CN108254289A - A kind of method and device of determining shale air content - Google Patents

A kind of method and device of determining shale air content Download PDF

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Publication number
CN108254289A
CN108254289A CN201711365218.7A CN201711365218A CN108254289A CN 108254289 A CN108254289 A CN 108254289A CN 201711365218 A CN201711365218 A CN 201711365218A CN 108254289 A CN108254289 A CN 108254289A
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natural gas
desorption
core sample
shale
shale core
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CN201711365218.7A
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CN108254289B (en
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侯连华
罗霞
林森虎
王京红
韩文学
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China Petroleum and Natural Gas Co Ltd
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China Petroleum and Natural Gas Co Ltd
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
    • G01N7/00—Analysing materials by measuring the pressure or volume of a gas or vapour
    • G01N7/14—Analysing materials by measuring the pressure or volume of a gas or vapour by allowing the material to emit a gas or vapour, e.g. water vapour, and measuring a pressure or volume difference

Abstract

The embodiment of the present application discloses a kind of method and device of determining shale air content；The method includes：First shale core sample is put into the first closed desorption device equipped with drilling fluid, natural gas desorption process of the second shale core sample of simulation in upper carry, to establish the correlation model of natural gas desorption rate and pressure differential；When pressure reduction to the default geostatic pressure in the first closed desorption device, pressure and temperature in first closed desorption device is kept at default geostatic pressure and formation temperature, the second shale core sample is simulated in the upper natural gas desorption process carried to well head, to establish the correlation model of natural gas desorption rate and desorption time；Correlation model and the correlation model of natural gas desorption rate and desorption time based on natural gas desorption rate and pressure differential determine the free tolerance of the second shale core sample；The shale air content of interval of interest where determining the second shale core sample.The accuracy of shale air content determined by can improving.

Description

A kind of method and device of determining shale air content
Technical field
This application involves petroleum natural gas exploration technical field, more particularly to a kind of method of determining shale air content And device.
Background technology
Shale oil gas has become the key areas for oil-gas exploration and development, and storage yield increases rapidly, from current shale oil gas From the point of view of exploration and development situation, still there are the well production of about 40 percentages (%) and estimation ultimate recovery (Estimated Ultimate Recovery, EUR) business development standard is not achieved.Influence shale oil gas whether can commercialize because Element is more, and wherein shale air content is to determine whether shale oil gas has one of an important factor for business development value, to shale The correct evaluation of air content is the key that evaluation and prediction shale oil gas business development " dessert area ".
The main process of the method for general measure shale air content is that the shale core of acquisition is put into desorption device at present, The gas desorption quantity in shale core is obtained, and tarpped gas volume is obtained after the shale core after the completion of desorption is crushed, according to shale Desorption quantity of the rock core in desorption device with desorption time relationship, by mineral office of the United States Federal direct method (USBM direct methods), The methods of improved direct method, Smith-williams' method and curve-fitting method, calculates shale core before desorption device is put into Tolerance is lost, but insufficient using the accuracy of the loss tolerance of shale core that these methods obtain, and then lead to the page obtained The accuracy of rock air content is relatively low, is usually only equivalent to the lower limit of practical shale air content.
In view of the above-mentioned problems, currently no effective solution has been proposed.
Invention content
The purpose of the embodiment of the present application is to provide a kind of method and device of determining shale air content, with determined by raising The accuracy of shale air content.
In order to solve the above technical problems, it is this that the embodiment of the present application, which provides a kind of method and device of determining shale air content, What sample was realized：
A kind of method of determining shale air content, is provided with the first shale core sample and the second shale core sample, with And formation temperature and ground where boring the first shale core sample described in when opening the first shale core sample at depth of stratum Stressor layer；Wherein, the first shale core sample is acquired by the method for pressurize coring, and the second shale core sample leads to Cross the method acquisition of conventional coring；The method includes：
The first shale core sample is put into the first closed desorption device equipped with drilling fluid, simulates the second page Natural gas desorption process of the rock core sample in upper carry, to establish the correlation model of natural gas desorption rate and pressure differential；Its In, the pressure differential subtracts the pressure in the described first closed desorption device according to the strata pressure and determines；
When pressure reduction to the default geostatic pressure in the described first closed desorption device, by the described first closed desorption device Interior pressure and temperature is kept at the default geostatic pressure and the formation temperature, simulates the second shale core sample Product are in the upper natural gas desorption process carried to well head, to establish the correlation model of natural gas desorption rate and desorption time；
When correlation model and the natural gas desorption rate based on the natural gas desorption rate and pressure differential are with desorption Between correlation model, determine the free tolerance of the second shale core sample；
Based on the free tolerance of the second shale core sample, target zone where the second shale core sample is determined The shale air content of section.
It is described that the first shale core sample is put into the first closed desorption device equipped with drilling fluid in preferred embodiment In, natural gas desorption process of the second shale core sample in upper carry is simulated, to establish natural gas desorption rate and pressure The correlation model of force difference, including：
It is above carried after the first shale core sample to well head, the first shale core sample is taken from coring tube Go out, and be put into the first closed desorption device equipped with drilling fluid；Wherein, the temperature and pressure in the described first closed desorption device point It Wei not the formation temperature and the strata pressure；
Described first closed desorption device is maintained at the temperature constant state that temperature is the formation temperature, is dropped according to specified pressure Low rate by the pressure in the described first closed desorption device from the drop in formation pressure to default geostatic pressure, and obtain in institute State the corresponding first natural gas desorption speed of the first shale core sample during the pressure reduction in the first closed desorption device Rate data；Wherein, the first natural gas desorption rate data include multiple first data points, and first data point includes： Pressure differential and the first natural gas desorption rate；The pressure differential is corresponded with the first natural gas desorption rate；The finger Constant-pressure, which reduces drilling well head of liquid of the rate representation during rock core above carries where coring tube at depth of stratum, reduces rate；
Based on the first natural gas desorption rate data, that establishes the natural gas desorption rate and pressure differential is associated with mould Type；Wherein, the natural gas desorption rate and the correlation model of pressure differential include the first incidence coefficient.
In preferred embodiment, the natural gas desorption rate and the correlation model of pressure differential are established using following formula：
Q1=a11ΔP2
Wherein, Q1Represent the first natural gas desorption rate, Δ P represents the pressure differential, a11Represent that described first closes Contact number；Wherein, when Δ P is less than or equal to 0, Q1Value be 0.
In preferred embodiment, simulation the second shale core sample is drawn through in the upper natural gas solution carried to well head Journey, to establish the correlation model of natural gas desorption rate and desorption time, including：
Obtain the corresponding second natural gas desorption rate data of the first shale core sample described in assignment procedure；Its In, the assignment procedure represents that the natural gas desorption rate of the first shale core sample is increased with desorption time increase Process；The second natural gas desorption rate data include multiple second data points, and second data point includes：Desorption time With the second natural gas desorption rate；The desorption time is corresponded with the second natural gas desorption rate；
Based on the second natural gas desorption rate data, being associated with for the natural gas desorption rate and desorption time is established Model；Wherein, the natural gas desorption rate includes the second incidence coefficient with the correlation model of desorption time and third is associated with system Number.
In preferred embodiment, the correlation model of the natural gas desorption rate and desorption time is established using following formula：
Wherein, Q2Represent the second natural gas desorption rate, t2Represent the desorption time, a21And a22Institute is represented respectively State the second incidence coefficient and the third incidence coefficient.
In preferred embodiment, the correlation model based on the natural gas desorption rate and pressure differential and the natural gas solution The correlation model of rate and desorption time is inhaled, determines the free tolerance of the second shale core sample, including：
It is above carried after the second shale core sample to well head, the second shale core sample is taken from coring tube Go out, and be put into the second closed desorption device equipped with drilling fluid；Wherein, the temperature and pressure in the described second closed desorption device point It Wei not the formation temperature and the default strata pressure；And the corresponding natural gas desorption of the specified desorption time of acquisition two Natural gas desorption in the desorption process of rate and the second shale core sample in the described second closed desorption device Amount；
During according to the specified corresponding natural gas desorption rate of desorption time and the natural gas desorption rate with desorption Between correlation model, determine the second shale core sample from well head to the natural gas being put into during the second closed desorption device Loss amount；
Correlation model based on the natural gas desorption rate and pressure differential determines the second shale core sample from brill After opening to it is upper in advance during natural gas loss amount and the second shale core sample it is natural during upper carry Gas loss amount；
Based on the second shale core sample from bore open after to it is upper in advance during natural gas loss amount, described the Natural gas loss amount of the two shale core samples during upper carry, the second shale core sample are from well head to being put into second Natural gas loss amount and the second shale core sample during closed desorption device is in the described second closed desorption device Desorption process in natural gas desorption quantity, determine the free tolerance of the second shale core sample.
It is described according to the specified corresponding natural gas desorption rate of desorption time and the natural gas solution in preferred embodiment The correlation model of rate and desorption time is inhaled, determines the second shale core sample from well head to being put into the second closed desorption device Natural gas loss amount in the process, including：
During according to the specified corresponding natural gas desorption rate of desorption time and the natural gas desorption rate with desorption Between correlation model, determine corresponding second incidence coefficient of the second shale core sample and third incidence coefficient；
According to corresponding second incidence coefficient of the second shale core sample and third incidence coefficient and described natural The correlation model of gas desorption rate and desorption time, establish the corresponding natural gas desorption rate of the second shale core sample with The incidence relation of desorption time；
Incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and desorption time determines The second shale core sample is from well head to the natural gas loss amount being put into during the second closed desorption device.
In preferred embodiment, the correlation model based on the natural gas desorption rate and pressure differential determines described second Shale core sample from bore open after to it is upper in advance during natural gas loss amount and the second shale core sample exist Natural gas loss amount during above carrying, including：
According to the corresponding natural gas desorption rate of the second shale core sample and the incidence relation of desorption time, determine Natural gas desorption rate when the second shale core sample is above carried to well head；
Natural gas desorption rate and brill when above being carried to well head according to the second shale core sample open described second Strata pressure, the default geostatic pressure where second shale core sample described in during shale core sample at depth of stratum, Determine corresponding first incidence coefficient of the second shale core sample；
According to corresponding first incidence coefficient of the second shale core sample and the natural gas desorption rate and pressure The correlation model of force difference establishes being associated with for the corresponding natural gas desorption rate of the second shale core sample and pressure differential System；
Incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and pressure differential, determines institute State the second shale core sample from bore open after to it is upper in advance during natural gas loss amount and second shale core Natural gas loss amount of the sample during upper carry.
In preferred embodiment, the method is also provided with the quality of the second shale core sample；Wherein, the second page Quality after the drilling fluid and water on the second shale core sample surface after the completion of the quality representation removal desorption of rock core sample； The free tolerance based on the second shale core sample, interval of interest where determining the second shale core sample Shale air content, including：
The second shale core sample after the completion of desorption is put into the closed grinder for filling water, the desorption is completed The second shale core sample afterwards crushes processing, obtains the tarpped gas volume of the second shale core sample；
Free tolerance and tarpped gas volume and the second shale core sample based on the second shale core sample Quality, the shale air content of interval of interest where determining the second shale core sample.
A kind of device of determining shale air content, described device provide the first shale core sample and the second shale core sample Formation temperature described in when product and brill open the first shale core sample where the first shale core sample at depth of stratum And strata pressure；Wherein, the first shale core sample is acquired by the method for pressurize coring, the second shale core sample Product are acquired by the method for conventional coring；Described device includes：First correlation model determining module, the second correlation model determine mould Block, free tolerance determining module and shale air content determining module；Wherein,
The first correlation model determining module, for the first shale core sample to be put into equipped with drilling fluid In one closed desorption device, natural gas desorption process of the second shale core sample in upper carry is simulated, to establish natural gas The correlation model of desorption rate and pressure differential；Wherein, the pressure differential subtracts the described first closed solution according to the strata pressure Pressure in haustorium determines；
The second correlation model determining module, for working as the pressure reduction in the described first closed desorption device to default During surface pressure, the pressure and temperature in the described first closed desorption device is kept at the default geostatic pressure and described Layer temperature simulates the second shale core sample in the upper natural gas desorption process carried to well head, to establish natural gas solution Inhale the correlation model of rate and desorption time；
The free tolerance determining module, for the correlation model based on the natural gas desorption rate and pressure differential and institute The correlation model of natural gas desorption rate and desorption time is stated, determines the free tolerance of the second shale core sample；
The shale air content determining module for the free tolerance based on the second shale core sample, determines institute The shale air content of interval of interest where stating the second shale core sample.
In preferred embodiment, the first correlation model determining module includes：First desorption rate data acquisition module and One model building module；Wherein,
The first desorption rate data acquisition module, for above being carried after the first shale core sample to well head, The first shale core sample from coring tube is taken out, and is put into the first closed desorption device equipped with drilling fluid；Wherein, Temperature and pressure in the first closed desorption device is respectively the formation temperature and the strata pressure；And by described first Closed desorption device is maintained at the temperature constant state that temperature is the formation temperature, and it is close by described first to reduce rate according to specified pressure The pressure in desorption device is closed from the drop in formation pressure to default geostatic pressure, and is obtained in the described first closed desorption device Pressure reduction during the corresponding first natural gas desorption rate data of the first shale core sample；Wherein, described One natural gas desorption rate data include multiple first data points, and first data point includes：Pressure differential and the first natural gas Desorption rate；The pressure differential is corresponded with the first natural gas desorption rate；The specified pressure reduces rate representation Drilling well head of liquid during rock core above carries where coring tube at depth of stratum reduces rate；
First model building module for being based on the first natural gas desorption rate data, is established described natural The correlation model of gas desorption rate and pressure differential；Wherein, the natural gas desorption rate and the correlation model of pressure differential include First incidence coefficient；Specifically, the first model determining module is used to establish the natural gas desorption speed using following formula The correlation model of rate and pressure differential：
Q1=a11ΔP2
Wherein, Q1Represent the first natural gas desorption rate, Δ P represents the pressure differential, a11Represent that described first closes Contact number；Wherein, when Δ P is less than or equal to 0, Q1Value be 0.
In preferred embodiment, the second correlation model determining module includes：Second desorption rate data acquisition module and Two model building modules；Wherein,
The second desorption rate data acquisition module, for obtaining the first shale core sample described in assignment procedure Corresponding second natural gas desorption rate data；Wherein, the assignment procedure represents the natural of the first shale core sample Gas desorption rate increases and increased process with desorption time；The second natural gas desorption rate data include the multiple second numbers Strong point, second data point include：Desorption time and the second natural gas desorption rate；The desorption time with described second day Right gas desorption rate corresponds；
Second model building module for being based on the second natural gas desorption rate data, is established described natural The correlation model of gas desorption rate and desorption time；Wherein, the correlation model packet of the natural gas desorption rate and desorption time Include the second incidence coefficient and third incidence coefficient；Specifically, second model building module is used to establish using following formula The correlation model of the natural gas desorption rate and desorption time：
Wherein, Q2Represent the second natural gas desorption rate, t2Represent the desorption time, a21And a22Institute is represented respectively State the second incidence coefficient and the third incidence coefficient.
In preferred embodiment, the free tolerance determining module includes：Desorption quantity determination sub-module, first-loss amount determine son Module, the second loss amount determination sub-module and free tolerance determination sub-module；Wherein,
The desorption quantity determination sub-module, for above being carried after the second shale core sample to well head, by described Two shale core samples take out from coring tube, and are put into the second closed desorption device equipped with drilling fluid；Wherein, described second Temperature and pressure in closed desorption device is respectively the formation temperature and the default strata pressure；And obtain two specified solutions Time corresponding natural gas desorption rate and the second shale core sample are inhaled in the described second closed desorption device Desorption process in natural gas desorption quantity；
The first-loss amount determination sub-module, for according to the corresponding natural gas desorption rate of the specified desorption time With the natural gas desorption rate and the correlation model of desorption time, determine the second shale core sample from well head to being put into Natural gas loss amount during second closed desorption device；
The second loss amount determination sub-module, for being associated with mould based on the natural gas desorption rate and pressure differential Type, determine the second shale core sample from bore open after to it is upper in advance during natural gas loss amount and described second Natural gas loss amount of the shale core sample during upper carry；
The free tolerance determination sub-module, for based on the second shale core sample from bore open after to it is upper in advance Natural gas loss amount of the natural gas loss amount, the second shale core sample in the process during upper carry, described second Shale core sample is from well head to the natural gas loss amount and the second shale rock being put into during the second closed desorption device Natural gas desorption quantity in desorption process of the heart sample in the described second closed desorption device, determines the second shale core sample The free tolerance of product.
A kind of method of determining shale air content, shale core sample, the shale core being provided in target interval The quality and brill of sample open the formation temperature where the shale core sample at depth of stratum during the shale core sample； Wherein, the shale core sample is acquired by the method for pressurize coring；The method includes：
It is above carried after the shale core sample to well head, the shale core sample is taken out, and put from coring tube Enter in the closed desorption device equipped with drilling fluid；Wherein, the temperature and pressure in the closed desorption device is respectively default ground temperature Degree and the strata pressure；
It obtains described in the corresponding natural gas desorption rate data of the shale core sample described in assignment procedure and acquisition Natural gas desorption quantity in desorption process of the shale core sample in the closed desorption device；Wherein, the assignment procedure table Show the natural gas desorption rate of the shale core sample increases and increased process with desorption time；The natural gas desorption speed Rate data include multiple data points, and the data point includes：Desorption time and natural gas desorption rate；The desorption time and institute State natural gas desorption rate one-to-one correspondence；
Based on the natural gas desorption rate data, being associated with for the natural gas desorption rate and desorption time is established System；
Based on the incidence relation, determine the shale core sample from well head to being put into during the closed desorption device Natural gas loss amount；And determine the tarpped gas volume of the shale core sample；
It is the natural gas desorption quantity in desorption process based on the shale core sample in the closed desorption device, described Shale core sample is from well head to the natural gas loss amount and the shale core sample being put into during the closed desorption device The tarpped gas volume and quality of product determine the shale air content of the target interval.
The embodiment of the present application provides a kind of method and device of determining shale air content, can be by the first shale rock Heart sample is put into the first closed desorption device equipped with drilling fluid, and it is natural in upper carry to simulate the second shale core sample Gas desorption process, to establish the correlation model of natural gas desorption rate and pressure differential；Wherein, the pressure differential is according to the stratum The pressure that pressure is subtracted in the described first closed desorption device determines；When the pressure reduction in the described first closed desorption device is to default During geostatic pressure, the pressure and temperature in the described first closed desorption device can be kept at the default geostatic pressure and The formation temperature simulates the second shale core sample in the upper natural gas desorption process carried to well head, to establish day The correlation model of right gas desorption rate and desorption time；Correlation model that can be based on the natural gas desorption rate and pressure differential With the natural gas desorption rate and the correlation model of desorption time, the free tolerance of the second shale core sample is determined； Can be based on the free tolerance of the second shale core sample, interval of interest where determining the second shale core sample Shale air content.In this way, the accuracy of shale air content determined by can improving.
Description of the drawings
In order to illustrate the technical solutions in the embodiments of the present application or in the prior art more clearly, to embodiment or it will show below There is attached drawing needed in technology description to be briefly described, it should be apparent that, the accompanying drawings in the following description is only this Some embodiments described in application, for those of ordinary skill in the art, in the premise of not making the creative labor property Under, it can also be obtained according to these attached drawings other attached drawings.
Fig. 1 is a kind of flow chart of the embodiment of the method for determining shale air content of the application；
Fig. 2 is the composition structure chart for the device embodiment that the application determines shale air content；
Fig. 3 is the composition structure that the application determines the first correlation model determining module in the device embodiment of shale air content Figure；
Fig. 4 is the composition structure that the application determines the second correlation model determining module in the device embodiment of shale air content Figure；
Fig. 5 is that the application determines to dissociate in the device embodiment of shale air content the composition structure chart of tolerance determining module.
Specific embodiment
The embodiment of the present application provides a kind of method and device of determining shale air content.
In order to make those skilled in the art better understand the technical solutions in the application, below in conjunction with the application reality The attached drawing in example is applied, the technical solution in the embodiment of the present application is clearly and completely described, it is clear that described implementation Example is merely a part but not all of the embodiments of the present application.Based on the embodiment in the application, this field is common Technical staff's all other embodiments obtained without creative efforts should all belong to the application protection Range.
The embodiment of the present application provides a kind of method of determining shale air content.The determining shale air content is provided with First shale rock described in when one shale core sample and the second shale core sample and brill open the first shale core sample Formation temperature and strata pressure where heart sample at depth of stratum.
In the present embodiment, the first shale core sample is acquired by the method for pressurize coring.The second page Rock core sample is acquired by the method for conventional coring.Wherein, as the second shale core sample above carries in conventional location of the coring procedure The pressure of drilling well fluid column in coring tube continuously decreases, and the natural gas of preservation gradually scatter and disappear by desorption in the second shale core sample, And second natural gas of the shale core sample during above carrying to well head to desorption device in the second shale core sample it is continuous Desorption is scattered and disappeared, but can not be collected, and there are the losses of amount of natural gas.And the acquisition mode of pressurize coring, it is ensured that on rock core Before being taken out after carrying to well head and from coring tube, the natural gas in the first shale core sample will not lose.In this way, can be First shale core sample of later use pressurize coring simulates decompression of the second shale core sample during upper propose Speed and required time can completely reproduce conventional coring and above carry natural gas loss amount during rock core.
In the present embodiment, the first shale core sample and the second shale core sample can be from different The shale interval in research work area collects, and can also be collected from the shale interval in same research work area.
In the present embodiment, by way of drilling measuring, when can obtain brill and opening the first shale core sample Formation temperature and strata pressure where the first shale core sample at depth of stratum.
Fig. 1 is a kind of flow chart of the embodiment of the method for determining shale air content of the application.As shown in Figure 1, described determine The method of shale air content, includes the following steps.
Step S101：The first shale core sample is put into the first closed desorption device equipped with drilling fluid, is simulated Natural gas desorption process of the second shale core sample in upper carry, to establish the pass of natural gas desorption rate and pressure differential Gang mould type；Wherein, the pressure differential subtracts the pressure in the described first closed desorption device according to the strata pressure and determines.
In the present embodiment, the first shale core sample is put into the first closed desorption device equipped with drilling fluid In, natural gas desorption process of the second shale core sample in upper carry is simulated, to establish natural gas desorption rate and pressure The correlation model of force difference, specifically may comprise steps of：
(1) it is above carried after the first shale core sample to well head, it can be by the first shale core sample from taking It takes out, and is put into the first closed desorption device equipped with drilling fluid in core cylinder.Wherein, the temperature in the described first closed desorption device It is respectively the formation temperature and the strata pressure with pressure.
(2) the described first closed desorption device can be maintained to the temperature constant state that temperature is the formation temperature, it can be by Rate is reduced by the pressure in the described first closed desorption device from the drop in formation pressure to default ground face pressure according to specified pressure Power, and the first shale core sample is corresponding during can obtaining the pressure reduction in the described first closed desorption device First natural gas desorption rate data.Wherein, the first natural gas desorption rate data can include multiple first data points, First data point can include：Pressure differential and the first natural gas desorption rate.The pressure differential and first natural gas Desorption rate corresponds.The specified pressure, which reduces rate, can represent the coring tube location layer depth during rock core above carries Drilling well head of liquid at degree reduces rate.For example, rock core upward strain speed is 10 ms/min (m/min) in well, simulate in rock It is 0.115MPa/min that drilling well head of liquid during carrying in the heart where coring tube at depth of stratum, which reduces rate,.
(3) based on the first natural gas desorption rate data, the natural gas desorption rate and pressure differential can be established Correlation model.Wherein, the first incidence coefficient can be included in the natural gas desorption rate and the correlation model of pressure differential.Tool Body, the method that fitting of a polynomial may be used establishes the natural gas desorption rate and the correlation model of pressure differential.
In the present embodiment, may be used that following formula establish the natural gas desorption rate and pressure differential is associated with mould Type：
Q1=a11ΔP2
Wherein, Q1Represent the first natural gas desorption rate, unit is cc/min (cm3/ min), Δ P is represented The pressure differential, unit be megapascal (MPa), a11Represent first incidence coefficient；Wherein, when Δ P is less than or equal to 0, Q1 Value be 0.
In the present embodiment, the default geostatic pressure can be 0.101325 megapascal (MPa).
In the present embodiment, the pressure differential can subtract in the described first closed desorption device according to the strata pressure Pressure determine.The depth of stratum where coring tube during rock core above carries can be represented since the specified pressure reduces rate The drilling well head of liquid at place reduces rate, so reducing rate by the pressure in the described first closed desorption device according to specified pressure During the drop in formation pressure to default geostatic pressure, the pressure in the first closed desorption device is equivalent in rock core Drilling well head of liquid during above carrying where coring tube at depth of stratum adds the default geostatic pressure.In this way, the pressure Force difference can represent the pressure differential that the strata pressure subtracts the drilling well head of liquid and the default geostatic pressure obtains.
Step S102：When pressure reduction to the default geostatic pressure in the described first closed desorption device, by described first Pressure and temperature in closed desorption device is kept at the default geostatic pressure and the formation temperature, simulation described second Shale core sample is in the upper natural gas desorption process carried to well head, to establish the pass of natural gas desorption rate and desorption time Gang mould type.
In the present embodiment, specifically, when the pressure reduction in the described first closed desorption device to default geostatic pressure When, the pressure and temperature in the described first closed desorption device can be kept at the default geostatic pressure and the stratum Temperature can obtain the corresponding second natural gas desorption rate data of the first shale core sample described in assignment procedure.Its In, the assignment procedure represents that the natural gas desorption rate of the first shale core sample is increased with desorption time increase Process.The second natural gas desorption rate data can include multiple second data points, and second data point can include： Desorption time and the second natural gas desorption rate.The desorption time is corresponded with the second natural gas desorption rate.Example Such as, it is for 4 minutes and described to be fetched into the time being put into closed desorption device from coring tube for the first shale core sample The natural gas desorption rate of first shale core sample increases with desorption time and increased maximum desorption time is 51 minutes, i.e., The time of the assignment procedure is 51 minutes.The second natural gas desorption rate data can be based on, establish the natural gas The correlation model of desorption rate and desorption time.Wherein, the correlation model of the natural gas desorption rate and desorption time can be with Including the second incidence coefficient and third incidence coefficient.Specifically, the method that fitting of a polynomial may be used establishes the natural gas The correlation model of desorption rate and desorption time.
In the present embodiment, following formula may be used and establish being associated with for the natural gas desorption rate and desorption time Model：
Wherein, Q2Represent the second natural gas desorption rate, unit cm3/ min, t2Represent the desorption time, it is single Minute is in position, a21And a22Second incidence coefficient and the third incidence coefficient are represented respectively.
Step S103：Correlation model and the natural gas desorption rate based on the natural gas desorption rate and pressure differential With the correlation model of desorption time, the free tolerance of the second shale core sample is determined.
In the present embodiment, correlation model and the natural gas solution based on the natural gas desorption rate and pressure differential Inhale the correlation model of rate and desorption time, determine the free tolerance of the second shale core sample, can specifically include with Lower step：
(1) it is above carried after the second shale core sample to well head, it can be by the second shale core sample from taking It takes out, and is put into the second closed desorption device equipped with drilling fluid in core cylinder.Wherein, the temperature in the described second closed desorption device It is respectively the formation temperature and the default strata pressure with pressure.And two specified desorption times can be obtained and corresponded to respectively Desorption process in the described second closed desorption device of natural gas desorption rate and the second shale core sample in Natural gas desorption quantity.Wherein, described two specified desorption times can be respectively that the second shale core sample is put into second Any two desorption time in the 1st minute~the 5th minute after in closed desorption device.For example, during described two specified desorptions Between can be respectively the 1st minute and the 2nd minute after the second shale core sample is put into the second closed desorption device.
(2) according to the specified corresponding natural gas desorption rate of desorption time and the natural gas desorption rate and desorption The correlation model of time, it may be determined that the second shale core sample is from well head to being put into during the second closed desorption device Natural gas loss amount.
(3) correlation model based on the natural gas desorption rate and pressure differential, it may be determined that second shale core Sample from bore open after to it is upper in advance during natural gas loss amount and the second shale core sample put forward process upper In natural gas loss amount.
(4) based on the second shale core sample from bore open after to it is upper in advance during natural gas loss amount, institute Natural gas loss amount of the second shale core sample during upper carry, the second shale core sample are stated from well head to being put into Natural gas loss amount and the second shale core sample during second closed desorption device is in the described second closed desorption Natural gas desorption quantity in desorption process in device, it may be determined that the free tolerance of the second shale core sample.Specifically, Can by the second shale core sample from bore open after to it is upper in advance during natural gas loss amount, second shale Natural gas loss amount of the core sample during upper carry, the second shale core sample are from well head to being put into the second closed solution The desorption of natural gas loss amount and the second shale core sample in the described second closed desorption device during haustorium The sum of natural gas desorption quantity in the process, the free tolerance as the second shale core sample.
In the present embodiment, the second shale core sample is fetched into from coring tube is put into the second closed desorption device Time be less than or equal to 30 minutes.
In the present embodiment, solution of the second shale core sample in the described second closed desorption device can be obtained Natural gas desorption quantity during suction, i.e., after the completion of described second shale core sample desorbs in the described second closed desorption device Total natural gas desorption quantity.Wherein, when intraday natural gas desorption quantity is less than 1cm3When, show that desorption is completed.
In the present embodiment, according to the specified corresponding natural gas desorption rate of desorption time and the natural gas solution The correlation model of rate and desorption time is inhaled, determines the second shale core sample from well head to being put into the second closed desorption device Natural gas loss amount in the process, specifically may comprise steps of：
(1) according to the specified corresponding natural gas desorption rate of desorption time and the natural gas desorption rate and desorption The correlation model of time, it may be determined that corresponding second incidence coefficient of the second shale core sample and third incidence coefficient. Specifically, described two specified desorption times and the corresponding natural gas of the specified desorption time can be desorbed speed Rate is substituted into the correlation model of the natural gas desorption rate and desorption time, can obtain the second shale core sample Corresponding second incidence coefficient and third incidence coefficient.For example, the second shale core sample is fetched into from coring tube and puts The time t for entering the second closed desorption device is 15 minutes, and described two specified desorption times can be respectively the second shale rock Heart sample taken out from coring tube after t3(t+1) minute and t4(t+2) minute and described two specified desorption times Corresponding natural gas desorption rate is respectively Q3And Q4, and following formula are used by Q3And Q4Be converted to ground standard air Respective value under pressure and 25 degrees Celsius (DEG C)：
Wherein, Q' represents that the Q when pressure and temperature is respectively P and T is converted to ground standard atmospheric pressure and 25 degrees Celsius Respective value under (DEG C)；Q represents the natural gas desorption rate when pressure and temperature is respectively P and T, and P represents the corresponding pressures of Q Power, T represent the corresponding temperature of Q.It can obtain respective value Q3' and Q'4Respectively 40.4404cm3/ min and 40.8216cm3/ min.By specified desorption time t3(t3=16) minute and t4(t4=17) minute and respective value Q3' and Q'4, substitute into institute In the correlation model for stating natural gas desorption rate and desorption time, it is corresponding that the second shale core sample can be calculated Second incidence coefficient and third incidence coefficient are respectively 25.914 and 0.1595.
(2) according to corresponding second incidence coefficient of the second shale core sample and third incidence coefficient and described The correlation model of natural gas desorption rate and desorption time establishes the corresponding natural gas desorption speed of the second shale core sample The incidence relation of rate and desorption time.For example, following formula, which may be used, establishes the corresponding day of the second shale core sample The incidence relation of right gas desorption rate and desorption time：
Q'2=25.914 (t'2)0.1595
Wherein, Q'2Represent the second shale core sample from well head to be put into during the second closed desorption device or Natural gas desorption rate in the assignment procedure, t'2Represent that the second shale core sample is close from well head to being put into second It closes during desorption device or the desorption time in the assignment procedure.
(3) incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and desorption time, Determine the second shale core sample from well head to the natural gas loss amount being put into during the second closed desorption device.Specifically Ground, the incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and desorption time, it may be determined that The second shale core sample is from well head to the natural gas desorption rate being put into during the second closed desorption device.According to described Second shale core sample is from well head to the natural gas desorption rate being put into during the second closed desorption device, it may be determined that described Second shale core sample is from well head to the natural gas loss amount being put into during the second closed desorption device.
In the present embodiment, the correlation model based on the natural gas desorption rate and pressure differential, determines described second Shale core sample from bore open after to it is upper in advance during natural gas loss amount and the second shale core sample exist Natural gas loss amount during above carrying, specifically may comprise steps of：
(1) according to the corresponding natural gas desorption rate of the second shale core sample and the incidence relation of desorption time, It can determine natural gas desorption rate when the second shale core sample is above carried to well head.It for example, can be by t'2=1 generation In the incidence relation for entering the corresponding natural gas desorption rate of the second shale core sample and desorption time, it is calculated described The value of natural gas desorption rate when second shale core sample is above carried to well head is 25.914cm3/min。
(2) described in natural gas desorption rate and brill when above being carried to well head according to the second shale core sample are opened Strata pressure, the default ground face pressure where second shale core sample described in during the second shale core sample at depth of stratum Power, it may be determined that corresponding first incidence coefficient of the second shale core sample.Specifically, the second page is opened for example, boring Strata pressure described in during rock core sample at depth of stratum where the second shale core sample is 19.665MPa, place stratum Depth is 1710m, and the default geostatic pressure is 0.101325MPa, can above carry the second shale core sample to well Value (the 25.914cm of natural gas desorption rate during mouth3/ min), bore open second page during the first shale core sample Strata pressure (19.665MPa) and the default geostatic pressure (0.101325MPa) where rock core sample at depth of stratum Difference, substitute into the natural gas desorption rate and the correlation model of pressure differential, the second shale rock can be calculated The value of corresponding first incidence coefficient of heart sample is 0.0678.
(3) according to corresponding first incidence coefficient of the second shale core sample and the natural gas desorption rate With the correlation model of pressure differential, the corresponding natural gas desorption rate of the second shale core sample and pressure differential can be established Incidence relation.For example, may be used following formula establish the corresponding natural gas desorption rate of the second shale core sample with The incidence relation of pressure differential：
Q′1=0.0678 (Δ P '1)2
Wherein, Q '1Represent the second shale core sample from brill open after to it is upper in advance during or upper put forward process In natural gas desorption rate, Δ P '1It represents to bore the second shale core sample institute described in when opening the second shale core sample Strata pressure at depth of stratum, with the second shale core sample from brill open after to it is upper in advance during or carry upper The pressure differential of drilling well head of liquid where coring tube in the process at depth of stratum.As Δ P '1During less than 0, Q '1Value be 0。
(4) incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and pressure differential, can With determine the second shale core sample from bore open after to it is upper in advance during natural gas loss amount and described second Natural gas loss amount of the shale core sample during upper carry.Specifically, for example, when brill opens the second shale core sample Depth of stratum H where the second shale core sample is 1710m, the density p of drilling fluidmudFor 1.2g/cm3, location layer depth Drilling well head of liquid at degree is ρmudH/100 and strata pressure are 19.665MPa, i.e. Δ P1=19.665- ρmudH/100, institute State the second shale core sample from bore open after to it is upper in advance during Δ P '1For -0.855MPa, less than 0.It is in this way, described Second shale core sample from bore open after to it is upper in advance during natural gas loss amount be 0.Meanwhile based on the second page The incidence relation of the corresponding natural gas desorption rate of rock core sample and pressure differential, it may be determined that the second shale core sample Natural gas desorption rate during upper carry.It is desorbed according to natural gas of the second shale core sample during upper carry Natural gas loss amount of the second shale core sample during upper carry can be calculated in rate.
Step S104：Based on the free tolerance of the second shale core sample, the second shale core sample is determined The shale air content of place interval of interest.
In the present embodiment, the quality of the second shale core sample can be obtained；Wherein, the second shale rock Quality after the drilling fluid and water on the second shale core sample surface after the completion of the quality representation removal desorption of heart sample.Example Such as, a ten thousandth electronic balance may be used to weigh the quality of the second shale core sample, obtain described second The quality of shale core sample is 1200.0001 grams (g).
In the present embodiment, the free tolerance based on the second shale core sample, determines the second shale rock The shale air content of interval of interest, can specifically include where heart sample, can be by the second shale core sample after the completion of desorption Product are put into the closed grinder for filling water, are crushed processing to the second shale core sample after the completion of the desorption, are obtained To the tarpped gas volume of the second shale core sample.Free tolerance and residue gas based on the second shale core sample The quality of amount and the second shale core sample, it may be determined that interval of interest where the second shale core sample Shale air content.It specifically, can be by the sum of the free tolerance of the second shale core sample and tarpped gas volume divided by described The quality of second shale core sample, the shale air content of interval of interest where obtaining the second shale core sample.
For example, the interval of interest in research area is marine deposit, apart 100 meters of the well of the well of pressurize coring and conventional coring, The shale distribution in the research area is stablized, and property is basically identical, the first shale core sample and second shale core Sample is respective layer position in the same same interval of interest for studying area, and therefore, the shale air content of two mouthfuls of wells should be identical. Depth of stratum H where first shale core sample described in when brill opens the first shale core sample is 1700m, corresponding stratum Pressure is 19.55MPa, and depth of stratum H where the second shale core sample described in when brill opens the second shale core sample is 1710m, corresponding strata pressure be 19.665MPa, the density p of drilling fluidmudFor 1.2g/cm3, the first shale core sample It is 4 minutes that product are fetched into time for being put into closed desorption device from coring tube, and the second shale core sample is from coring tube In be fetched into that be put into time of the second closed desorption device be 15 minutes, the quality of the first shale core sample is 1050.0325 grams, the quality of the second shale core sample is 1200.0001 grams.It can be obtained respectively using the application method It is respectively 5.8964 to the first shale core sample and the corresponding shale air content of the second shale core sample Cubic meter/ton and 5.8439 cubic metres/ton, relative error therebetween is 0.898%.The shale obtained due to pressurize coring What air content reflected is the true air content of shale formation, therefore, the conventional coring Jing Yeyanyan obtained using the application method The air content of the heart is more accurate.
The embodiment of the present application additionally provides a kind of method of determining shale air content.The method of the determining shale air content Shale core sample, the quality of the shale core sample and the brill that can be provided in target interval open the shale core Formation temperature during sample where the shale core sample at depth of stratum；Wherein, the shale core sample passes through pressurize The method acquisition of coring.The method of the determining shale air content, includes the following steps.
Step S201：It is above carried after the shale core sample to well head, it can be by the shale core sample from coring It is taken out, and be put into the closed desorption device equipped with drilling fluid in cylinder；Wherein, the temperature and pressure difference in the closed desorption device For default surface temperature and the strata pressure.
Step S202：The corresponding natural gas desorption rate number of the shale core sample described in assignment procedure can be obtained According to and obtain natural gas desorption quantity in the desorption process of the shale core sample in the closed desorption device；Wherein, The assignment procedure represents that the natural gas desorption rate of the shale core sample increases and increased process with desorption time；Institute It states natural gas desorption rate data and includes multiple data points, the data point includes：Desorption time and natural gas desorption rate；Institute Desorption time is stated to correspond with the natural gas desorption rate.
Step S203：Based on the natural gas desorption rate data, the natural gas desorption rate and desorption can be established The incidence relation of time.
In the present embodiment, based on the natural gas desorption rate data, the method that fitting of a polynomial may be used is built Found the incidence relation of the natural gas desorption rate and desorption time.Specifically, for example, may be used described in following formula foundation The incidence relation of natural gas desorption rate and desorption time：
Q″2=19.88 (t "2)0.1377
Wherein, Q "2Represent the shale core sample from well head to being put into during closed desorption device or described specified Natural gas desorption rate in the process, t "2Represent the shale core sample from well head to being put into during closed desorption device or Desorption time in the assignment procedure.
Step S204：Based on the incidence relation, it may be determined that the shale core sample is described close from well head to being put into Close the natural gas loss amount during desorption device.Specifically, based on the incidence relation, it may be determined that the shale core sample From well head to the natural gas desorption rate being put into during closed desorption device.According to the shale core sample from well head to being put into Natural gas desorption rate during closed desorption device, it may be determined that the shale core sample is from well head to being put into closed desorption Natural gas loss amount during device.
It can determine the tarpped gas volume of the shale core sample.It specifically, can be by the shale core after the completion of desorption Sample is put into the closed grinder for filling water, is crushed processing to the shale core sample after the completion of the desorption, is obtained The tarpped gas volume of the shale core sample.
Step S205：The natural gas solution in desorption process based on the shale core sample in the closed desorption device Pipette, the shale core sample are from well head to the natural gas loss amount that is put into during the closed desorption device and described The tarpped gas volume and quality of shale core sample determine the shale air content of the target interval.
In the present embodiment, the quality of the shale core sample can be obtained；Wherein, the shale core sample Quality after the drilling fluid and water of shale core sample surfaces after the completion of quality representation removal desorption.For example, it may be used ten thousand / mono- electronic balance weighs the quality of the shale core sample, and the quality for obtaining the shale core sample is 1050.0325 gram.
In the present embodiment, based on the day in desorption process of the shale core sample in the closed desorption device Right gas desorption quantity, the shale core sample from well head to the natural gas loss amount being put into during the closed desorption device, with And the tarpped gas volume and quality of the shale core sample, it determines the shale air content of the target interval, can specifically include, It can be by natural gas desorption quantity, the shale rock in desorption process of the shale core sample in the closed desorption device Heart sample is from well head to the residual of the natural gas loss amount and the shale core sample being put into during the closed desorption device The sum of tolerance divided by the quality of the shale core sample are stayed, the shale of interval of interest where obtaining the shale core sample Air content.In this way, for the research work area with pressurize coring, method provided by the embodiments of the present application may be used and determine shale Air content.
The first shale core sample can be put into equipped with drilling well by the embodiment of the method for the determining shale air content In first closed desorption device of liquid, natural gas desorption process of the second shale core sample in upper carry is simulated, to establish The correlation model of natural gas desorption rate and pressure differential；Wherein, the pressure differential subtracts described first according to the strata pressure Pressure in closed desorption device determines；It, can be with when pressure reduction to the default geostatic pressure in the described first closed desorption device Pressure and temperature in described first closed desorption device is kept at the default geostatic pressure and the formation temperature, mould Intend the second shale core sample in the upper natural gas desorption process carried to well head, to establish natural gas desorption rate and solution Inhale the correlation model of time；Correlation model that can be based on the natural gas desorption rate and pressure differential and natural gas desorption The correlation model of rate and desorption time determines the free tolerance of the second shale core sample；It can be based on described second The free tolerance of shale core sample, the shale air content of interval of interest where determining the second shale core sample.In this way, Can accurately obtain shale core sample that free tolerance includes from bore open after to it is upper in advance during natural gas loss Amount, natural gas loss amount of the shale core sample during upper carry, shale core sample are from well head to being put into the second closed solution Natural gas loss amount during haustorium, so as to improve the accuracy of identified shale air content.
Fig. 2 is the composition structure chart for the device embodiment that the application determines shale air content.The determining shale air content Device the first shale core sample and the second shale core sample be provided and bored open the first shale core sample when institute Formation temperature and strata pressure where stating the first shale core sample at depth of stratum；Wherein, the first shale core sample Product are acquired by the method for pressurize coring, and the second shale core sample is acquired by the method for conventional coring.Such as Fig. 2 institutes Show, the device of the determining shale air content can include：First correlation model determining module 100, the second correlation model determine Module 200, free tolerance determining module 300 and shale air content determining module 400.
The first correlation model determining module 100 can be used for the first shale core sample being put into equipped with brill In first closed desorption device of well liquid, natural gas desorption process of the second shale core sample in upper carry is simulated, to build The correlation model of vertical natural gas desorption rate and pressure differential；Wherein, the pressure differential subtracts described according to the strata pressure Pressure in one closed desorption device determines.
The second correlation model determining module 200 can be used for when the pressure reduction in the described first closed desorption device During to default geostatic pressure, the pressure and temperature in the described first closed desorption device is kept at the default geostatic pressure With the formation temperature, the second shale core sample is simulated in the upper natural gas desorption process carried to well head, to establish The correlation model of natural gas desorption rate and desorption time.
The free tolerance determining module 300 can be used for being associated with based on the natural gas desorption rate and pressure differential Model and the correlation model of the natural gas desorption rate and desorption time determine the free gas of the second shale core sample Amount.
The shale air content determining module 400, can be used for the free tolerance based on the second shale core sample, The shale air content of interval of interest where determining the second shale core sample.
Fig. 3 is the composition structure that the application determines the first correlation model determining module in the device embodiment of shale air content Figure.As shown in figure 3, the first correlation model determining module 100 in Fig. 2 can include：First desorption rate data acquisition module 110 and first model building module 120.
The first desorption rate data acquisition module 110, can be used for treating the first shale core sample above carry to After well head, the first shale core sample from coring tube is taken out, and is put into the first closed desorption device equipped with drilling fluid In；Wherein, the temperature and pressure in the described first closed desorption device is respectively the formation temperature and the strata pressure；It and will The first closed desorption device is maintained at the temperature constant state that temperature is the formation temperature, and rate is reduced by institute according to specified pressure The pressure in the first closed desorption device is stated from the drop in formation pressure to default geostatic pressure, and is obtained closed described first The corresponding first natural gas desorption rate data of the first shale core sample during pressure reduction in desorption device；Its In, the first natural gas desorption rate data include multiple first data points, and first data point includes：Pressure differential and One natural gas desorption rate；The pressure differential is corresponded with the first natural gas desorption rate；The specified pressure reduces Drilling well head of liquid of the rate representation during rock core above carries where coring tube at depth of stratum reduces rate.
First model building module 120 can be used for, based on the first natural gas desorption rate data, establishing institute State natural gas desorption rate and the correlation model of pressure differential；Wherein, the natural gas desorption rate and the correlation model of pressure differential Include the first incidence coefficient；Specifically, the first model determining module can be used for establishing the day using following formula The correlation model of right gas desorption rate and pressure differential：
Q1=a11ΔP2
Wherein, Q1Represent the first natural gas desorption rate, Δ P represents the pressure differential, a11Represent that described first closes Contact number；Wherein, when Δ P is less than or equal to 0, Q1Value be 0.
Fig. 4 is the composition structure that the application determines the second correlation model determining module in the device embodiment of shale air content Figure.As shown in figure 4, the second correlation model determining module 200 in Fig. 2 can include：Second desorption rate data acquisition module 210 and second model building module 220.
The second desorption rate data acquisition module 210 can be used for obtaining the first shale described in assignment procedure The corresponding second natural gas desorption rate data of core sample；Wherein, the assignment procedure represents the first shale core sample The natural gas desorption rate of product increases and increased process with desorption time；The second natural gas desorption rate data include more A second data point, second data point include：Desorption time and the second natural gas desorption rate；The desorption time and institute State the second natural gas desorption rate one-to-one correspondence.
Second model building module 220 can be used for, based on the second natural gas desorption rate data, establishing institute State the correlation model of natural gas desorption rate and desorption time；Wherein, the natural gas desorption rate and desorption time are associated with Model includes the second incidence coefficient and third incidence coefficient；Specifically, second model building module can be used for using down State the correlation model that formula establishes the natural gas desorption rate and desorption time：
Wherein, Q2Represent the second natural gas desorption rate, t2Represent the desorption time, a21And a22Institute is represented respectively State the second incidence coefficient and the third incidence coefficient.
Fig. 5 is that the application determines to dissociate in the device embodiment of shale air content the composition structure chart of tolerance determining module. As shown in figure 5, the free tolerance determining module 300 in Fig. 2 can include：Desorption quantity determination sub-module 310, first-loss amount are true Stator modules 320, the second loss amount determination sub-module 330 and free tolerance determination sub-module 340.
The desorption quantity determination sub-module 310 can be used for above carrying to well head after the second shale core sample, will The second shale core sample takes out from coring tube, and is put into the second closed desorption device equipped with drilling fluid；Wherein, institute It is respectively the formation temperature and the default strata pressure to state the temperature and pressure in the second closed desorption device；And obtain two The specified corresponding natural gas desorption rate of desorption time and the second shale core sample are in the described second closed solution Natural gas desorption quantity in desorption process in haustorium.
The first-loss amount determination sub-module 320 can be used for according to the corresponding natural gas of the specified desorption time Desorption rate and the correlation model of the natural gas desorption rate and desorption time determine the second shale core sample from well Mouthful to the natural gas loss amount being put into during the second closed desorption device.
The second loss amount determination sub-module 330 can be used for based on the natural gas desorption rate and pressure differential Correlation model, determine the second shale core sample from bore open after to it is upper in advance during natural gas loss amount and institute State natural gas loss amount of the second shale core sample during upper carry.
The free tolerance determination sub-module 340, can be used for based on the second shale core sample from brill open after to It is upper in advance during natural gas loss amount during upper carry of natural gas loss amount, the second shale core sample, The second shale core sample is from well head to the natural gas loss amount and described being put into during the second closed desorption device Natural gas desorption quantity in desorption process of the two shale core samples in the described second closed desorption device, determines the second page The free tolerance of rock core sample.
The device embodiment of the determining shale air content is corresponding with the embodiment of the method for the determining shale air content, It can realize the technical solution of the embodiment of the method for determining shale air content, and the technique effect of adquisitiones embodiment.
In the 1990s, the improvement of a technology can be distinguished clearly be on hardware improvement (for example, Improvement to circuit structures such as diode, transistor, switches) or software on improvement (improvement for method flow).So And with the development of technology, the improvement of current many method flows can be considered as directly improving for hardware circuit. Designer nearly all obtains corresponding hardware circuit by the way that improved method flow is programmed into hardware circuit.Cause This, it cannot be said that the improvement of a method flow cannot be realized with hardware entities module.For example, programmable logic device (Programmable Logic Device, PLD) (such as field programmable gate array (Field Programmable Gate Array, FPGA)) it is exactly such a integrated circuit, logic function determines device programming by user.By designer Voluntarily programming a digital display circuit " integrated " on a piece of PLD, designs and make without asking chip maker Dedicated IC chip.Moreover, nowadays, substitution manually makes IC chip, this programming is also used instead mostly " patrols Volume compiler (logic compiler) " software realizes that software compiler used is similar when it writes with program development, And the source code before compiling also write by handy specific programming language, this is referred to as hardware description language (Hardware Description Language, HDL), and HDL is also not only a kind of, but there are many kind, such as ABEL (Advanced Boolean Expression Language)、AHDL(Altera Hardware Description Language)、Confluence、CUPL(Cornell University Programming Language)、HDCal、JHDL (Java Hardware Description Language)、Lava、Lola、MyHDL、PALASM、RHDL(Ruby Hardware Description Language) etc., VHDL (Very-High-Speed are most generally used at present Integrated Circuit Hardware Description Language) and Verilog2.Those skilled in the art It will be apparent to the skilled artisan that it only needs method flow slightly programming in logic and being programmed into integrated circuit with above-mentioned several hardware description languages In, it is possible to it is readily available the hardware circuit for realizing the logical method flow.
It is also known in the art that other than realizing controller in a manner of pure computer readable program code, it is complete Entirely can by by method and step carry out programming in logic come controller with logic gate, switch, application-specific integrated circuit, may be programmed The form of logic controller and embedded microcontroller etc. realizes identical function.Therefore this controller is considered one kind Hardware component, and the structure that can also be considered as to the device for being used to implement various functions included in it in hardware component.Or Even, the device for being used to implement various functions can be considered as either the software module of implementation method can be Hardware Subdivision again Structure in part.
Device that above-described embodiment illustrates, module can specifically be realized or by computer chip or entity by having certain The product of function is planted to realize.
For convenience of description, it is divided into various modules during description apparatus above with function to describe respectively.Certainly, implementing this The function of each module is realized can in the same or multiple software and or hardware during application.
As seen through the above description of the embodiments, those skilled in the art can be understood that the application can It is realized by the mode of software plus required general hardware platform.Based on such understanding, the technical solution essence of the application On the part that the prior art contributes can be embodied in the form of software product in other words, in a typical configuration In, computing device includes one or more processors (CPU), input/output interface, network interface and memory.The computer is soft Part product can include some instructions and use so that a computer equipment (can be personal computer, server or network Equipment etc.) perform method described in certain parts of each embodiment of the application or embodiment.The computer software product can To store in memory, memory may include the volatile memory in computer-readable medium, random access memory (RAM) and/or the forms such as Nonvolatile memory, such as read-only memory (ROM) or flash memory (flash RAM).Memory is computer The example of readable medium.Computer-readable medium includes permanent and non-permanent, removable and non-removable media can be by Any method or technique come realize information store.Information can be computer-readable instruction, data structure, the module of program or its His data.The example of the storage medium of computer includes, but are not limited to phase transition internal memory (PRAM), static RAM (SRAM), dynamic random access memory (DRAM), other kinds of random access memory (RAM), read-only memory (ROM), electrically erasable programmable read-only memory (EEPROM), fast flash memory bank or other memory techniques, CD-ROM are read-only Memory (CD-ROM), digital versatile disc (DVD) or other optical storages, magnetic tape cassette, tape magnetic rigid disk storage or Other magnetic storage apparatus or any other non-transmission medium, available for storing the information that can be accessed by a computing device.According to Herein defines, and computer-readable medium does not include of short duration computer readable media (transitory media), such as modulation Data-signal and carrier wave.
Each embodiment in this specification is described by the way of progressive, identical similar portion between each embodiment Point just to refer each other, and the highlights of each of the examples are difference from other examples.Especially for device reality For applying example, since it is substantially similar to embodiment of the method, so description is fairly simple, related part is referring to embodiment of the method Part explanation.
The application can be used in numerous general or special purpose computing system environments or configuration.Such as：Personal computer, clothes Business device computer, handheld device or portable device, multicomputer system, the system based on microprocessor, are put laptop device Top box, programmable consumer-elcetronics devices, network PC, minicomputer, mainframe computer, including any of the above system or equipment Distributed computing environment etc..
The application can be described in the general context of computer executable instructions, such as program Module.Usually, program module includes routines performing specific tasks or implementing specific abstract data types, program, object, group Part, data structure etc..The application can also be put into practice in a distributed computing environment, in these distributed computing environment, by Task is performed and connected remote processing devices by communication network.In a distributed computing environment, program module can be with In the local and remote computer storage media including storage device.
Although depicting the application by embodiment, it will be appreciated by the skilled addressee that the application there are many deformation and Variation is without departing from spirit herein, it is desirable to which appended claim includes these deformations and changes without departing from the application's Spirit.

Claims (14)

  1. A kind of 1. method of determining shale air content, which is characterized in that be provided with the first shale core sample and the second shale rock Stratum described in when heart sample and brill open the first shale core sample where the first shale core sample at depth of stratum Temperature and strata pressure；Wherein, the first shale core sample is acquired by the method for pressurize coring, the second shale rock Heart sample is acquired by the method for conventional coring；The method includes：
    The first shale core sample is put into the first closed desorption device equipped with drilling fluid, simulates the second shale rock Natural gas desorption process of the heart sample in upper carry, to establish the correlation model of natural gas desorption rate and pressure differential；Wherein, institute It states pressure differential the pressure in the described first closed desorption device is subtracted according to the strata pressure and determine；
    It, will be in the described first closed desorption device when pressure reduction to the default geostatic pressure in the described first closed desorption device Pressure and temperature is kept at the default geostatic pressure and the formation temperature, simulates the second shale core sample and exists The natural gas desorption process to well head is above carried, to establish the correlation model of natural gas desorption rate and desorption time；
    Correlation model and the natural gas desorption rate and desorption time based on the natural gas desorption rate and pressure differential Correlation model determines the free tolerance of the second shale core sample；
    Based on the free tolerance of the second shale core sample, interval of interest where determining the second shale core sample Shale air content.
  2. 2. the method for a kind of determining shale air content according to claim 1, which is characterized in that described by the first page Rock core sample is put into the first closed desorption device equipped with drilling fluid, simulates the second shale core sample in upper carry Natural gas desorption process, to establish the correlation model of natural gas desorption rate and pressure differential, including：
    It is above carried after the first shale core sample to well head, the first shale core sample is taken out from coring tube, And it is put into the first closed desorption device equipped with drilling fluid；Wherein, the temperature and pressure difference in the described first closed desorption device For the formation temperature and the strata pressure；
    Described first closed desorption device is maintained at the temperature constant state that temperature is the formation temperature, speed is reduced according to specified pressure Rate from the drop in formation pressure to default geostatic pressure, and obtains the pressure in the described first closed desorption device described the The corresponding first natural gas desorption rate number of the first shale core sample during pressure reduction in one closed desorption device According to；Wherein, the first natural gas desorption rate data include multiple first data points, and first data point includes：Pressure Difference and the first natural gas desorption rate；The pressure differential is corresponded with the first natural gas desorption rate；The specified pressure Power, which reduces drilling well head of liquid of the rate representation during rock core above carries where coring tube at depth of stratum, reduces rate；
    Based on the first natural gas desorption rate data, the natural gas desorption rate and the correlation model of pressure differential are established； Wherein, the natural gas desorption rate and the correlation model of pressure differential include the first incidence coefficient.
  3. 3. the method for a kind of determining shale air content according to claim 2, which is characterized in that established using following formula The correlation model of the natural gas desorption rate and pressure differential：
    Q1=a11ΔP2
    Wherein, Q1Represent the first natural gas desorption rate, Δ P represents the pressure differential, a11Represent the first association system Number；Wherein, when Δ P is less than or equal to 0, Q1Value be 0.
  4. A kind of 4. method of determining shale air content according to claim 1, which is characterized in that the simulation described second Shale core sample is in the upper natural gas desorption process carried to well head, to establish the pass of natural gas desorption rate and desorption time Gang mould type, including：
    Obtain the corresponding second natural gas desorption rate data of the first shale core sample described in assignment procedure；Wherein, institute It states assignment procedure and represents that the natural gas desorption rate of the first shale core sample increases and increased process with desorption time； The second natural gas desorption rate data include multiple second data points, and second data point includes：Desorption time and Two natural gas desorption rates；The desorption time is corresponded with the second natural gas desorption rate；
    Based on the second natural gas desorption rate data, that establishes the natural gas desorption rate and desorption time is associated with mould Type；Wherein, the correlation model of the natural gas desorption rate and desorption time includes the second incidence coefficient and third incidence coefficient.
  5. 5. the method for a kind of determining shale air content according to claim 4, which is characterized in that established using following formula The correlation model of the natural gas desorption rate and desorption time：
    Wherein, Q2Represent the second natural gas desorption rate, t2Represent the desorption time, a21And a22Described is represented respectively Two incidence coefficients and the third incidence coefficient.
  6. 6. the method for a kind of determining shale air content according to claim 1, which is characterized in that described based on described natural Gas desorption rate and the correlation model of pressure differential and the correlation model of the natural gas desorption rate and desorption time determine described The free tolerance of second shale core sample, including：
    It is above carried after the second shale core sample to well head, the second shale core sample is taken out from coring tube, And it is put into the second closed desorption device equipped with drilling fluid；Wherein, the temperature and pressure difference in the described second closed desorption device For the formation temperature and the default strata pressure；And the corresponding natural gas desorption speed of the specified desorption time of acquisition two Natural gas desorption quantity in the desorption process of rate and the second shale core sample in the described second closed desorption device；
    According to the specified corresponding natural gas desorption rate of desorption time and the natural gas desorption rate and desorption time Correlation model determines the second shale core sample from well head to the natural gas loss being put into during the second closed desorption device Amount；
    Correlation model based on the natural gas desorption rate and pressure differential determines the second shale core sample after brill is opened To it is upper in advance during natural gas loss amount and the second shale core sample during upper carry natural gas damage Vector；
    Based on the second shale core sample from bore open after to it is upper in advance during natural gas loss amount, the second page Natural gas loss amount, the second shale core sample of the rock core sample during upper carry are closed from well head to being put into second The solution of natural gas loss amount and the second shale core sample in the described second closed desorption device during desorption device Natural gas desorption quantity during suction determines the free tolerance of the second shale core sample.
  7. 7. the method for a kind of determining shale air content according to claim 6, which is characterized in that described according to described specified The corresponding natural gas desorption rate of desorption time and the correlation model of the natural gas desorption rate and desorption time determine described Second shale core sample from well head to the natural gas loss amount being put into during the second closed desorption device, including：
    According to the specified corresponding natural gas desorption rate of desorption time and the natural gas desorption rate and desorption time Correlation model determines corresponding second incidence coefficient of the second shale core sample and third incidence coefficient；
    According to corresponding second incidence coefficient of the second shale core sample and third incidence coefficient and the natural gas solution The correlation model of rate and desorption time is inhaled, establishes the corresponding natural gas desorption rate of the second shale core sample and desorption The incidence relation of time；
    Incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and desorption time determines described Second shale core sample is from well head to the natural gas loss amount being put into during the second closed desorption device.
  8. 8. the method for a kind of determining shale air content according to claim 7, which is characterized in that described based on described natural The correlation model of gas desorption rate and pressure differential, determine the second shale core sample from brill open after to it is upper in advance during Natural gas loss amount during upper carry of natural gas loss amount and the second shale core sample, including：
    According to the corresponding natural gas desorption rate of the second shale core sample and the incidence relation of desorption time, determine described Natural gas desorption rate when second shale core sample is above carried to well head；
    Natural gas desorption rate and brill when above being carried to well head according to the second shale core sample open second shale Strata pressure, the default geostatic pressure where second shale core sample described in during core sample at depth of stratum, determine Corresponding first incidence coefficient of the second shale core sample；
    According to corresponding first incidence coefficient of the second shale core sample and the natural gas desorption rate and pressure differential Correlation model, establish the corresponding natural gas desorption rate of the second shale core sample and the incidence relation of pressure differential；
    Incidence relation based on the corresponding natural gas desorption rate of the second shale core sample and pressure differential determines described Two shale core samples from bore open after to it is upper in advance during natural gas loss amount and the second shale core sample Natural gas loss amount during upper carry.
  9. 9. the method for a kind of determining shale air content according to claim 1, which is characterized in that the method is also provided with The quality of the second shale core sample；Wherein, after the completion of the quality representation removal desorption of the second shale core sample The second shale core sample surface drilling fluid and water after quality；It is described free based on the second shale core sample Tolerance, the shale air content of interval of interest where determining the second shale core sample, including：
    The second shale core sample after the completion of desorption is put into the closed grinder for filling water, after the completion of the desorption Second shale core sample crushes processing, obtains the tarpped gas volume of the second shale core sample；
    The matter of free tolerance and tarpped gas volume and the second shale core sample based on the second shale core sample Amount, the shale air content of interval of interest where determining the second shale core sample.
  10. 10. a kind of device of determining shale air content, which is characterized in that described device provides the first shale core sample and second Described in when shale core sample and brill open the first shale core sample where the first shale core sample at depth of stratum Formation temperature and strata pressure；Wherein, the first shale core sample is acquired by the method for pressurize coring, and described second Shale core sample is acquired by the method for conventional coring；Described device includes：First correlation model determining module, the second association Model determining module, free tolerance determining module and shale air content determining module；Wherein,
    The first correlation model determining module, it is close for the first shale core sample to be put into first equipped with drilling fluid It closes in desorption device, simulates natural gas desorption process of the second shale core sample in upper carry, to establish natural gas desorption The correlation model of rate and pressure differential；Wherein, the pressure differential subtracts the described first closed desorption device according to the strata pressure Interior pressure determines；
    The second correlation model determining module, for working as the pressure reduction in the described first closed desorption device to default ground face pressure During power, the pressure and temperature in the described first closed desorption device is kept at the default geostatic pressure and the stratum temperature Degree simulates the second shale core sample in the upper natural gas desorption process carried to well head, to establish natural gas desorption speed The correlation model of rate and desorption time；
    The free tolerance determining module, for the correlation model based on the natural gas desorption rate and pressure differential and the day The correlation model of right gas desorption rate and desorption time determines the free tolerance of the second shale core sample；
    The shale air content determining module for the free tolerance based on the second shale core sample, determines described The shale air content of interval of interest where two shale core samples.
  11. A kind of 11. device of determining shale air content according to claim 10, which is characterized in that the first association mould Type determining module includes：First desorption rate data acquisition module and the first model building module；Wherein,
    The first desorption rate data acquisition module, for above being carried after the first shale core sample to well head, by institute It states the first shale core sample to take out from coring tube, and is put into the first closed desorption device equipped with drilling fluid；Wherein, it is described Temperature and pressure in first closed desorption device is respectively the formation temperature and the strata pressure；It is and closed by described first Desorption device is maintained at the temperature constant state that temperature is the formation temperature, and rate is reduced by the described first closed solution according to specified pressure Pressure in haustorium obtains the pressure in the described first closed desorption device from the drop in formation pressure to default geostatic pressure The corresponding first natural gas desorption rate data of the first shale core sample during power reduces；Wherein, described first day Right gas desorption rate data include multiple first data points, and first data point includes：Pressure differential and the desorption of the first natural gas Rate；The pressure differential is corresponded with the first natural gas desorption rate；The specified pressure reduces rate representation in rock Drilling well head of liquid during carrying in the heart where coring tube at depth of stratum reduces rate；
    First model building module for being based on the first natural gas desorption rate data, establishes the natural gas solution Inhale the correlation model of rate and pressure differential；Wherein, the natural gas desorption rate and the correlation model of pressure differential include first Incidence coefficient；Specifically, the first model determining module be used for using following formula establish the natural gas desorption rate with The correlation model of pressure differential：
    Q1=a11ΔP2
    Wherein, Q1Represent the first natural gas desorption rate, Δ P represents the pressure differential, a11Represent the first association system Number；Wherein, when Δ P is less than or equal to 0, Q1Value be 0.
  12. A kind of 12. device of determining shale air content according to claim 10, which is characterized in that the second association mould Type determining module includes：Second desorption rate data acquisition module and the second model building module；Wherein,
    The second desorption rate data acquisition module corresponds to for obtaining the first shale core sample described in assignment procedure The second natural gas desorption rate data；Wherein, the assignment procedure represents the natural gas solution of the first shale core sample Inhale rate increases and increased process with desorption time；The second natural gas desorption rate data include multiple second data Point, second data point include：Desorption time and the second natural gas desorption rate；The desorption time is natural with described second Gas desorption rate corresponds；
    Second model building module for being based on the second natural gas desorption rate data, establishes the natural gas solution Inhale the correlation model of rate and desorption time；Wherein, the correlation model of the natural gas desorption rate and desorption time includes the Two incidence coefficients and third incidence coefficient；Specifically, second model building module is used for using described in the foundation of following formula The correlation model of natural gas desorption rate and desorption time：
    Wherein, Q2Represent the second natural gas desorption rate, t2Represent the desorption time, a21And a22Described is represented respectively Two incidence coefficients and the third incidence coefficient.
  13. 13. the device of a kind of determining shale air content according to claim 10, which is characterized in that the free tolerance is true Cover half block includes：Desorption quantity determination sub-module, first-loss amount determination sub-module, the second loss amount determination sub-module and free gas Measure determination sub-module；Wherein,
    The desorption quantity determination sub-module, for above being carried after the second shale core sample to well head, by the second page Rock core sample takes out from coring tube, and is put into the second closed desorption device equipped with drilling fluid；Wherein, described second is closed Temperature and pressure in desorption device is respectively the formation temperature and the default strata pressure；And when obtaining two specified desorptions Between the solution of corresponding natural gas desorption rate and the second shale core sample in the described second closed desorption device Natural gas desorption quantity during suction；
    The first-loss amount determination sub-module, for according to the corresponding natural gas desorption rate of the specified desorption time and institute The correlation model of natural gas desorption rate and desorption time is stated, determines the second shale core sample from well head to being put into second Natural gas loss amount during closed desorption device；
    The second loss amount determination sub-module, for the correlation model based on the natural gas desorption rate and pressure differential, really The fixed second shale core sample from bore open after to it is upper in advance during natural gas loss amount and second shale Natural gas loss amount of the core sample during upper carry；
    The free tolerance determination sub-module, for based on the second shale core sample from bore open after to it is upper in advance process In natural gas loss amount, second shale during upper carry of natural gas loss amount, the second shale core sample Core sample is from well head to the natural gas loss amount and the second shale core sample being put into during the second closed desorption device Natural gas desorption quantity in desorption process of the product in the described second closed desorption device, determines the second shale core sample Free tolerance.
  14. A kind of 14. method of determining shale air content, which is characterized in that be provided with shale core sample in target interval, institute It states the quality of shale core sample and brill is opened during the shale core sample at the depth of stratum of the shale core sample place Formation temperature；Wherein, the shale core sample is acquired by the method for pressurize coring；The method includes：
    It above carries to well head, the shale core sample is taken out from coring tube, and be put into dress after the shale core sample Have in the closed desorption device of drilling fluid；Wherein, the temperature and pressure in the closed desorption device be respectively default surface temperature and The strata pressure；
    It obtains the corresponding natural gas desorption rate data of the shale core sample described in assignment procedure and obtains the shale Natural gas desorption quantity in desorption process of the core sample in the closed desorption device；Wherein, the assignment procedure represents institute State the natural gas desorption rate of shale core sample increases and increased process with desorption time；The natural gas desorption rate number According to including multiple data points, the data point includes：Desorption time and natural gas desorption rate；The desorption time and the day Right gas desorption rate corresponds；
    Based on the natural gas desorption rate data, the incidence relation of the natural gas desorption rate and desorption time is established；
    Based on the incidence relation, determine the shale core sample from well head to the day being put into during the closed desorption device Right gas loss amount；And determine the tarpped gas volume of the shale core sample；
    The natural gas desorption quantity in desorption process, the shale based on the shale core sample in the closed desorption device Core sample is from well head to the natural gas loss amount and the shale core sample being put into during the closed desorption device Tarpped gas volume and quality determine the shale air content of the target interval.
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