CN106593423A - Method and device for identifying oil reservoir fluid type - Google Patents
Method and device for identifying oil reservoir fluid type Download PDFInfo
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- CN106593423A CN106593423A CN201610978037.0A CN201610978037A CN106593423A CN 106593423 A CN106593423 A CN 106593423A CN 201610978037 A CN201610978037 A CN 201610978037A CN 106593423 A CN106593423 A CN 106593423A
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/04—Measuring depth or liquid level
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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Abstract
The application provides a method and a device for identifying reservoir fluid types, wherein the method comprises the following steps: determining the apparent density and the apparent sound wave time difference of fluid in the oil reservoir to be detected according to a density logging curve, a sound wave time difference logging curve and a neutron logging curve of the oil reservoir to be detected; determining a first oil-gas detection curve of the fluid in the reservoir to be detected according to the apparent density of the fluid in the reservoir to be detected; determining a second oil-gas detection curve of the fluid in the reservoir to be detected according to the time difference of the visual sound waves of the fluid in the reservoir to be detected; determining a third oil gas detection curve according to the first oil gas detection curve and the second oil gas detection curve; and determining the type of the fluid in the oil reservoir to be detected based on the numerical intervals of the apparent density, the apparent acoustic time difference, the first oil-gas detection curve, the second oil-gas detection curve and the third oil-gas detection curve. The method and the device for identifying the oil reservoir fluid type can improve the identification precision of the oil reservoir fluid type.
Description
Technical field
The application is related to reservoir exploration and development technical field, the recognition methodss of more particularly to a kind of reservoir fluid type and
Device.
Background technology
The effective ways for carrying out reservoir fluid type identification at present mainly use resistivity and porosity curve, according to
The formula such as A Erqi, calculate the water saturation of oil reservoir.The method can effectively recognize oil and water or efficiently identify gas and water,
But conventional oil reservoir, high gas-oil ratio (HGOR) oil reservoir and gas reservoir cannot be accurately distinguished.
Currently when being identified to high gas-oil ratio (HGOR) oil reservoir, gas reservoir, generally using density, neutron well logging curve in gas-bearing bed
There is the phenomenon of " excavation effect " to carry out qualitative recognition.2015《Grand celebration petroleum geology and exploitation》(the 5th phase of volume 34) delivers
What Xu magnitude was write《High gas-oil ratio (HGOR) oil reservoir well logging excavation effect quantitative Analysis and application》, proposed to density, neutron moisture first
Well curve carries out a kind of new method of quantitative Analysis at " excavation effect " of gas-bearing bed.But in use, the method master
There are following two defects：1st, the relatively poor reservoir of physical property, recognition effect are not projected；2nd, density log curve investigative range
It is shallower, easily affected by factors such as mud immersion, Damintuns so that result of calculation is inaccurate.
It should be noted that above the introduction of technical background is intended merely to the convenient technical scheme to the application carry out it is clear,
Complete explanation, and facilitate the understanding of those skilled in the art and illustrate.Can not be merely because these schemes be the application's
Background section is set forth and thinks that above-mentioned technical proposal is known to those skilled in the art.
The content of the invention
The purpose of the application embodiment is recognition methodss and the device for providing a kind of reservoir fluid type, it is possible to increase
The accuracy of identification of reservoir fluid type.
For achieving the above object, on the one hand the application provides a kind of recognition methodss of reservoir fluid type, methods described bag
Include：Density log curve, acoustic travel time logging curve and neutron well logging curve according to oil reservoir to be measured, determines the oil to be measured
In Tibetan the apparent density of fluid and regard interval transit time；According to the apparent density of fluid in the oil reservoir to be measured, the oil reservoir to be measured is determined
First oil and gas detection curve of middle fluid；According in the oil reservoir to be measured fluid regarding interval transit time, determine the oil reservoir to be measured
Second oil and gas detection curve of middle fluid；According to the first oil and gas detection curve and the second oil and gas detection curve, it is determined that
3rd oil and gas detection curve；Based on the apparent density, regarding interval transit time, the first oil and gas detection curve, the second oil and gas detection curve
And the 3rd each residing numerical intervals of oil and gas detection curve, determine the type of fluid in the oil reservoir to be measured.
Further, according to oil reservoir to be measured density log curve, acoustic travel time logging curve and neutron well logging curve,
Determine the apparent density of fluid in the oil reservoir to be measured and specifically include depending on interval transit time：The density of the oil reservoir to be measured is determined respectively
The each self-corresponding porosity curve of log, acoustic travel time logging curve and neutron well logging curve；Based on three holes
Porosity curve, determines the apparent density of fluid in the oil reservoir to be measured and regards interval transit time.
Further, the density log curve, acoustic travel time logging curve and neutron moisture are determined according to the following equation
The each self-corresponding porosity curve of well curve：
POR_DEN=(DEN-DMA)/(DF-DMA) × (1-VSH)
POR_DT=(DT-TMA)/(CP* (TF-TMA)) × (1-VSH)
POR_CN=(CNL-NMA)/(NF-NMA) × (1-VSH)
Wherein, POR_DEN represents the corresponding porosity curve of the density log curve, when POR_DT represents the sound wave
The corresponding porosity curve of difference log, POR_CN represent the corresponding porosity curve of the neutron well logging curve, and DEN is represented
The density of the oil reservoir to be measured, DMA table show the skeletal density in the oil reservoir to be measured, and DF represents the fluid in the oil reservoir to be measured
Density, DT represent the sound wave value of the oil reservoir to be measured, and TMA represents the skeleton sound wave value in the oil reservoir to be measured, and CP represents sound wave
Time difference compacting factor, TF represent the fluid acoustic value in the oil reservoir to be measured, and CNL represents the neutron well logging of the oil reservoir to be measured
Value, NMA represent the skeleton neutron well logging value in the oil reservoir to be measured, and NF represents the fluid neutron well logging in the oil reservoir to be measured
Value, VSH represent the shale content of the oil reservoir to be measured.
Further, the apparent density of fluid in the oil reservoir to be measured is determined according to the following equation and regards interval transit time：
DFA=DMA- (DMA-DEN) * (NF-NMA)/(CNL-NMA)
TFA=TMA+ (DT-TMA) * (NF-NMA)/(CP* (CNL-NMA))
Wherein, DFA represents the apparent density of fluid in the oil reservoir to be measured, and TFA represents regarding for fluid in the oil reservoir to be measured
Interval transit time.
Further, the first oil and gas detection curve of fluid in the oil reservoir to be measured and second oily is determined according to the following equation
Gas detection curve：
HYC_DEN=1-DFA
HYC_DT=TFA/180-1
Wherein, HYC_DEN represents the first oil and gas detection curve, and HYC_DT represents the second oil and gas detection curve.
Further, the 3rd oil and gas detection curve is determined according to the following equation：
HYCI=HYC_DEN+HYC_DT
Wherein, HYCI represents the 3rd oil and gas detection curve.
For achieving the above object, on the other hand the application provides a kind of identifying device of reservoir fluid type, described device
Including：Fluid parameter determining unit, for the density log curve according to oil reservoir to be measured, acoustic travel time logging curve and neutron
Log, determines the apparent density of fluid in the oil reservoir to be measured and regards interval transit time；Oil and gas detection curve determining unit, is used for
According to the apparent density of fluid in the oil reservoir to be measured, the first oil and gas detection curve of fluid in the oil reservoir to be measured is determined；According to
In the oil reservoir to be measured fluid regarding interval transit time, determine the second oil and gas detection curve of fluid in the oil reservoir to be measured；According to
The first oil and gas detection curve and the second oil and gas detection curve, determine the 3rd oil and gas detection curve；Fluid type determines
Unit, for based on the apparent density, regarding interval transit time, the first oil and gas detection curve, the second oil and gas detection curve and the 3rd
The each residing numerical intervals of oil and gas detection curve, determine the type of fluid in the oil reservoir to be measured.
Further, the fluid parameter determining unit is specifically included：Porosity curve determining module, for determining respectively
The each self-corresponding porosity of the density log curve of the oil reservoir to be measured, acoustic travel time logging curve and neutron well logging curve is bent
Line；Parameter determination module, for based on three porosity curves, determining the apparent density of fluid in the oil reservoir to be measured and regarding
Interval transit time.
Further, the porosity curve determining module determines the density log curve, sound wave according to the following equation
Time difference log and each self-corresponding porosity curve of neutron well logging curve：
POR_DEN=(DEN-DMA)/(DF-DMA) × (1-VSH)
POR_DT=(DT-TMA)/(CP* (TF-TMA)) × (1-VSH)
POR_CN=(CNL-NMA)/(NF-NMA) × (1-VSH)
Wherein, POR_DEN represents the corresponding porosity curve of the density log curve, when POR_DT represents the sound wave
The corresponding porosity curve of difference log, POR_CN represent the corresponding porosity curve of the neutron well logging curve, and DEN is represented
The density of the oil reservoir to be measured, DMA table show the skeletal density in the oil reservoir to be measured, and DF represents the fluid in the oil reservoir to be measured
Density, DT represent the sound wave value of the oil reservoir to be measured, and TMA represents the skeleton sound wave value in the oil reservoir to be measured, and CP represents sound wave
Time difference compacting factor, TF represent the fluid acoustic value in the oil reservoir to be measured, and CNL represents the neutron well logging of the oil reservoir to be measured
Value, NMA represent the skeleton neutron well logging value in the oil reservoir to be measured, and NF represents the fluid neutron well logging in the oil reservoir to be measured
Value, VSH represent the shale content of the oil reservoir to be measured.
Further, the parameter determination module determine according to the following equation fluid in the oil reservoir to be measured apparent density and
Depending on interval transit time：
DFA=DMA- (DMA-DEN) * (NF-NMA)/(CNL-NMA)
TFA=TMA+ (DT-TMA) * (NF-NMA)/(CP* (CNL-NMA))
Wherein, DFA represents the apparent density of fluid in the oil reservoir to be measured, and TFA represents regarding for fluid in the oil reservoir to be measured
Interval transit time.
Therefore, interval transit time used in this application, density, neutron well logging curve are capable of the class of comprehensive distinguishing fluid
Type, not only can effectively recognize oil reservoir and water layer or gas-bearing formation and water layer, at the same conventional oil reservoir, high gas-oil ratio (HGOR) oil reservoir can be distinguished with
And gas reservoir, and when high gas-oil ratio (HGOR) oil reservoir and gas reservoir is recognized, as the interval transit time for having used investigation depth deeper is surveyed simultaneously
Well curve, can at utmost reduce the calculation error caused because of factors such as slurry compounding, Damintuns so that fluid type is recognized
Result it is more accurate.Comparing is had more preferably come the method for calculating gas-bearing formation " excavation effect " using density, neutron well logging curve merely
Effect.
With reference to explanation hereinafter and accompanying drawing, the particular implementation of the application is disclose in detail, the original of the application is specified
Reason can be in adopted mode.It should be understood that presently filed embodiment is not so limited in scope.In appended power
In the range of the spirit and terms that profit is required, presently filed embodiment includes many changes, modifications and equivalent.
The feature for describing for a kind of embodiment and/or illustrating can be in same or similar mode one or more
It is used in individual other embodiment, combined with the feature in other embodiment, or substitute the feature in other embodiment.
It should be emphasized that term "comprises/comprising" refers to the presence of feature, one integral piece, step or component when using herein, but and
It is not excluded for the presence of one or more further features, one integral piece, step or component or additional.
Description of the drawings
Included accompanying drawing is used for providing being further understood from the application embodiment, which constitutes the one of description
Part, for illustrating presently filed embodiment, and comes together to explain the principle of the application with word description.It should be evident that
Drawings in the following description are only some embodiments of the application, for those of ordinary skill in the art, are not being paid
On the premise of going out creative labor, can be with according to these other accompanying drawings of accompanying drawings acquisition.In the accompanying drawings：
A kind of recognition methodss flow chart of reservoir fluid type that Fig. 1 is provided for the application embodiment；
A kind of functional block diagram of the identifying device of reservoir fluid type that Fig. 2 is provided for the application embodiment.
Specific embodiment
In order that those skilled in the art more fully understand the technical scheme in the application, below in conjunction with the application reality
The accompanying drawing in mode is applied, the technical scheme in the application embodiment is clearly and completely described, it is clear that described
Embodiment is only a part of embodiment of the application, rather than the embodiment of whole.Based on the embodiment party in the application
Formula, all other embodiment that those of ordinary skill in the art are obtained under the premise of creative work is not made, all answers
When the scope for belonging to the application protection.
Fig. 1 is referred to, the application embodiment provides a kind of recognition methodss of reservoir fluid type, and methods described can be wrapped
Include following steps.
Step S1：Density log curve, acoustic travel time logging curve and neutron well logging curve according to oil reservoir to be measured, really
Determine the apparent density of fluid in the oil reservoir to be measured and regard interval transit time.
In the present embodiment, it is contemplated that if carrying out fluid class only with the shallower density log curve of investigation depth
The identification of type, is easily affected by factors such as slurry compounding, Damintuns.Therefore, in the present embodiment, can adopt simultaneously
Be identified come convection cell type with the deeper acoustic travel time logging curve of investigation depth such that it is able to reduce because slurry compounding,
The error that the factors such as Damintun are caused.
In the present embodiment, in order to exactly by density and interval transit time predicting fluid in oil reservoir to be measured
Type, it may be determined that in the oil reservoir to be measured the apparent density of fluid and regard interval transit time.In the present embodiment, the apparent density
With disclosure satisfy that depending on interval transit time：In water layer, apparent density is 1g/ml, regards interval transit time as 180us/ft；When containing in reservoir
During oil gas, apparent density can be less than 1g/ml, can be more than 180us/ft depending on interval transit time.With in reservoir oil lighten or
Air content increases, and apparent density can reduce, and can increase depending on interval transit time.
In the present embodiment, can determine that the density log curve of the oil reservoir to be measured, interval transit time are surveyed first respectively
Well curve and each self-corresponding porosity curve of neutron well logging curve, every porosity curve are right in the reservoir of different content
The variation tendency answered is often also different.In the present embodiment, the density log curve, sound can be determined according to the following equation
Ripple time difference log and each self-corresponding porosity curve of neutron well logging curve：
POR_DEN=(DEN-DMA)/(DF-DMA) × (1-VSH)
POR_DT=(DT-TMA)/(CP* (TF-TMA)) × (1-VSH)
POR_CN=(CNL-NMA)/(NF-NMA) × (1-VSH)
Wherein, POR_DEN represents the corresponding porosity curve of the density log curve, when POR_DT represents the sound wave
The corresponding porosity curve of difference log, POR_CN represent the corresponding porosity curve of the neutron well logging curve, and DEN is represented
The density of the oil reservoir to be measured, DMA table show the skeletal density in the oil reservoir to be measured, and DF represents the fluid in the oil reservoir to be measured
Density, DT represent the sound wave value of the oil reservoir to be measured, and TMA represents the skeleton sound wave value in the oil reservoir to be measured, and CP represents sound wave
Time difference compacting factor, TF represent the fluid acoustic value in the oil reservoir to be measured, and CNL represents the neutron well logging of the oil reservoir to be measured
Value, NMA represent the skeleton neutron well logging value in the oil reservoir to be measured, and NF represents the fluid neutron well logging in the oil reservoir to be measured
Value, VSH represent the shale content of the oil reservoir to be measured.
In pure water layer, three porosity curve values are identical；When oil gas is contained in reservoir, relative to pure water layer, POR_
DEN increases, POR_DT increases, and POR_CN values reduce.
In the present embodiment, it is possible to use POR_CN replaces POR_DEN and POR_DT, such that it is able to be based on described in three
Porosity curve, determines the apparent density of fluid in the oil reservoir to be measured and regards interval transit time.Specifically, can be according to the following equation
Determine the apparent density of fluid in the oil reservoir to be measured and regard interval transit time：
DFA=DMA- (DMA-DEN) * (NF-NMA)/(CNL-NMA)
TFA=TMA+ (DT-TMA) * (NF-NMA)/(CP* (CNL-NMA))
Wherein, DFA represents the apparent density of fluid in the oil reservoir to be measured, and TFA represents regarding for fluid in the oil reservoir to be measured
Interval transit time.
So, the apparent density that obtains according to both the above formula and interval transit time is regarded, is disclosure satisfy that：In water layer, DFA is
1g/ml, TFA are 180us/ft；When oil gas is contained in reservoir, DFA values are less than 1g/ml, and TFA values are more than 180us/ft；With
In reservoir, oil lightens or air content increases, and DFA values reduce, and the increase of TFA values.
Step S2：According to the apparent density of fluid in the oil reservoir to be measured, determine that first of fluid in the oil reservoir to be measured is oily
Gas detection curve；According in the oil reservoir to be measured fluid regarding interval transit time, determine that second of fluid in the oil reservoir to be measured is oily
Gas detection curve.
In the present embodiment, the apparent density and depending on interval transit time be fluid type identification basis.Treated based on described
Survey in oil reservoir the apparent density of fluid and regard interval transit time, it may be determined that a plurality of oil and gas detection of fluid is bent in the oil reservoir to be measured
Line.Wherein, the first oil and gas detection curve can be produced by apparent density, and so, the first oil and gas detection curve just can be by
The density log curve and the neutron well logging curve determine.Second oil and gas detection curve can be by producing regarding interval transit time
Raw, so, the second oil and gas detection curve just can be true by the acoustic travel time logging curve and the neutron well logging curve
It is fixed.
Specifically, the first oil gas of fluid in the oil reservoir to be measured can be determined in the present embodiment according to the following equation
Detection curve and the second oil and gas detection curve：
HYC_DEN=1-DFA
HYC_DT=TFA/180-1
Wherein, HYC_DEN represents the first oil and gas detection curve, and HYC_DT represents the second oil and gas detection curve.
In the present embodiment, HYC_DEN is Application density, the oil and gas detection curve of two logs calculating of neutron.
It is, with the density of water as standard, fluid type in reservoir to be judged.HYC_DEN values are less, represent that fluid density is bigger；
HYC_DEN is bigger, represents that oily lighter or air content is higher；Density detection scope is shallower, and the identification to oil gas is more sensitive.
HYC_DT is the oil and gas detection curve calculated using interval transit time, two logs of neutron.It is the sound with water
The ripple time difference is standard, and the fluid type in reservoir is judged.Equally, HYC_DT values are less, represent that fluid density is bigger；
HYC_DT is bigger, represents that oily lighter or air content is higher；Due to the investigative range of acoustic travel time logging it is larger, therefore HYC_DT
Affected less by factors such as slurry compounding, Damintuns, result of calculation is more reliable.
Step S3：According to the first oil and gas detection curve and the second oil and gas detection curve, determine that the 3rd oil gas is examined
Survey curve.
In the present embodiment, for this three logs of integrated application interval transit time, density and neutron carrying out
First oil and gas detection curve and the second oil and gas detection curve can be combined by oil and gas detection, so as to generate the inspection of the 3rd oil gas
Survey curve.Specifically, the 3rd oil and gas detection curve can be determined in the present embodiment according to the following equation：
HYCI=HYC_DEN+HYC_DT
Wherein, HYCI represents the 3rd oil and gas detection curve.
From above formula, HYCI is integrated application interval transit time, density, three logs of neutron carry out oil and gas detection
As a result.When high gas-oil ratio (HGOR) oil reservoir or gas reservoir is recognized, the abnormal signal of Gas content is effectively exaggerated, light oil or gas-bearing formation is made
Recognition effect is more accurate.
Step S4：Based on the apparent density, regarding interval transit time, the first oil and gas detection curve, the second oil and gas detection curve with
And the 3rd each residing numerical intervals of oil and gas detection curve, determine the type of fluid in the oil reservoir to be measured.
In the present embodiment, different fluid type, its corresponding apparent density, regarding interval transit time, the first oil and gas detection
Curve, the second oil and gas detection curve and the 3rd oil and gas detection curve may be at different numerical intervals, so, according to each
Interval residing for individual parameter values, just can determine the particular type of fluid.
In a concrete application scene, in 3276～3350 meters of well sections in oil field, according to the result of calculation of the application, stream
The apparent density DFA convergence 1g/ml of body, is close to 180us/ft depending on interval transit time；Three oil and gas detection curve HYCI, HYC_DEN,
HYC_DT illustrates do not have oil gas all close to 0, and the integrated interpretation well section is water layer.
In another concrete application scene, in 3040～3100 meters of well sections in oil field, according to the result of calculation of the application,
DFA values are between 0.6～1g/ml；TFA values are between 180～230us/ft；HYC_DEN values are 0.2～0.3；HYC_DT values are
0.1～0.2；HYCI values are 0.2～0.4, and these numerical value meet conventional reservoir characteristics, and the integrated interpretation well section is conventional oil reservoir.
In another concrete application scene, in 2839～2867 meters of well sections in oil field.According to the application result of calculation,
DFA values lowest point has reached 0.067g/ml；TFA values have been up to 320us/ft；HYC_DEN values are 1 to the maximum；HYC_DT values
It is 0.8 to the maximum；HYCI values are up to 1.7.These numerical value have obvious high gas-oil ratio (HGOR) characteristics of reservoirs, and the integrated interpretation well section is height
Gas-oil ratio oil reservoir.
The application also provides a kind of identifying device of reservoir fluid type.Fig. 2 is referred to, described device can include：
Fluid parameter determining unit 100, for the density log curve according to oil reservoir to be measured, acoustic travel time logging curve with
And neutron well logging curve, determine the apparent density of fluid in the oil reservoir to be measured and regard interval transit time；
Oil and gas detection curve determining unit 200, for the apparent density according to fluid in the oil reservoir to be measured, it is determined that described treat
Survey the first oil and gas detection curve of fluid in oil reservoir；According in the oil reservoir to be measured fluid regarding interval transit time, it is determined that described treat
Survey the second oil and gas detection curve of fluid in oil reservoir；It is bent according to the first oil and gas detection curve and second oil and gas detection
Line, determines the 3rd oil and gas detection curve；
Fluid type determining unit 300, for based on the apparent density, regarding interval transit time, the first oil and gas detection curve, the
The each residing numerical intervals of two oil and gas detection curves and the 3rd oil and gas detection curve, determine fluid in the oil reservoir to be measured
Type.
In one embodiment of the application, the fluid parameter determining unit 100 is specifically included：
Porosity curve determining module, for determining that the density log curve of the oil reservoir to be measured, interval transit time are surveyed respectively
Well curve and each self-corresponding porosity curve of neutron well logging curve；
Parameter determination module, for based on three porosity curves, determine fluid in the oil reservoir to be measured regarding close
Spend and regard interval transit time.
In one embodiment of the application, the porosity curve determining module determines the density according to the following equation
The each self-corresponding porosity curve of log, acoustic travel time logging curve and neutron well logging curve：
POR_DEN=(DEN-DMA)/(DF-DMA) × (1-VSH)
POR_DT=(DT-TMA)/(CP* (TF-TMA)) × (1-VSH)
POR_CN=(CNL-NMA)/(NF-NMA) × (1-VSH)
Wherein, POR_DEN represents the corresponding porosity curve of the density log curve, when POR_DT represents the sound wave
The corresponding porosity curve of difference log, POR_CN represent the corresponding porosity curve of the neutron well logging curve, and DEN is represented
The density of the oil reservoir to be measured, DMA table show the skeletal density in the oil reservoir to be measured, and DF represents the fluid in the oil reservoir to be measured
Density, DT represent the sound wave value of the oil reservoir to be measured, and TMA represents the skeleton sound wave value in the oil reservoir to be measured, and CP represents sound wave
Time difference compacting factor, TF represent the fluid acoustic value in the oil reservoir to be measured, and CNL represents the neutron well logging of the oil reservoir to be measured
Value, NMA represent the skeleton neutron well logging value in the oil reservoir to be measured, and NF represents the fluid neutron well logging in the oil reservoir to be measured
Value, VSH represent the shale content of the oil reservoir to be measured.
In one embodiment of the application, during the parameter determination module determines the oil reservoir to be measured according to the following equation
The apparent density of fluid and regard interval transit time：
DFA=DMA- (DMA-DEN) * (NF-NMA)/(CNL-NMA)
TFA=TMA+ (DT-TMA) * (NF-NMA)/(CP* (CNL-NMA))
Wherein, DFA represents the apparent density of fluid in the oil reservoir to be measured, and TFA represents regarding for fluid in the oil reservoir to be measured
Interval transit time.
It should be noted that the specific implementation of above-mentioned each functional module and the description in the application step S1 to S4
Unanimously, just repeat no more here.
Therefore, interval transit time used in this application, density, neutron well logging curve are capable of the class of comprehensive distinguishing fluid
Type, not only can effectively recognize oil reservoir and water layer or gas-bearing formation and water layer, at the same conventional oil reservoir, high gas-oil ratio (HGOR) oil reservoir can be distinguished with
And gas reservoir, and when high gas-oil ratio (HGOR) oil reservoir and gas reservoir is recognized, as the interval transit time for having used investigation depth deeper is surveyed simultaneously
Well curve, can at utmost reduce the calculation error caused because of factors such as slurry compounding, Damintuns so that fluid type is recognized
Result it is more accurate.Comparing is had more preferably come the method for calculating gas-bearing formation " excavation effect " using density, neutron well logging curve merely
Effect.
Description to the various embodiments of the application above is supplied to those skilled in the art with the purpose for describing.Which is not
Be intended to exhaustion or be not intended to limit the invention to single disclosed embodiment.As described above, the application's is various
Substitute and change is will be apparent for above-mentioned technology one of ordinary skill in the art.Therefore, although specifically beg for
The embodiment of some alternatives is discussed, but other embodiment will be apparent, or those skilled in the art are relative
Easily draw.The application is intended to be included in all replacements, modification and the change of this present invention for having discussed, and falls
Other embodiment in the spirit and scope of above-mentioned application.
Each embodiment in this specification is described by the way of progressive, identical similar between each embodiment
Part mutually referring to what each embodiment was stressed is the difference with other embodiment.Especially, it is right
For device embodiments, as which is substantially similar to method embodiment, so description is fairly simple, related part ginseng
The part explanation of square method embodiment.
Although depicting the application by embodiment, it will be appreciated by the skilled addressee that the application has many deformations
With change without deviating from spirit herein, it is desirable to which appended claim includes these deformations and changes without deviating from the application
Spirit.
Claims (10)
1. a kind of recognition methodss of reservoir fluid type, it is characterised in that methods described includes：
Density log curve, acoustic travel time logging curve and neutron well logging curve according to oil reservoir to be measured, determines described to be measured
In oil reservoir the apparent density of fluid and regard interval transit time；
According to the apparent density of fluid in the oil reservoir to be measured, the first oil and gas detection curve of fluid in the oil reservoir to be measured is determined；
According in the oil reservoir to be measured fluid regarding interval transit time, determine the second oil and gas detection curve of fluid in the oil reservoir to be measured；
According to the first oil and gas detection curve and the second oil and gas detection curve, the 3rd oil and gas detection curve is determined；
Examine based on the apparent density, regarding interval transit time, the first oil and gas detection curve, the second oil and gas detection curve and the 3rd oil gas
The each residing numerical intervals of curve are surveyed, the type of fluid in the oil reservoir to be measured is determined.
2. method according to claim 1, it is characterised in that the density log curve, interval transit time according to oil reservoir to be measured
Log and neutron well logging curve, determine the apparent density of fluid in the oil reservoir to be measured and specifically include depending on interval transit time：
Determine that density log curve, acoustic travel time logging curve and the neutron well logging curve of the oil reservoir to be measured are each right respectively
The porosity curve answered；
Based on three porosity curves, determine the apparent density of fluid in the oil reservoir to be measured and regard interval transit time.
3. method according to claim 2, it is characterised in that determine the density log curve, sound according to the following equation
Ripple time difference log and each self-corresponding porosity curve of neutron well logging curve：
POR_DEN=(DEN-DMA)/(DF-DMA) × (1-VSH)
POR_DT=(DT-TMA)/(CP* (TF-TMA)) × (1-VSH)
POR_CN=(CNL-NMA)/(NF-NMA) × (1-VSH)
Wherein, POR_DEN represents the corresponding porosity curve of the density log curve, and POR_DT represents that the interval transit time is surveyed
The corresponding porosity curve of well curve, POR_CN represent the corresponding porosity curve of the neutron well logging curve, and DEN represents described
The density of oil reservoir to be measured, DMA table show the skeletal density in the oil reservoir to be measured, and DF represents that the fluid in the oil reservoir to be measured is close
Degree, DT represent the sound wave value of the oil reservoir to be measured, and TMA represents the skeleton sound wave value in the oil reservoir to be measured, when CP represents sound wave
Differential pressure real coefficient, TF represent the fluid acoustic value in the oil reservoir to be measured, and CNL represents the neutron well logging value of the oil reservoir to be measured,
NMA represents the skeleton neutron well logging value in the oil reservoir to be measured, and NF represents the fluid neutron well logging value in the oil reservoir to be measured,
VSH represents the shale content of the oil reservoir to be measured.
4. method according to claim 3, it is characterised in that determine fluid in the oil reservoir to be measured according to the following equation
Apparent density and regard interval transit time：
DFA=DMA- (DMA-DEN) * (NF-NMA)/(CNL-NMA)
TFA=TMA+ (DT-TMA) * (NF-NMA)/(CP* (CNL-NMA))
Wherein, DFA represents the apparent density of fluid in the oil reservoir to be measured, TFA represent fluid in the oil reservoir to be measured regarding sound wave
The time difference.
5. method according to claim 4, it is characterised in that determine fluid in the oil reservoir to be measured according to the following equation
First oil and gas detection curve and the second oil and gas detection curve：
HYC_DEN=1-DFA
HYC_DT=TFA/180-1
Wherein, HYC_DEN represents the first oil and gas detection curve, and HYC_DT represents the second oil and gas detection curve.
6. method according to claim 5, it is characterised in that determine the 3rd oil and gas detection curve according to the following equation：
HYCI=HYC_DEN+HYC_DT
Wherein, HYCI represents the 3rd oil and gas detection curve.
7. a kind of identifying device of reservoir fluid type, it is characterised in that described device includes：
Fluid parameter determining unit, for the density log curve according to oil reservoir to be measured, acoustic travel time logging curve and neutron
Log, determines the apparent density of fluid in the oil reservoir to be measured and regards interval transit time；
Oil and gas detection curve determining unit, for the apparent density according to fluid in the oil reservoir to be measured, determines the oil reservoir to be measured
First oil and gas detection curve of middle fluid；According in the oil reservoir to be measured fluid regarding interval transit time, determine the oil reservoir to be measured
Second oil and gas detection curve of middle fluid；According to the first oil and gas detection curve and the second oil and gas detection curve, it is determined that
3rd oil and gas detection curve；
Fluid type determining unit, for based on the apparent density, regarding interval transit time, the first oil and gas detection curve, the second oil gas
The each residing numerical intervals of detection curve and the 3rd oil and gas detection curve, determine the type of fluid in the oil reservoir to be measured.
8. device according to claim 7, it is characterised in that the fluid parameter determining unit is specifically included：
Porosity curve determining module, density log curve, the acoustic travel time logging for determining the oil reservoir to be measured respectively are bent
Line and each self-corresponding porosity curve of neutron well logging curve；
Parameter determination module, for based on three porosity curves, determine fluid in the oil reservoir to be measured apparent density and
Depending on interval transit time.
9. device according to claim 8, it is characterised in that the porosity curve determining module is true according to the following equation
The each self-corresponding porosity curve of the fixed density log curve, acoustic travel time logging curve and neutron well logging curve：
POR_DEN=(DEN-DMA)/(DF-DMA) × (1-VSH)
POR_DT=(DT-TMA)/(CP* (TF-TMA)) × (1-VSH)
POR_CN=(CNL-NMA)/(NF-NMA) × (1-VSH)
Wherein, POR_DEN represents the corresponding porosity curve of the density log curve, and POR_DT represents that the interval transit time is surveyed
The corresponding porosity curve of well curve, POR_CN represent the corresponding porosity curve of the neutron well logging curve, and DEN represents described
The density of oil reservoir to be measured, DMA table show the skeletal density in the oil reservoir to be measured, and DF represents that the fluid in the oil reservoir to be measured is close
Degree, DT represent the sound wave value of the oil reservoir to be measured, and TMA represents the skeleton sound wave value in the oil reservoir to be measured, when CP represents sound wave
Differential pressure real coefficient, TF represent the fluid acoustic value in the oil reservoir to be measured, and CNL represents the neutron well logging value of the oil reservoir to be measured,
NMA represents the skeleton neutron well logging value in the oil reservoir to be measured, and NF represents the fluid neutron well logging value in the oil reservoir to be measured,
VSH represents the shale content of the oil reservoir to be measured.
10. device according to claim 9, it is characterised in that the parameter determination module determines institute according to the following equation
State the apparent density of fluid in oil reservoir to be measured and regard interval transit time：
DFA=DMA- (DMA-DEN) * (NF-NMA)/(CNL-NMA)
TFA=TMA+ (DT-TMA) * (NF-NMA)/(CP* (CNL-NMA))
Wherein, DFA represents the apparent density of fluid in the oil reservoir to be measured, TFA represent fluid in the oil reservoir to be measured regarding sound wave
The time difference.
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Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108518220A (en) * | 2018-02-26 | 2018-09-11 | 中国石油大学(北京) | The method and apparatus of reservoir fluid is identified based on integrated fluid discrimination index |
| CN111812736A (en) * | 2020-07-22 | 2020-10-23 | 西南石油大学 | Method for evaluating gas content of compact sandstone anhydrous gas reservoir |
| CN114086939A (en) * | 2021-10-27 | 2022-02-25 | 中国石油天然气股份有限公司 | Oil gas quantitative identification method and system for complex fault block oil gas reservoir |
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2016
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108518220A (en) * | 2018-02-26 | 2018-09-11 | 中国石油大学(北京) | The method and apparatus of reservoir fluid is identified based on integrated fluid discrimination index |
| CN108518220B (en) * | 2018-02-26 | 2020-06-09 | 中国石油大学(北京) | Method and device for identifying reservoir fluid based on comprehensive fluid identification index |
| CN111812736A (en) * | 2020-07-22 | 2020-10-23 | 西南石油大学 | Method for evaluating gas content of compact sandstone anhydrous gas reservoir |
| CN111812736B (en) * | 2020-07-22 | 2021-03-16 | 西南石油大学 | Method for evaluating gas content of compact sandstone anhydrous gas reservoir |
| CN114086939A (en) * | 2021-10-27 | 2022-02-25 | 中国石油天然气股份有限公司 | Oil gas quantitative identification method and system for complex fault block oil gas reservoir |
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