CN107884841A - A kind of method and system for being used to determine shale natural gas advantage preservation mode - Google Patents
A kind of method and system for being used to determine shale natural gas advantage preservation mode Download PDFInfo
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- CN107884841A CN107884841A CN201610875569.1A CN201610875569A CN107884841A CN 107884841 A CN107884841 A CN 107884841A CN 201610875569 A CN201610875569 A CN 201610875569A CN 107884841 A CN107884841 A CN 107884841A
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Abstract
The invention discloses a kind of method and system for being used to determine shale natural gas advantage preservation mode, this method includes：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. it is free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.The present invention provides convenience means for shale gas reservoir natural gas advantage preservation mode, has great practical value in shale gas exploration and development.
Description
Technical field
The invention belongs to unconventionaloil pool exploration and development technical field, and specifically, more particularly to one kind is used to determine page
The method and system of rock natural gas advantage preservation mode.
Background technology
Mainly with free with adsorbing two states preservation, wherein natural gas advantage preservation mode is shale gas reservoir natural gas
Determine shale gas reservoirs exploration exploiting economy, the key factor of capability forecasting result and actual change rule.
At present, 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 both ratios, and then determine shale natural gas advantage preservation mode.It is 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.
The content of the invention
For solve problem above, the invention provides it is a kind of be used for determine shale natural gas advantage preservation mode method 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,
Including：
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. it is free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.
According to one embodiment of present invention, according to etc. it is free absorption Critical porosity and effecive porosity determine shale day
Right gas advantage preservation mode further comprises：
When etc. free absorption Critical porosity and during equal effecive porosity, shale gas reservoir free gas and adsorbed gas content
It is equal；
When etc. it is free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. it is free absorption Critical porosity be more than effecive porosity when, shale gas reservoir is based on adsorbed gas.
According to one embodiment of present invention, the free absorption Critical porosity of the grade is expressed as unit volume shale and dissociated
Critical free gas porosity and adsorbed gas porosity sum 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, to determine to face
The critical free gas porosity under the conditions of boundary.
According to another aspect of the present invention, additionally provide it is a kind of be used for determine shale natural gas advantage preservation mode be
System, including：
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, shale gas reservoir effecive porosity is determined using well-log information；
Natural gas preservation mode determining module, according to etc. it is 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 during equal effecive porosity, shale gas reservoir free gas and adsorbed gas content
It is equal；
When etc. it is free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. it is free absorption Critical porosity be more than effecive porosity when, shale gas reservoir is based on adsorbed gas.
According to one embodiment of present invention, the free Critical porosity determining module of adsorbing of the grade is by unit volume shale
Critical free gas porosity and adsorbed gas porosity sum conduct when free gas mass content is equal with adsorbed gas mass content
The free absorption Critical porosity of grade.
According to one embodiment of present invention, the free absorption Critical porosity determining module of the grade further comprises：
Reservoir parameter determining unit, the reservoir parameter of shale gas reservoir is determined using well-log information；
Isothermal adsorption constant determining unit, log is demarcated using rock core adsorption isotherm experiment, to determine that shale gas stores up
Layer isothermal adsorption constant；
Adsorbed gas content computing unit, utilize shale gas reservoir isothermal adsorption constant and the reservoir parameter meter of shale gas reservoir
Calculate shale gas reservoir adsorbed gas content；
Adsorbed gas mass content computing unit, shale gas reservoir adsorbed gas content is scaled unit volume shale adsorbed gas
Mass content；
Adsorbed gas porosity calculation unit, determine to inhale 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 of the grade further comprises：
Critical free gas mass content computing unit, determine 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 obtain 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
Obtain it is clear that or being understood by implementing the present invention.The purpose of the present invention and other advantages can be by specification, rights
Specifically noted structure is realized and obtained in claim and accompanying drawing.
Brief description of the drawings
Technical scheme in order to illustrate the embodiments of the present invention more clearly, required in being described below to embodiment
Accompanying 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 of grade according to an embodiment of the invention and effecive porosity comparison diagram.
Embodiment
Embodiments of the present invention are described in detail below with reference to drawings and Examples, and how the present invention is applied whereby
Technological means solves technical problem, and the implementation process for reaching technique effect can fully understand and implement according to this.Need to illustrate
As long as not forming conflict, each embodiment in the present invention and each feature in each embodiment can be combined with each other,
The technical scheme formed is within protection scope of the present invention.
Grade free suction of the shale gas reservoir free gas that the present invention is determined using well-log information with adsorbed gas content when equal
A kind of attached Critical porosity, it is proposed that method and system for being used to determine 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 following assumed condition：(1), the 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 stratum water etc. and influences Adsorption Natural Gas
Material；(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 porosities such as determination.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, such free absorption Critical porosity is expressed as unit volume shale free gas mass content and adsorbed gas quality
When content is equal, free gas porosity and adsorbed gas porosity sum.
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.Followed by step S102 using rock core adsorption isotherm experiment demarcation log, shale is determined
Gas reservoir isothermal adsorption parameter.Because core experiment points are limited, after demarcating log with finite data, believe using well logging
Cease whole well section and solve other specification.Isothermal adsorption constant herein includes：Lang Gemiaoer volumes 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)
Obtain：
Wherein, ρg(101.3Kpa,20℃)Represent natural gas density under standard state.
Shale adsorbed gas porosityIt can be calculated by following formula (2)：
Wherein,
GadsRepresent the adsorbed gas volume content of shale gas reservoir unit mass shale, unit m3/kg。GadsFormula can be passed through
(3) Lang Gemiaoer equations, the reservoir pressure of shale gas reservoir, Lang Gemiaoer volumes and calculation of pressure shale gas reservoir unit are utilized
The adsorbed gas volume content of quality shale.
Followed by step S104, it is determined that the critical free gas porosity with adsorbed gas content when equalSpecifically,
Shale gas reservoir unit volume shale free gas mass content under critical condition is determined first with equation of state of real gas
Mfree, i.e.,：
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 illustrate by taking methane CH4 as an example.
It is finally the free absorption Critical porosities such as step S105 determinationsSpecifically, work as unit volume shale free gas
When mass content is equal with adsorbed gas mass content, i.e.,：
Mfree=Mads
It can determine that critical free gas porosity has：
It can be obtained etc. by the adsorbed gas porosity that formula (2) and formula (6) determine respectively and critical free gas porosity free
Adsorbing Critical porosity size is：
In step s 200, shale gas reservoir effecive porosity φ is determined using well-log informatione.The φeCan be by well-log information
Obtained by prior art means.
Finally in step 300, according to etc. it is 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 during equal effecive porosity, i.e. φe=φcWhen, shale gas storage
Layer free gas and adsorbed gas content are equal；
When etc. it is 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. it is free absorption Critical porosity be more than effecive porosity when, i.e. φe＜ φcWhen, shale gas reservoir is with adsorbed gas
Based on.
The present invention is to determine that shale gas reservoir natural gas advantage preservation mode is provided convenience means using well-log information, institute
The various parameters needed can obtain 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 natural gas advantage preservation mode is determined, there is great practical value in shale gas exploration and development.
According to another aspect of the present invention, additionally provide it is a kind of be used for determine shale natural gas advantage preservation mode be
Unite, free absorption Critical porosity determining module, effecive porosity determining module and the natural gas preservation modes such as the system includes
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. it is free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.
According to one embodiment of present invention, the natural gas preservation mode determining module determines shale day in the following manner
Right gas advantage preservation mode：When etc. free absorption Critical porosity and during equal effecive porosity, shale gas reservoir free gas and
Adsorbed gas content is equal；When etc. it is free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. it is free absorption Critical porosity be more than effecive porosity when, shale gas reservoir is based on adsorbed gas.
According to one embodiment of present invention, such free absorption Critical porosity determining module 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
Spend the free absorption Critical porosities such as sum conduct.
According to one embodiment of present invention, such free absorption Critical porosity determining module further comprises that reservoir is joined
Number determining unit, isothermal adsorption constant determining unit, adsorbed gas content computing unit, adsorbed gas mass content computing unit and suction
Attached stomata porosity computing unit.Wherein, reservoir parameter determining unit determines the reservoir parameter of shale gas reservoir using well-log information；
Isothermal adsorption constant determining unit is using rock core adsorption isotherm experiment demarcation log, 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
Degree determines adsorbed gas porosity.
According to one embodiment of present invention, free absorption Critical porosity determining module is waited to further comprise critical free
Makings amount cubage 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.
Evaluated below by way of the well-log information to Sichuan Basin Fuling Prefecture a bite shale gas well, determine that the well etc. is swum
From absorption Critical porosity (the most right 1 PHIC curves of Fig. 4), and with the well effecive porosity logging evaluation result (Fig. 4 most right 1
Road PHIE curves) contrasted.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 more than etc. free absorption Critical porosity, storage
Layer is based on free gas.The evaluation result has identical judgement conclusion with actual formulation experiment.
While it is disclosed that embodiment as above, but described content only to facilitate understand the present invention and adopt
Embodiment, it is not limited to the present invention.Any those skilled in the art to which this invention pertains, this is not being departed from
On 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 the scope of patent protection of the present invention, still should be subject to the scope of the claims as defined in the appended claims.
Claims (10)
1. a kind of method for determining shale natural gas advantage preservation mode, including：
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. it is free absorption Critical porosity and effecive porosity determine shale natural gas advantage preservation mode.
2. according to the method for claim 1, it is characterised in that 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 during equal effecive porosity, shale gas reservoir free gas and adsorbed gas content phase
Deng；
When etc. it is free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. it is free absorption Critical porosity be more than effecive porosity when, shale gas reservoir is based on adsorbed gas.
3. method according to claim 1 or 2, it is characterised in that the free absorption Critical porosity of grade is expressed as list
Critical free gas porosity and absorption spiracular slit when position volume shale free gas mass content is equal with adsorbed gas mass content
Spend sum.
4. according to the method for claim 3, it is characterised in that the adsorbed gas porosity is calculated by following steps
Arrive：
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.
5. according to the method for claim 4, it is characterised in that the critical free gas porosity is calculated by following steps
Obtain：
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.
6. a kind of system for determining shale natural gas advantage preservation mode, including：
Etc. free absorption Critical porosity determining module, the free absorption critical pore such as shale gas reservoir is determined using well-log information
Degree；
Effecive porosity determining module, shale gas reservoir effecive porosity is determined using well-log information；
Natural gas preservation mode determining module, according to etc. it is free absorption Critical porosity and effecive porosity determine shale natural gas
Advantage preservation mode.
7. system according to claim 6, it is characterised 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 during equal effecive porosity, shale gas reservoir free gas and adsorbed gas content phase
Deng；
When etc. it is free absorption Critical porosity be less than effecive porosity when, shale gas reservoir is based on free gas；
When etc. it is free absorption Critical porosity be more than effecive porosity when, shale gas reservoir is based on adsorbed gas.
8. the system according to claim 6 or 7, it is characterised in that the free absorption Critical porosity determining module of grade
By critical free gas porosity and adsorbed gas of the unit volume shale free gas mass content when equal with adsorbed gas mass content
Porosity sum is as the free absorption Critical porosity of the grade.
9. system according to claim 8, it is characterised in that the free absorption Critical porosity determining module of grade enters one
Step includes：
Reservoir parameter determining unit, the reservoir parameter of shale gas reservoir is determined using well-log information；
Isothermal adsorption constant determining unit, log is demarcated using rock core adsorption isotherm experiment, to determine shale gas reservoir etc.
Warm absorption constant；
Adsorbed gas content computing unit, page is calculated using the reservoir parameter of shale gas reservoir isothermal adsorption constant and shale gas reservoir
Rock gas reservoir adsorbed gas content；
Adsorbed gas mass content computing unit, shale gas reservoir adsorbed gas content is scaled unit volume shale adsorbed gas quality
Content；
Adsorbed gas porosity calculation unit, adsorbed gas is determined according to unit volume shale adsorbed gas mass content and absorption phase density
Porosity.
10. system according to claim 9, it is characterised in that the free absorption Critical porosity determining module of grade is entered
One step includes：
Critical free gas mass content computing unit, shale gas reservoir list under critical condition is determined using equation of state of real gas
The position critical free gas mass content of volume shale；
Critical free gas porosity calculation unit, unit volume shale free gas mass content and unit volume shale are adsorbed
Gas mass content is equal, to determine the critical free gas porosity under critical condition.
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| CN107884841B (en) | 2019-06-18 |
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