CN107884841B - It is a kind of for determining the method and system of shale natural gas advantage preservation mode - Google Patents
It is a kind of for determining the method and system of shale natural gas advantage preservation mode Download PDFInfo
- Publication number
- CN107884841B CN107884841B CN201610875569.1A CN201610875569A CN107884841B CN 107884841 B CN107884841 B CN 107884841B CN 201610875569 A CN201610875569 A CN 201610875569A CN 107884841 B CN107884841 B CN 107884841B
- Authority
- CN
- China
- Prior art keywords
- gas
- shale
- porosity
- free
- critical
- 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
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V9/00—Prospecting or detecting by methods not provided for in groups G01V1/00 - G01V8/00
Landscapes
- Physics & Mathematics (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- General Physics & Mathematics (AREA)
- Geophysics (AREA)
- Sampling And Sample Adjustment (AREA)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
Abstract
The invention discloses a kind of for determining the method and system of shale natural gas advantage preservation mode, this method comprises: determining the free absorption Critical porosity such as shale gas reservoir using well-log information；Shale gas reservoir effecive porosity is determined using well-log information；According to etc. free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.The present invention is that shale gas reservoir natural gas advantage preservation mode is provided convenience means, has great practical value in shale gas exploration and development.
Description
Technical field
The invention belongs to unconventional oil and gas exploration and development technical fields, specifically, more particularly to a kind of for determining page
The method and system of rock natural gas advantage preservation mode.
Background technique
Shale gas reservoir natural gas is mainly to dissociate and absorption two states preservation, and wherein natural gas advantage preservation mode is
Determine the key factor of shale gas reservoirs exploration exploiting economy, capability forecasting result and actual change rule.
Currently, shale gas advantage preservation mode is determined by logging mode, it is basic by free, absorption two states day
The quantitative assessment of right Gas content by determining the two ratio, and then determines shale natural gas advantage preservation mode.However, above-mentioned
Each link and committed step that method is related to are complex, lack simple and quick determination shale natural gas advantage preservation side at present
The method of formula.
Summary of the invention
In order to solve the above problem, the method that the present invention provides a kind of for determining shale natural gas advantage preservation mode and
System, for determining shale natural gas advantage preservation mode.
According to an aspect of the invention, there is provided a kind of method for determining shale natural gas advantage preservation mode,
Include:
The free absorption Critical porosity such as shale gas reservoir is determined using well-log information；
Shale gas reservoir effecive porosity is determined using well-log information；
According to etc. free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.
According to one embodiment of present invention, according to etc. free absorption Critical porosity and effecive porosity determine shale day
Right gas advantage preservation mode further comprises:
When etc. free absorption Critical porosity and when equal effecive porosity, shale gas reservoir free gas and adsorbed gas content
It is equal；
When etc. free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. free absorption Critical porosity be greater than effecive porosity when, shale gas reservoir is based on adsorbed gas.
According to one embodiment of present invention, it is free to be expressed as unit volume shale for the free absorption Critical porosity such as described
The sum of critical free gas porosity and adsorbed gas porosity when gas mass content is equal with adsorbed gas mass content.
According to one embodiment of present invention, the adsorbed gas porosity is calculated by following steps:
The reservoir parameter of shale gas reservoir is determined using well-log information；
Log is demarcated using rock core adsorption isotherm experiment, to determine shale gas reservoir isothermal adsorption constant；
Shale gas reservoir adsorbed gas is calculated using the reservoir parameter of shale gas reservoir isothermal adsorption constant and shale gas reservoir
Content；
Shale gas reservoir adsorbed gas content is scaled unit volume shale adsorbed gas mass content；
Adsorbed gas porosity is determined according to unit volume shale adsorbed gas mass content and absorption phase density.
According to one embodiment of present invention, the critical free gas porosity is calculated by following steps:
Determine that shale gas reservoir unit volume shale free gas quality contains under critical condition using equation of state of real gas
Amount；
Unit volume shale free gas mass content is equal with unit volume shale adsorbed gas mass content, face to determine
The critical free gas porosity under the conditions of boundary.
According to another aspect of the present invention, it additionally provides and a kind of is for determine shale natural gas advantage preservation mode
System, comprising:
Etc. free absorption Critical porosity determining module, determine that the free absorption such as shale gas reservoir is critical using well-log information
Porosity；
Effecive porosity determining module determines shale gas reservoir effecive porosity using well-log information；
Natural gas preservation mode determining module, according to etc. free absorption Critical porosity and effecive porosity determine shale day
Right gas advantage preservation mode.
According to one embodiment of present invention, the natural gas preservation mode determining module determines shale in the following manner
Natural gas advantage preservation mode:
When etc. free absorption Critical porosity and when equal effecive porosity, shale gas reservoir free gas and adsorbed gas content
It is equal；
When etc. free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. free absorption Critical porosity be greater than effecive porosity when, shale gas reservoir is based on adsorbed gas.
According to one embodiment of present invention, the free absorption Critical porosity determining module such as described is by unit volume shale
The conduct of the sum of critical free gas porosity and adsorbed gas porosity when free gas mass content is equal with adsorbed gas mass content
The free absorption Critical porosity such as described.
According to one embodiment of present invention, the free absorption Critical porosity determining module such as described further comprises:
Reservoir parameter determination unit determines the reservoir parameter of shale gas reservoir using well-log information；
Isothermal adsorption constant determination unit demarcates log using rock core adsorption isotherm experiment, to determine that shale gas stores up
Layer isothermal adsorption constant；
Adsorbed gas content computing unit utilizes the reservoir parameter meter of shale gas reservoir isothermal adsorption constant and shale gas reservoir
Calculate shale gas reservoir adsorbed gas content；
Shale gas reservoir adsorbed gas content is scaled unit volume shale adsorbed gas by adsorbed gas mass content computing unit
Mass content；
Adsorbed gas porosity calculation unit is determined and is inhaled according to unit volume shale adsorbed gas mass content and absorption phase density
Attached stomata porosity.
According to one embodiment of present invention, the free absorption Critical porosity determining module such as described further comprises:
Critical free gas mass content computing unit determines that shale gas stores up under critical condition using equation of state of real gas
The layer critical free gas mass content of unit volume shale；
Critical free gas porosity calculation unit, by unit volume shale free gas mass content and unit volume shale
Adsorbed gas mass content is equal, to determine the critical free gas porosity under critical condition.
Beneficial effects of the present invention:
The present invention determines the free absorption Critical porosity such as shale gas reservoir using well-log information, and then determines that natural gas is excellent
Gesture preservation mode, required various parameters can be obtained according to well-log information, to determine shale gas reservoir day using well-log information
Right gas advantage preservation mode is provided convenience means, has great practical value in shale gas exploration and development.
Other features and advantages of the present invention will be illustrated in the following description, also, partly becomes from specification
It obtains it is clear that understand through the implementation of the invention.The objectives and other advantages of the invention can be by specification, right
Specifically noted structure is achieved and obtained in claim and attached drawing.
Detailed description of the invention
To describe the technical solutions in the embodiments of the present invention more clearly, required in being described below to embodiment
Attached drawing does simple introduction:
Fig. 1 is method flow diagram according to an embodiment of the invention；
Fig. 2 is shale free gas and adsorbed gas occurrence status schematic diagram；
Fig. 3 is technical step schematic diagram according to an embodiment of the invention；
Fig. 4 is the free absorption Critical porosity such as according to an embodiment of the invention and effecive porosity comparison diagram.
Specific embodiment
Hereinafter, embodiments of the present invention will be described in detail with reference to the accompanying drawings and examples, how to apply to the present invention whereby
Technological means solves technical problem, and the realization process for reaching technical effect can fully understand and implement.It needs to illustrate
As long as not constituting conflict, each feature in each embodiment and each embodiment in the present invention can be combined with each other,
It is within the scope of the present invention to be formed by technical solution.
Shale gas reservoir free gas and the adsorbed gas content that the present invention is determined using well-log information when equal etc. free suction
Attached Critical porosity proposes a kind of for determining the method and system of shale natural gas advantage preservation mode.It is as shown in Figure 1
Method flow diagram according to an embodiment of the invention, below with reference to Fig. 1, the present invention is described in detail.
In the present invention, the free absorption Critical porosity such as shale and natural gas advantage preservation mode are determined with well-log information
Method establish under assumed condition below: (1) natural gas, in shale gas reservoir is methane, and mainly to adsorb and swim
From two states preservation；(2), shale gas reservoir active porosity surface takes up space without water flooding etc. and influences Adsorption Natural Gas
Substance；(3), the quality of natural gas content based on unit volume shale adsorbed gas and free gas both occurrence status it is equal come
The free absorption Critical porosity such as determining.Shale free gas and adsorbed gas occurrence status schematic diagram are illustrated in figure 2, in shale gas
Including free gas and adsorbed gas, the natural gas of both states has different porositys.
As shown in Figure 1, being step S100 first, the free absorption critical pore such as shale gas reservoir is determined using well-log information
Degree.Specifically, the free absorption Critical porosity such as this is expressed as unit volume shale free gas mass content and adsorbed gas quality
When content is equal, the sum of free gas porosity and adsorbed gas porosity.
The technical step implemented etc. free absorption Critical porosity is as shown in figure 3, be that step S101 utilizes survey first
Well data determines shale gas reservoir parameter, and reservoir parameter herein includes: rock density ρb, units/kg/m3；Reservoir pressure P, it is single
Position Pa；Reservoir temperature T, unit K.Log is demarcated using rock core adsorption isotherm experiment followed by step S102, determines shale
Gas reservoir isothermal adsorption parameter.Since core experiment points are limited, after demarcating log with finite data, believe using well logging
It ceases whole well section and solves other parameters.Isothermal adsorption constant herein includes: Lang Gemiaoer volume VL, unit m3/kg；Lang Gemiaoer
Pressure PL, unit Pa；Adsorb phase density ρa, units/kg/m3.Shale adsorbed gas content and its institute are determined followed by step S103
Account for porositySpecifically, the adsorbed gas volume content of shale gas reservoir unit mass shale is scaled unit volume shale
Adsorbed gas mass content and shale adsorbed gas porosity, wherein unit volume shale adsorbed gas mass content can be counted by formula (1)
It obtains:
Wherein, ρg(101.3Kpa,20℃)Indicate natural gas density under standard state.
Shale adsorbed gas porosityIt can be calculated by following formula (2):
Wherein,
GadsIndicate the adsorbed gas volume content of shale gas reservoir unit mass shale, unit m3/kg。GadsFormula can be passed through
(3) Lang Gemiaoer equation utilizes the reservoir pressure of shale gas reservoir, Lang Gemiaoer volume and calculation of pressure shale gas reservoir unit
The adsorbed gas volume content of quality shale.
Followed by step S104, the critical free gas porosity with adsorbed gas content when equal is determinedSpecifically,
Shale gas reservoir unit volume shale free gas mass content under critical condition is determined first with equation of state of real gas
Mfree, it may be assumed that
Wherein, Z(P,T)For the real gas compressibility factor under reservoir temperature T and pressure P-condition, MCH4For mole of natural gas
Quality, the present invention are illustrated by taking methane CH4 as an example.
It is finally the free absorption Critical porosities such as step S105 determinationSpecifically, working as unit volume shale free gas
When mass content is equal with adsorbed gas mass content, it may be assumed that
Mfree=Mads
It can determine that critical free gas porosity has:
By formula (2) and formula (6), determining adsorbed gas porosity and available wait of critical free gas porosity are dissociated respectively
Adsorb Critical porosity size are as follows:
In step s 200, shale gas reservoir effecive porosity φ is determined using well-log informatione.The φeIt can be by well-log information
It is obtained by prior art means.
Finally in step 300, according to etc. free absorption Critical porosity and effecive porosity determine that shale natural gas is excellent
Gesture preservation mode.
Specifically, when etc. free absorption Critical porosity and when equal effecive porosity, i.e. φe=φcWhen, shale gas storage
Layer free gas and adsorbed gas content are equal；
When etc. free absorption Critical porosity be less than effecive porosity when, i.e. φe> φcWhen, shale gas reservoir is with free gas
Based on；
When etc. free absorption Critical porosity be greater than effecive porosity when, i.e. φe< φcWhen, shale gas reservoir is with adsorbed gas
Based on.
The present invention is means of providing convenience in such a way that well-log information determines shale gas reservoir natural gas advantage preservation, institute
The various parameters needed can be obtained according to well-log information.The present invention determines that the free absorption such as shale gas reservoir is faced using well-log information
Boundary's porosity, and then determine natural gas advantage preservation mode, there is great practical value in shale gas exploration and development.
According to another aspect of the present invention, it additionally provides and a kind of is for determine shale natural gas advantage preservation mode
System, the system include etc. free absorption Critical porosity determining module, effecive porosity determining module and natural gas preservation mode
Determining module.Wherein, free absorption Critical porosity determining module is waited to determine the free suction such as shale gas reservoir using well-log information
Attached Critical porosity；Effecive porosity determining module determines shale gas reservoir effecive porosity using well-log information；Natural gas is assigned
Deposit mode determining module according to etc. free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.
According to one embodiment of present invention, which determines shale day in the following manner
Right gas advantage preservation mode: when etc. free absorption Critical porosity and when equal effecive porosity, shale gas reservoir free gas with
Adsorbed gas content is equal；When etc. free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. free absorption Critical porosity be greater than effecive porosity when, shale gas reservoir is based on adsorbed gas.
According to one embodiment of present invention, the free absorption Critical porosity determining module such as this is single by under critical condition
Critical free gas porosity and absorption spiracular slit when position volume shale free gas mass content is equal with adsorbed gas mass content
The free absorption Critical porosities such as the sum of degree conduct.
According to one embodiment of present invention, the free absorption Critical porosity determining module such as this further comprises reservoir ginseng
Number determination unit, isothermal adsorption constant determination unit, adsorbed gas content computing unit, adsorbed gas mass content computing unit and suction
Attached stomata porosity computing unit.Wherein, reservoir parameter determination unit determines the reservoir parameter of shale gas reservoir using well-log information；
Isothermal adsorption constant determination unit demarcates log using rock core adsorption isotherm experiment, to determine shale gas reservoir isothermal adsorption
Constant；Adsorbed gas content computing unit calculates shale using the reservoir parameter of shale gas reservoir isothermal adsorption constant shale gas reservoir
Gas reservoir adsorbed gas content；Shale gas reservoir adsorbed gas content is scaled unit volume page by adsorbed gas mass content computing unit
Rock adsorbed gas mass content；Adsorbed gas porosity calculation unit is mutually close according to unit volume shale adsorbed gas mass content and absorption
It spends and determines adsorbed gas porosity.
According to one embodiment of present invention, it further comprises critical free for waiting free absorption Critical porosity determining module
Makings amount content computing unit and critical free gas porosity calculate unit.Wherein, critical free gas mass content computing unit
Shale gas reservoir unit volume shale free gas mass content under critical condition is determined using equation of state of real gas；Critical trip
From stomata porosity computing unit by unit volume shale free gas mass content and unit volume shale adsorbed gas mass content phase
Deng to determine the critical free gas porosity of unit volume shale under critical condition.
It is evaluated below by way of the well-log information to Sichuan Basin Fuling Prefecture a bite shale gas well, determines that the well etc. is swum
From absorption Critical porosity (the most right 1 PHIC curve of Fig. 4), and with the well effecive porosity logging evaluation result (Fig. 4 most right 1
Road PHIE curve) it compares.Comparing result shows: well 2520m with shallow well section effecive porosity be less than etc. it is free absorption face
Boundary's porosity, reservoir is based on adsorbed gas；2520m with deep-well section effecive porosity be greater than etc. free absorption Critical porosity, storage
Layer is based on free gas.The evaluation result and practical formulation experiment judgement conclusion having the same.
While it is disclosed that embodiment content as above but described only to facilitate understanding the present invention and adopting
Embodiment is not intended to limit the invention.Any those skilled in the art to which this invention pertains are not departing from this
Under the premise of the disclosed spirit and scope of invention, any modification and change can be made in the implementing form and in details,
But scope of patent protection of the invention, still should be subject to the scope of the claims as defined in the appended claims.
Claims (8)
1. a kind of method for determining shale natural gas advantage preservation mode, comprising:
The free absorption Critical porosity such as shale gas reservoir, the free absorption Critical porosity table such as described are determined using well-log information
Be shown as unit volume shale free gas mass content it is equal with adsorbed gas mass content when critical free gas porosity and absorption
The sum of stomata porosity；
Shale gas reservoir effecive porosity is determined using well-log information；
According to etc. free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.
2. the method according to claim 1, wherein according to etc. free absorption Critical porosity and effecive porosity
Determine that shale natural gas advantage preservation mode further comprises:
When etc. free absorption Critical porosity and when equal effecive porosity, shale gas reservoir free gas and adsorbed gas content phase
Deng；
When etc. free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. free absorption Critical porosity be greater than effecive porosity when, shale gas reservoir is based on adsorbed gas.
3. method according to claim 1 or 2, which is characterized in that the adsorbed gas porosity is calculated by following steps
It obtains:
The reservoir parameter of shale gas reservoir is determined using well-log information；
Log is demarcated using rock core adsorption isotherm experiment, to determine shale gas reservoir isothermal adsorption constant；
Shale gas reservoir adsorbed gas content is calculated using the reservoir parameter of shale gas reservoir isothermal adsorption constant and shale gas reservoir；
Shale gas reservoir adsorbed gas content is scaled unit volume shale adsorbed gas mass content；
Adsorbed gas porosity is determined according to unit volume shale adsorbed gas mass content and absorption phase density.
4. according to the method described in claim 3, it is characterized in that, the critical free gas porosity is calculated by following steps
It obtains:
Shale gas reservoir unit volume shale free gas mass content under critical condition is determined using equation of state of real gas；
Unit volume shale free gas mass content is equal to unit volume shale adsorbed gas mass content, to determine critical condition
Under the critical free gas porosity.
5. a kind of system for determining shale natural gas advantage preservation mode, comprising:
Etc. free absorption Critical porosity determining module, the free absorption critical pore such as shale gas reservoir is determined using well-log information
Degree, the free absorption Critical porosity such as described are expressed as unit volume shale free gas mass content and adsorbed gas mass content phase
The sum of critical free gas porosity and adsorbed gas porosity whens equal；
Effecive porosity determining module determines shale gas reservoir effecive porosity using well-log information；
Natural gas preservation mode determining module, according to etc. free absorption Critical porosity and effecive porosity determine shale natural gas
Advantage preservation mode.
6. system according to claim 5, which is characterized in that the natural gas preservation mode determining module passes through with lower section
Formula determines shale natural gas advantage preservation mode:
When etc. free absorption Critical porosity and when equal effecive porosity, shale gas reservoir free gas and adsorbed gas content phase
Deng；
When etc. free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. free absorption Critical porosity be greater than effecive porosity when, shale gas reservoir is based on adsorbed gas.
7. system according to claim 5 or 6, which is characterized in that the free absorption Critical porosity determining module such as described
Further comprise:
Reservoir parameter determination unit determines the reservoir parameter of shale gas reservoir using well-log information；
Isothermal adsorption constant determination unit demarcates log using rock core adsorption isotherm experiment, to determine shale gas reservoir etc.
Warm absorption constant；
Adsorbed gas content computing unit calculates page using the reservoir parameter of shale gas reservoir isothermal adsorption constant and shale gas reservoir
Rock gas reservoir adsorbed gas content；
Shale gas reservoir adsorbed gas content is scaled unit volume shale adsorbed gas quality by adsorbed gas mass content computing unit
Content；
Adsorbed gas porosity calculation unit determines adsorbed gas according to unit volume shale adsorbed gas mass content and absorption phase density
Porosity.
8. system according to claim 7, which is characterized in that the free absorption Critical porosity determining module such as described is into one
Step includes:
Critical free gas mass content computing unit determines shale gas reservoir list under critical condition using equation of state of real gas
The position critical free gas mass content of volume shale；
Critical free gas porosity calculation unit adsorbs unit volume shale free gas mass content and unit volume shale
Gas mass content is equal, to determine the critical free gas porosity under critical condition.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610875569.1A CN107884841B (en) | 2016-09-30 | 2016-09-30 | It is a kind of for determining the method and system of shale natural gas advantage preservation mode |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610875569.1A CN107884841B (en) | 2016-09-30 | 2016-09-30 | It is a kind of for determining the method and system of shale natural gas advantage preservation mode |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CN107884841A CN107884841A (en) | 2018-04-06 |
| CN107884841B true CN107884841B (en) | 2019-06-18 |
Family
ID=61769252
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610875569.1A Active CN107884841B (en) | 2016-09-30 | 2016-09-30 | It is a kind of for determining the method and system of shale natural gas advantage preservation mode |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN107884841B (en) |
Families Citing this family (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN117634900A (en) * | 2023-11-07 | 2024-03-01 | 中国科学院地质与地球物理研究所 | Shale in-situ gas quantity evaluation method and device, computer equipment and storage medium |
Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104392272A (en) * | 2014-10-13 | 2015-03-04 | 成都创源油气技术开发有限公司 | Shale gas reservoir favorable area selection integrated evaluation method |
| CN105134195A (en) * | 2015-09-02 | 2015-12-09 | 中国石油天然气股份有限公司 | Shale gas reservoir quality evaluation method based on logging information |
| CN105822293A (en) * | 2016-03-17 | 2016-08-03 | 成都创源油气技术开发有限公司 | Method for recognizing superior shale gas reservoir by adopting conventional logging information |
| CN105927218A (en) * | 2016-05-20 | 2016-09-07 | 中国石油大学(北京) | Continental facies clay shale reservoir stratum gas content prediction method and device |
Family Cites Families (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US9720124B2 (en) * | 2011-08-10 | 2017-08-01 | Schlumberger Technology Corporation | Logging in gas shale and other unconventional reservoirs |
-
2016
- 2016-09-30 CN CN201610875569.1A patent/CN107884841B/en active Active
Patent Citations (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN104392272A (en) * | 2014-10-13 | 2015-03-04 | 成都创源油气技术开发有限公司 | Shale gas reservoir favorable area selection integrated evaluation method |
| CN105134195A (en) * | 2015-09-02 | 2015-12-09 | 中国石油天然气股份有限公司 | Shale gas reservoir quality evaluation method based on logging information |
| CN105822293A (en) * | 2016-03-17 | 2016-08-03 | 成都创源油气技术开发有限公司 | Method for recognizing superior shale gas reservoir by adopting conventional logging information |
| CN105927218A (en) * | 2016-05-20 | 2016-09-07 | 中国石油大学(北京) | Continental facies clay shale reservoir stratum gas content prediction method and device |
Non-Patent Citations (1)
| Title |
|---|
| "关于页岩含气量确定方法的探讨";董谦 等;《天然气与石油》;20121031;第30卷(第5期);第34-37页 |
Also Published As
| Publication number | Publication date |
|---|---|
| CN107884841A (en) | 2018-04-06 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN110334431B (en) | Single-well control reserve calculation and residual gas analysis method for low-permeability tight gas reservoir | |
| Zolfaghari et al. | Water sorption behaviour of gas shales: I. Role of clays | |
| Leroy et al. | Predicting the surface tension of aqueous 1: 1 electrolyte solutions at high salinity | |
| CN107387068B (en) | Method and system for determining free gas content of shale gas reservoir | |
| Liu et al. | A permeability-change relationship in the dryout zone for CO2 injection into saline aquifers | |
| CN110162808A (en) | A kind of method of determining shale gas well adsorbed gas and free gas throughput contribution | |
| Zhang et al. | A digital twin for unconventional reservoirs: A multiscale modeling and algorithm to investigate complex mechanisms | |
| CN107884841B (en) | It is a kind of for determining the method and system of shale natural gas advantage preservation mode | |
| Li et al. | A new method for production data analysis in shale gas reservoirs | |
| CN110782187B (en) | Method and system for dynamically evaluating depleted oil and gas reservoir type gas storage based on water content | |
| Mei et al. | Fractal analysis of shape factor for matrix-fracture transfer function in fractured reservoirs | |
| Heath et al. | Adsorption and capillary condensation in porous media as a function of the chemical potential of water in carbon dioxide | |
| CN109582923A (en) | A kind of method and processing terminal based on two-parameter calculated hydration object saturation degree | |
| CN111963163B (en) | Shale gas reservoir double-hole and double-permeation model construction and pressure dynamic prediction method based on gas-water two-phase flow | |
| CN111720114B (en) | Well logging saturation calculation method for sandstone hydrocarbon reservoir | |
| CN104181090B (en) | A kind of hydrocarbon saturation evaluation methodology based on rock electricity structural coefficient | |
| Guo et al. | A new model to predict the relative permeability of wetting phase for tight sandstones | |
| Zhou et al. | Comparison of freezing and hydration characteristics for porous media | |
| Reseda et al. | Kajian efektifitas pengendalian banjir di DAS Garang | |
| Gu et al. | Estimation of two-phase relative permeabilities based on treelike fractal model and pressure drop around gas bubbles in porous media | |
| Zhu | Impact of scaling break and fracture orientation on effective permeability of fractal fracture network | |
| Zhou et al. | Occurrence and resource evaluation of the subsurface high-K brines in the Pingluoba brine-bearing structure in western Sichuan Basin | |
| 耿斌 et al. | Correction method of oil saturation in unconsolidated sandstone heavy oil reservoirs: a case study of Guantao Formation in Zhanhua Sag, Jiyang Depression | |
| Lian et al. | Pressure behavior of shale-gas flow in dual porous medium based on fractal theory | |
| Sedaee et al. | A novel method for calculating polymer adsorption in fractures through a dual porosity model |
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 |