is formed. The method for predicting the fracture development pattern of the Jinhu sunken Fufan second section and the reservoir matrix-fracture permeability sensitivity by combining regional geological data comprises the following steps:
(1) establishing a double-hole double-permeability characterization model of a small unit body of a two-section fractured reservoir of the sunken Fuyang in the gold lake;
the opening, porosity and permeability distribution of the gold lake depressed mons second section fracture were calculated by using equations (2) to (4) (fig. 2, fig. 3 and fig. 4).
(2) Establishing a golden lake sunken crack development mode division model;
and performing multi-parameter simulation on the cracks by using a fine small block geological model, and determining the density, the opening degree, the porosity and the permeability of the cracks through ancient and modern stress field simulation (figures 5, 6 and 7).
Using the parameters b/p,
And establishing critical values of the development modes of the low-pore hypotonic type, the high-pore hypertonic type, the low-pore hypertonic type, the high-pore hypotonic type and the middle transition type cracks, and dividing the development modes of the cracks in different regions.
The crack multi-parameter simulation is carried out by utilizing a fine geological model, and the result shows that the surface density and the opening development rule of cracks in different areas are different, and the cracks in the Minqiao and Yangjia dam areas have large crack opening and high density; the density of cracks in the rock harbor area is relatively large, and the opening degree is low; the crack density in the river mouth area of the bridge is low, the opening degree is relatively large, and the crack is a typical low-hole high-permeability crack; and the crack parameters in copper cities develop moderately. Therefore, by using the density-opening relation of the cracks of different statistical units in the regions and combining the porosity and permeability distribution of the cracks, a classification standard of crack development modes (table 1) is established, and the gold lake sunken cracks are preliminarily divided into five development modes (fig. 8 and 9): TABLE 1 Classification criteria for different crack development patterns
In table 1, ρ units: m/m2(ii) a b unit: x 10-5m；KmaxUnit: x 10-3μm2；
Unit: x 10-3％。
(1) The porosity and the permeability of the low-porosity low-permeability crack are low values and are mainly distributed on the Yancun, the golden lake and the sunken edge; the sand body has thin thickness, poor plane continuity, high shale content and low brittleness of the rock.
(2) The porosity and the permeability of the high-porosity and high-permeability cracks are high values; the opening and the density of the cracks are high values, and the cracks are areas with high archaic main stress difference and stable distribution; the cracks are mainly distributed in a west slope and Minbridge area, and are buried moderately shallow (1500-2600 m) nowadays; the reservoir mainly comprises low-permeability siltstone and fine sandstone, the rock brittleness is high, the pores of the reservoir matrix develop in the middle, the sand body plane distribution is stable, and the deposition environment is mainly the deposition in the shoreside lake.
(3) The porosity of the low-pore high-permeability crack is a low value, and the permeability is a high value; the opening of the crack is relatively high, the density is low, the crack is a low-value region for releasing the ancient stress during the fracture activity, the crack is mainly large-scale crack, often a few large-opening cracks dominate the permeability and are mainly distributed near the rock harbor fault, the Yancun fault and part of main fractures; the matrix has relatively high porosity, large sand thickness and good lateral continuity, and is mostly deposited on the front edge of the delta and river channel sand.
(4) The porosity of the high-porosity low-permeability type crack is a high value, and the permeability is a low value; the opening of the crack is relatively low, the density is high, the crack is a high-value region for releasing the ancient stress during the fracture activity, the crack is mainly a small-scale crack, is densely developed, has a moderate burial depth (1900 m-2800 m), and is mainly distributed at the intersection of secondary small faults such as an Lvlian beam, Anle North, and the like, the densely developed region, and the turning end of the south part of the fault of Yancun and Shigang; the porosity of the matrix is low, the thickness of a single layer of sand is thin, the lateral continuity is poor, and most of the sand and mud are thin and are deposited in a mutual layer.
(5) The middle transition type cracks are medium in porosity and permeability and are distributed in transition regions from high-porosity low-permeability cracks to low-porosity high-permeability cracks and from low-porosity low-permeability cracks to other types of cracks.
Thirdly, establishing a reservoir matrix-fracture permeability sensitivity mathematical model;
determining the porosity and permeability range of the matrix in the block by using well logging interpretation, wherein the permeability of the crack has strong anisotropy, and providing an evaluation parameter for evaluating the permeability anisotropy of the crack, namely a permeability coefficient of variation tau by adjusting the size of thetay。
By passingThe magnitude of the theta value in the dynamic coordinate system is continuously adjusted, and the heterogeneity of the crack permeability of different regions can be analyzed by using the formula (6) (fig. 10-17). The influence of the cracks on the reservoirs with different matrix permeability is different, the matrix permeability is increased, the heterogeneity of the cracks is reduced, but the change trends of different areas are inconsistent; in areas such as a towset, a minbridge, a spread, a trekke, a stone harbor and the like, even if a reservoir matrix has higher permeability, the influence of cracks on development cannot be ignored; in the north of branch of a river Jian and Anle, if the permeability of the reservoir matrix is more than (10-30) x 10-3μm2The effect of the fractures was weak early in the field development (fig. 18).
Fourthly, optimizing reservoir exploration and development blocks;
and (3) optimizing fracture development mode areas of low pore hyperosmotic property and high pore hyperosmotic property and areas with weak matrix sensitivity by using the divided fracture development modes and the reservoir influences of the fractures on different matrix permeabilities as optimized exploration and development areas.
The present invention has been described above by way of example, but the present invention is not limited to the above-described specific embodiments, and any modification or variation made based on the present invention is within the scope of the present invention as claimed.
Claims (1)
1. The method for predicting the sensitivity of a fracture development mode and a reservoir matrix-fracture permeability comprises the following steps:
firstly, establishing a double-hole double-permeability representation model of a fractured reservoir tiny unit body;
establishing a conceptual model of the distribution of the cracks and the matrixes in the research area by utilizing the distribution of the faults or the cracks; determining the porosity and permeability range of the matrix in the cell block through well logging interpretation; new cracks are generally not generated in the current stress field, the linear density, the occurrence shape and the set system characteristics of the cracks basically remain unchanged, but under the influence of three-way extrusion stress, the cracks are closed to a certain extent, and the seepage capability is deteriorated; the formula for calculating the opening of the crack after the transformation of the ground stress field at present:
in the formula (1), b0B is the original, present opening, m, of the crack, respectively; sigma'nEffective positive stress, MPa; bresIs the residual opening of the crack, m; sigmanrefWhen the opening of the crack is reduced by 90%, corresponding effective positive stress is MPa;
for a single statistical unit, the fracture conductivity of different scales is different, the fracture with long extension and large opening degree usually plays a leading role in the conductivity, the fracture conductivity of different scales is evaluated by means of a proper model, and the pore permeability parameter of the fracture is calculated by establishing a micro unit model; porosity calculation model of fracture:
permeability tensor calculation model for fracture:
in the unit body, the permeability K is larger than that of the crack in the maximum permeability direction of the crackmaxExpressed as:
in formulas (2) to (4), R is the side length of a statistical unit, m; rhorminFracture surface density of flake size, m/m2；ρrmaxDensity of fracture line in core size, m/m2(ii) a m is the number of fracture sections, which is the number of crack permeability in the unit body; n isxi、nyiThe components of the unit normal vector of the ith group of fracture surfaces on the coordinate axis of the X, Y axis respectively; calculating porosity by using the fracture surface density of the sheet scale, wherein the parameter reflects the storage and corrosion capacities of the fracture to a certain extent, and the fracture of the sheet scale is the length d of the fracture>10-5m is a crack; crack line density using core dimensionsCalculating the size and direction of permeability, wherein the crack of the core scale is the length d of the crack>0.5m crack; kiParallel permeability value for cracks, 10-3μm2；nxi、nyiThe components of the unit normal vector of the ith group of fracture surfaces on the coordinate axis of the X, Y axis respectively; establishing a static coordinate system O-EENWS by taking the crack as a reference object, establishing a dynamic coordinate system O-XY by taking a geodetic coordinate as a reference object, defining theta as an included angle between an OX axis and the east-ward direction in a horizontal plane, namely a rotation angle of the dynamic coordinate system, and solving the permeability of the crack in different directions in the dynamic coordinate system by adjusting the size of the theta; defining theta as a negative value when the OX axis is positioned in the northeast direction; when the angle is in the southeast direction, theta is a positive value;
secondly, establishing a crack development mode division model;
carrying out multi-parameter simulation on the cracks by using a fine small block geological model, determining the density, the opening degree, the porosity and the permeability of the cracks by simulating the ancient and modern stress fields, and using the parameters b/rho,
Establishing critical values of development modes of low-pore hypotonic type, high-pore hypertonic type, low-pore hypertonic type, high-pore hypotonic type and intermediate transition type cracks, and establishing development modes of cracks in different regions;
thirdly, establishing a reservoir matrix-fracture permeability sensitivity mathematical model;
determining the porosity and permeability range of the matrix in the block by using well logging interpretation, wherein the permeability of the crack has strong anisotropy, and providing an evaluation parameter for evaluating the permeability anisotropy of the crack, namely a permeability coefficient of variation tau by adjusting the size of thetay；
In the formulae (5) to (6),Kθiis theta in a unit bodyiPermeability value in the direction, 10-3μm2(ii) a n is the number of permeability of cracks in different directions in the unit body; krPermeability as a matrix, 10-3μm2；
Average permeability of the cell body in different directions, 10-3μm2；nxi、nyiThe components of the unit normal vector of the ith group of fracture surfaces on the coordinate axis of the X, Y axis respectively; rhormaxFracture surface density of core size, m/m2；
By continuously adjusting the value of theta in the dynamic coordinate system, the heterogeneity of the crack permeability of different regions can be analyzed by using a formula (6); the influence of the cracks on the reservoirs with different matrix permeability is different, the matrix permeability is increased, the heterogeneity of the cracks is reduced, but the change trends of different areas are inconsistent;
fourthly, optimizing reservoir exploration and development blocks;
and (3) optimizing fracture development mode areas of low pore hyperosmotic property and high pore hyperosmotic property and blocks with weak fracture sensitivity to the matrix as optimized exploration and development areas by utilizing the divided fracture development modes and the reservoir influences of the fractures on different matrix permeabilities.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201711389879.3A CN108008117B (en) | 2017-12-21 | 2017-12-21 | Fracture development mode and reservoir matrix-fracture permeability sensitivity prediction method |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201711389879.3A CN108008117B (en) | 2017-12-21 | 2017-12-21 | Fracture development mode and reservoir matrix-fracture permeability sensitivity prediction method |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN108008117A CN108008117A (en) | 2018-05-08 |
| CN108008117B true CN108008117B (en) | 2020-04-03 |
Family
ID=62060295
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201711389879.3A Expired - Fee Related CN108008117B (en) | 2017-12-21 | 2017-12-21 | Fracture development mode and reservoir matrix-fracture permeability sensitivity prediction method |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN108008117B (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109709301B (en) * | 2018-11-30 | 2021-09-28 | 中国石油天然气股份有限公司 | Method, device and system for determining distribution of fracture pore type tight sandstone reservoir |
| CN109946437B (en) * | 2019-04-15 | 2021-07-23 | 西南石油大学 | Fractured compact reservoir working fluid damage evaluation method considering both base block and fracture system |
| CN109946436B (en) * | 2019-04-15 | 2021-06-29 | 西南石油大学 | Fracture-property dense gas layer working fluid damage evaluation method considering both foundation block and fracture |
| CN112198551A (en) * | 2020-09-12 | 2021-01-08 | 北京恺标技术发展有限公司 | Universal novel method for quantitatively evaluating reservoir fracture strength |
| CN112392476B (en) * | 2020-12-02 | 2022-02-15 | 西南石油大学 | Method for determining hole permeability parameters of low-permeability fracture by using conventional logging data |
Family Cites Families (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| RU2492447C1 (en) * | 2012-03-15 | 2013-09-10 | Федеральное государственное бюджетное учреждение науки Институт проблем нефти и газа РАН | Method to define anisotropy of pore space and position of main axes of permeability tensor of rocks on core |
| CN103257089B (en) * | 2013-04-08 | 2015-06-03 | 中国石油天然气股份有限公司 | Method for measuring permeability of matrix and crack by pressure pulse measuring device |
| CN104500050B (en) * | 2014-10-31 | 2017-03-22 | 中国石油大学(华东) | Fractured reservoir permeability tensor and anisotropy quantitative prediction method |
| CN105260543B (en) * | 2015-10-19 | 2018-06-01 | 中国石油天然气股份有限公司 | Multi-medium oil-gas flow simulation method and device based on double-hole model |
| CN106484958B (en) * | 2016-09-19 | 2019-09-17 | 中国石油大学(华东) | A kind of system of the three-dimensional cracking permeability tensor computation model based on pit shaft gap observation |
-
2017
- 2017-12-21 CN CN201711389879.3A patent/CN108008117B/en not_active Expired - Fee Related
Also Published As
| Publication number | Publication date |
|---|---|
| CN108008117A (en) | 2018-05-08 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN108008117B (en) | Fracture development mode and reservoir matrix-fracture permeability sensitivity prediction method | |
| CN110644980B (en) | Comprehensive classification evaluation method for ultra-low permeability oil reservoir | |
| CN109838230B (en) | Quantitative evaluation method for oil reservoir water flooded layer | |
| CN107917865B (en) | compact sandstone reservoir multi-parameter permeability prediction method | |
| Carlson et al. | Submarine fan environment inferred from turbidite thickness distributions | |
| CN108061699B (en) | Quantitative prediction method for hole permeability parameters of multi-stage and multi-scale cracks | |
| US10724348B2 (en) | Method of exploiting a sedimentary basin comprising hydrocarbons, by modelling the accumulation of terrestrial organic matter | |
| Riveiros et al. | Modern distribution of salt marsh foraminifera and thecamoebians in the Seymour–Belize Inlet Complex, British Columbia, Canada | |
| Wassmer et al. | Contribution of anisotropy of magnetic susceptibility (AMS) to reconstruct flooding characteristics of a 4220 BP tsunami from a thick unconsolidated structureless deposit (Banda Aceh, Sumatra) | |
| CN108227033B (en) | Method and device for predicting porosity of sandstone reservoir and computer storage medium | |
| Hernandez-Marin et al. | The role of faulting on surface deformation patterns from pumping-induced groundwater flow (Las Vegas Valley, USA) | |
| CN110968928B (en) | Low-permeability compact sandstone equivalent three-pore rock physical modeling method and application thereof | |
| CN110188388B (en) | Method for evaluating glutenite reservoir physical property by utilizing nuclear magnetic pressure physical property index | |
| CN113361111B (en) | Partitioning method of low-permeability reservoir characteristic model | |
| Ziegler et al. | Modeling sediment transport dynamics in Thompson Island pool, upper Hudson River | |
| Racasa et al. | Submarine groundwater discharge from non-tidal coastal peatlands along the Baltic Sea | |
| Nugraha et al. | How erosive are submarine landslides? | |
| Cao et al. | Erosion resistance and scouring depth of fine-grained seabed of the Huanghe River estuary, China | |
| Sui et al. | Microscopic stress sensitivity analysis with in situ SEM study and digital core deformation simulation | |
| CN113435075A (en) | Computer method for simulating load response caused by landslide disaster impact on seabed energy pipeline | |
| CN112348330A (en) | Method for determining quantitative classification of altered pyroclastic glutenite reservoir | |
| CN108195669B (en) | Method for correcting and predicting static mechanical parameters of rock under oil reservoir confining pressure condition | |
| Liang et al. | Reservoir characteristics and its comprehensive evaluation of gray relational analysis on the western Sulige gas field, Ordos Basin, China | |
| Wang et al. | Sedimentological Influence on Physical Properties of a Tight Sandstone Reservoir: The Cretaceous Nenjiang Formation, Southern Songliao Basin, Northeast China | |
| CN111287739A (en) | Residual oil distribution prediction method based on formation crude oil viscosity |
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 | ||
| TA01 | Transfer of patent application right | ||
| TA01 | Transfer of patent application right |
Effective date of registration: 20200312 Address after: 266580 Qingdao Changjiang Road, Huangdao District, Shandong, No. 66 Applicant after: China University of Petroleum (East China) Address before: 261319 Xiabao Village, Taibaozhuang Street, Xiashan District, Weifang City, Shandong Province Applicant before: Liu Jingshou |
|
| GR01 | Patent grant | ||
| GR01 | Patent grant | ||
| CF01 | Termination of patent right due to non-payment of annual fee | ||
| CF01 | Termination of patent right due to non-payment of annual fee |
Granted publication date: 20200403 Termination date: 20201221 |