CN109283597A - A kind of carbonate formation overpressure prediction method - Google Patents
A kind of carbonate formation overpressure prediction method Download PDFInfo
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Abstract
The present invention provides a kind of carbonate formation overpressure prediction method, method includes: to obtain Basic Physical Properties parameter for carbonate formation selection oil gas water comprehensive log interpretation model；Then Rock Matrix bulk modulus is calculated using Voigt-Reuss-Hill average modulus model, calculates pore-fluid bulk modulus using Wood model or Patchy model, calculate rock matrix bulk modulus using BISQ model；Quantify model prediction superpressure finally by poroelasticity mechanics.The beneficial effects of the present invention are: technical solution provided by the present invention proposes a kind of new overpressure prediction method for carbonate formation, it solves that carbonate rock is fine and close and extremely uneven bring overpressure prediction is difficult to a certain extent, there is industrial application value.
Description
Technical field
The present invention relates to geological exploration field more particularly to a kind of carbonate formation overpressure prediction methods.
Background technique
The existing a large amount of research of overpressure genesis and common recognition, superpressure in oil-gas bearing basin can be by various physics and chemical mistake
Journey generates, and low compaction and later compression etc. are directly changed effective stress；Hydrocarbon, clay mineral dehydration, hydrocarbon cracking
Increase Deng newborn pore-fluid volume；Buoyancy and the effect of fluid flow boost etc..The genesis mechanism of extensive abnormal high pressure is substantially
Can be divided into three classes: undercompaction pressurization (formation compaction is uneven), hydrocarbon pressurization and construction squeeze pressurization etc..Superpressure may cause well
Various engineerings safety problem, the overpressure predictions such as spray, borehole well instability, borehole washout and circulation of drilling fluid leakage are studied to drilling engineering
Safety and its cost-effectiveness are most important.Formation overpressure has important shadow to conventional and unconventional oil and gas development as natural production capacity
Loud and reservoir modeling and numerical simulation for oil-gas reservoir important parameter.
Clastic Stratum of Country Rocks overpressure prediction method mainly analysis well logging, seismic response parameter on the basis of, in conjunction with
The empirical method that Terzaghi effective stress theory proposes.Taizaghi effective stress theoretical description soil is answered in upper cover
Compacting process under the action of power is more applicable in for the clastic rock with certain Compaction Law, but is not suitable for diagenesis
Chemical compaction acts on significant carbonate formation in the process.
It is raw after in carbonate formation deposition process that strong (recrystallization, dolomitization, corrosion) is transformed,
Original pore structure characteristic is caused to change significant, rock composition and lithology are also multiple chemical reaction superposition as a result, this rock
Property and the multiple heterogeneity of physical property make carbonate rock overpressure prediction be still domestic and international still unsolved research puzzle.
Summary of the invention
To solve the above-mentioned problems, the present invention provides a kind of carbonate formation overpressure prediction method, equipment and storages
A kind of equipment, carbonate formation overpressure prediction method, mainly comprises the steps that
S101: according to carbonate reservoir physical property means of interpretation, Predicting Carbonate Formation is treated using well-log information
Basic Physical Properties parameter explains, and obtains the Basic Physical Properties parameter of carbonate formation to be predicted；The Basic Physical Properties parameter packet
It includes: the rock shale mineral content V of carbonate formation to be predictedsh, each mineral composition volume content Vi, matrix porosity
φsWith rock fracture porosity φc；
S102: according to the rock shale mineral content V of carbonate formation to be predictedshWith each mineral composition volume content
Vi, using Voigt-Reuss-Hill average modulus model, the Rock Matrix volume of carbonate formation to be predicted is calculated
Modulus Ks；
S103: Wood model or Patchy model are used, the pore-fluid of carbonate formation to be predicted is calculated
Bulk modulus Kf；
S104: BISQ model is used, the rock matrix bulk modulus K of carbonate formation to be predicted is calculatedd；
S105: according to rock porosity φ, Rock Matrix bulk modulus Ks, pore-fluid bulk modulus KfAnd rock matrix
Bulk modulus Kd, using poroelasticity mechanics quantitative model, calculate the overpressure prediction value p for obtaining carbonate formation to be predicted；
Wherein, rock porosity φ is matrix porosity φsWith rock fracture porosity φcSum.
Further, in step S101, according to carbonate reservoir physical property means of interpretation, using well-log information to be predicted
The Basic Physical Properties parameter of carbonate formation explains, and obtains the step of the Basic Physical Properties parameter of carbonate formation to be predicted
Suddenly, comprising:
S201: obtaining the logging data and log data of carbonate reservoir, and the log data includes acoustic logging number
According to, density log data, neutron well logging data and Electric Log Data；
S202: the rock shale mineral content V of carbonate reservoir is calculated using formula (1)sh:
In above formula, VshFor rock shale mineral content, GCUR is stratum constant, layer natural gamma rays intensity for the purpose of SH
Index；
S203: according to the drilling fluid filtrate conductivity in logging data, carbonate rock is calculated using Archie formula
The rock fracture porosity φ of reservoirc, shown in calculation formula such as formula (2):
In above formula, φcFor rock fracture porosity, σLLDAnd σLLSRespectively deep lateral conductivity rate and shallow lateral conductivity rate,
It is the inverse of Electric Log Data, σmfAnd σwRespectively drilling fluid filtrate conductivity and stratum water conductivity are well logging number
According to,mfIt is priori value for the porosity exponent in crack；
S204: according to rock shale mineral content VshWith rock fracture porosity φc, mould is balanced using macroscopical rock volume
The matrix porosity φ of carbonate reservoir is calculated in typesWith mineral composition volume content each in carbonate reservoir
Vi, shown in calculation formula such as formula (3):
In above formula, φsFor matrix porosity, ViFor i-th kind of mineral volume content, Δ tf、Δtsh、ΔtimaWith Δ t
Interval transit time value respectively in fluid time difference value, shale time difference value, i-th kind of mineral time difference value and sound wave measuring well curve；ρf、
ρsh、ρimaWith the density value that ρ is respectively in fluid density value, shale density value, i-th kind of mineral density value and density log data；
CNLf、CNLsh、CNLimaIt is respectively subvalue in fluid, subvalue in shale, subvalue and neutron well logging data in i-th kind of mineral with CNL
In middle subvalue；Wherein Δ t, ρ and CNL is respectively the log data of acoustic logging, density log, neutron well logging, Δ tf、Δ
tsh、Δtima、ρf、ρsh、ρima、CNLf、CNLshAnd CNLimaFor priori value；I=1,2,3 ..., N, N are in carbonate reservoir
Mineral species quantity；
S205: by matrix porosity φs, rock fracture porosity φcWith each mineral composition volume content Vi, as
Final carbonate reservoir physical property explanation results.
Further, in step S202, shown in the calculation formula of SH such as formula (4):
In above formula, GRmaxAnd GRminRespectively gamma ray curve maximum and minimum, GR be target zone containing shale from
Right gamma reading, is gamma ray log data；GRmax、GRminFor priori value.
Further, in step S202, the value of stratum constant GCUR is 2.
Further, in step S204, carbonate rock Minerals content includes: shale content, calcite content, dolomite
Content mixing paste salt content；In situation known to shale content, ViRespectively indicate three kinds of mineral contents: calcite content V1, white clouds
Stone content V2Mixing paste salt content V3,；Steps are as follows for the calculating of macroscopical rock volume balance model:
S301: the unknown number number nonsingular linear equal with equation number is obtained by formula (3) arrangement and just determines equation group；Institute
Stating unknown number includes: φs、V1、V2And V3；
S302: an initial value close to solution is searched for by particle swarm algorithm；
S303: according to initial value, matrix porosity φ is obtained using Nonlinear Constrained Optimization MethodsAnd V1、V2、V3's
Exact Solutions.
Further, in step S102, according to the rock shale mineral content V of carbonate formation to be predictedshWith each mine
Object forms volume content Vi, using Voigt-Reuss-Hill average modulus model, calculate the rock of carbonate formation to be predicted
Ground mass matter bulk modulus KsCalculation formula such as formula (5) shown in:
In above formula, MiIt is priori value for each mineralogical composition concrete moduli；I=1,2 ..., N, N be to
The mineral species quantity contained in Predicting Carbonate Formation, wherein f2、f3And f4Respectively represent limestone, dolomite and gypsum-salt rock
Volume content.
Further, in step S103, the pore-fluid bulk modulus K of carbonate formation to be predicted is calculatedfCalculating
Shown in formula such as formula (6):
In above formula, KiIt is priori value for mixture fluid component volume modulus each in carbonate formation to be predicted；xiFor
Each section percentage by volume of the n kind component of composition mixture fluid, calculation formula are as follows:M, n, a, b are rock
Electrical parameter is priori value；RtIt is log data for true formation resistivity curve；RiIt is logging data for formation water resistivity；i
=1,2 ..., n.
Further, in step S105, according to rock porosity φ, Rock Matrix bulk modulus Ks, pore-fluid volume
Modulus KfWith rock matrix bulk modulus Kd, calculate the calculation formula of the overpressure prediction value p of acquisition carbonate formation to be predicted such as
Shown in formula (7):
In above formula,It is priori value for mean principle stress；β is the empirical parameter coefficient of dimensionless, is priori value；A is multiple
Close elasticity modulus group item；φ=φs+φc。
Technical solution provided by the invention has the benefit that technical solution provided by the present invention for carbonate
Rock stratum proposes a kind of new overpressure prediction method, and it is fine and close and extremely unevenly bring to solve carbonate rock to a certain extent
Overpressure prediction it is difficult, there is certain industrial application value.
Detailed description of the invention
Present invention will be further explained below with reference to the attached drawings and examples, in attached drawing:
Fig. 1 is a kind of flow chart of carbonate formation overpressure prediction method in the embodiment of the present invention；
Fig. 2 is the schematic diagram of 1 well carbonate rock interval well-log information overpressure prediction result of double mausoleums in the embodiment of the present invention.
Specific embodiment
For a clearer understanding of the technical characteristics, objects and effects of the present invention, now control attached drawing is described in detail
A specific embodiment of the invention.
The embodiment provides a kind of carbonate formation overpressure prediction methods.
Referring to FIG. 1, Fig. 1 is a kind of flow chart of carbonate formation overpressure prediction method in the embodiment of the present invention, tool
Body includes the following steps:
S101: according to carbonate reservoir physical property means of interpretation, Predicting Carbonate Formation is treated using well-log information
Basic Physical Properties parameter explains, and obtains the Basic Physical Properties parameter of carbonate formation to be predicted；The Basic Physical Properties parameter packet
It includes: the rock shale mineral content V of carbonate formation to be predictedsh, each mineral composition volume content Vi, matrix porosity
φsWith rock fracture porosity φc；
S102: according to the rock shale mineral content V of carbonate formation to be predictedshWith each mineral composition volume content
Vi, using Voigt-Reuss-Hill average modulus model, the Rock Matrix volume of carbonate formation to be predicted is calculated
Modulus Ks；
S103: Wood model or Patchy model are used, the pore-fluid of carbonate formation to be predicted is calculated
Bulk modulus Kf；
S104: BISQ model is used, the rock matrix bulk modulus K of carbonate formation to be predicted is calculatedd；(tool
Body method is shown in document: Dvorkin J., Nur A.Dynamic poroelasticity:A unified model with the
Squirt and the Biot mechanisms [J] .Geophysics, 1993,58 (4): 524-533. and Mavko G.,
Mukerji T.,Dvorkin J.The rock physics handbook:tools for seismic analysis of
porous media[M].New York:Cambridge University Press,2009.)；
S105: according to rock porosity φ, Rock Matrix bulk modulus Ks, pore-fluid bulk modulus KfAnd rock matrix
Bulk modulus Kd, using poroelasticity mechanics quantitative model, calculate the overpressure prediction value p for obtaining carbonate formation to be predicted；
Wherein, rock porosity φ is matrix porosity φsWith rock fracture porosity φcSum.
In step S101, according to carbonate reservoir physical property means of interpretation, using well-log information to carbonate rock to be predicted
The step of Basic Physical Properties parameter on stratum explains, and obtains the Basic Physical Properties parameter of carbonate formation to be predicted, comprising:
S201: obtaining the logging data and log data of carbonate reservoir, and the log data includes acoustic logging number
According to, density log data, neutron well logging data and Electric Log Data；
S202: the rock shale mineral content V of carbonate reservoir is calculated using formula (1)sh:
In above formula, VshFor rock shale mineral content, GCUR is stratum constant, layer natural gamma rays intensity for the purpose of SH
Index；
S203: according to the drilling fluid filtrate conductivity in logging data, carbonate rock is calculated using Archie formula
The rock fracture porosity φ of reservoirc, shown in calculation formula such as formula (2):
In above formula, φcFor rock fracture porosity, σLLDAnd σLLSRespectively deep lateral conductivity rate and shallow lateral conductivity rate,
It is the inverse of Electric Log Data, σmfAnd σwRespectively drilling fluid filtrate conductivity and stratum water conductivity are well logging number
According to,mfIt is priori value for the porosity exponent in crack；
S204: according to rock shale mineral content VshWith rock fracture porosity φc, mould is balanced using macroscopical rock volume
The matrix porosity φ of carbonate reservoir is calculated in typesWith mineral composition volume content each in carbonate reservoir
Vi, shown in calculation formula such as formula (3):
In above formula, φsFor matrix porosity, ViFor i-th kind of mineral volume content, Δ tf、Δtsh、ΔtimaWith Δ t
Interval transit time value respectively in fluid time difference value, shale time difference value, i-th kind of mineral time difference value and sound wave measuring well curve；ρf、
ρsh、ρimaWith the density value that ρ is respectively in fluid density value, shale density value, i-th kind of mineral density value and density log data；
CNLf、CNLsh、CNLimaIt is respectively subvalue in fluid, subvalue in shale, subvalue and neutron well logging data in i-th kind of mineral with CNL
In middle subvalue；Wherein Δ t, ρ and CNL is respectively the log data of acoustic logging, density log, neutron well logging, Δ tf、Δ
tsh、Δtima、ρf、ρsh、ρima、CNLf、CNLshAnd CNLimaFor priori value；I=1,2,3 ..., N, N are in carbonate reservoir
Mineral species quantity；
S205: by matrix porosity φs, rock fracture porosity φcWith each mineral composition volume content Vi, as
Final carbonate reservoir physical property explanation results.
In step S202, shown in the calculation formula of SH such as formula (4):
In above formula, GRmaxAnd GRminRespectively gamma ray curve maximum and minimum, GR be target zone containing shale from
Right gamma reading, is gamma ray log data；GRmax、GRminFor priori value.
In step S202, the value of stratum constant GCUR is 2.
In step S204, carbonate rock Minerals content includes: shale content, calcite content, dolomite content mixing paste
Salt content；In situation known to shale content, ViRespectively indicate three kinds of mineral contents: calcite content V1, dolomite content V2
Mixing paste salt content V3,；Steps are as follows for the calculating of macroscopical rock volume balance model:
S301: the unknown number number nonsingular linear equal with equation number is obtained by formula (3) arrangement and just determines equation group；Institute
Stating unknown number includes: φs、V1、V2And V3；
S302: an initial value close to solution is searched for by particle swarm algorithm；
S303: according to initial value, matrix porosity φ is obtained using Nonlinear Constrained Optimization MethodsAnd V1、V2、V3's
Exact Solutions.
In step S102, according to the rock shale mineral content V of carbonate formation to be predictedshWith each mineral composition volume
Content Vi, using Voigt-Reuss-Hill average modulus model, calculate the Rock Matrix volume of carbonate formation to be predicted
Modulus KsCalculation formula such as formula (5) shown in:
In above formula, MiIt is priori value for each mineralogical composition concrete moduli；I=1,2 ..., N, N be to
The mineral species quantity contained in Predicting Carbonate Formation, wherein f2、f3And f4Respectively represent limestone, dolomite and gypsum-salt rock
Volume content.
In step S103, the pore-fluid bulk modulus K of carbonate formation to be predicted is calculatedfCalculation formula such as formula
(6) shown in:
In above formula, KiIt is priori value for mixture fluid component volume modulus each in carbonate formation to be predicted；xiFor
Each section percentage by volume of the n kind component of composition mixture fluid, calculation formula are as follows:M, n, a, b are rock
Electrical parameter is priori value；RtIt is log data for true formation resistivity curve；RiIt is logging data for formation water resistivity；i
=1,2 ..., n.
In step S105, according to rock porosity φ, Rock Matrix bulk modulus Ks, pore-fluid bulk modulus KfAnd rock
Stone skeleton bulk modulus Kd, calculate calculation formula such as formula (7) institute for obtaining the overpressure prediction value p of carbonate formation to be predicted
Show:
In above formula,It is priori value for mean principle stress；β is the empirical parameter coefficient of dimensionless, is priori value；A is multiple
Close elasticity modulus group item；φ=φs+φc。
Since above-mentioned model and parameter are all the linear-elastic behaviors for characterizing porous media, practical rock often has
Viscoelasticity (Non-linear elastic property) and energy dissipation.And the constitutive relationship of stress-strain in the viscoelastic medium compares classical elastic
Constitutive relationship of stress-strain in medium is much more complex, and the usually not specific physical significance of multiple parameters, is difficult testing
With measurement in engineering and application.Therefore, because viscoelasticity theory phenomenological, generally solution be viscoelasticity is reduced to through
Allusion quotation Elasticity Problems are based on this thinking, and carbonate formation overpressure prediction theoretical model needs to consider viscoelasticity, but can lead to
Processing viscoelasticity challenge can be simplified by crossing the empirical parameter factor beta of introducing dimensionless, and then is obtained reality and be used to predict carbonic acid
The equation (7) of rock salt Formation overpressure.The empirical parameter factor beta of dimensionless can be regarded as correction coefficient related with viscoelasticity, should
The empirical parameter factor beta of dimensionless can be deposited using rock physical modeling experimental data, formation testing data, carbonate formation
The empirical acquisition of the data such as phase, lithology and physical property.
1 wells of double mausoleums are chosen in the application study of the embodiment of the present invention, and the well location is in Northeast Sichuan area NNE to hair dam-Shuan Miaochang
It structurally, is thunderbolt ways, Chialingchiang Formation, winged celestial pass group Marine source rock develop superpressure or the typical of strong superpressure is bored
Well utilizes log data, conventional logging (porosity, density, neutron, natural gamma, resistivity etc.) and full array sonic log
Etc. data predictions and simulations calculate the superpressure situation of carbonate rock interval, and compared with drilling rod observed pressure.
By extracting the well loggings ginsengs such as carbonate rock section well logging density, p-and s-wave velocity and well log interpretation physical properties of rock
Number, takes the average value of each parameter in different substratums in conjunction with logging data, utilizes Voigt-Reuss-Hill average modulus model side
Journey and Wood model equation calculate separately Rock Matrix bulk modulus and fluid modulus, calculate rock bone using BISQ model
Frame bulk modulus predicts pore pressure (Fig. 2) by hole amount of pressure model equation.It can be seen that by Fig. 2, table 1, predict hole
Pressure value and the pressure value of 6 drilling rod actual measurement depths are close, and relative error range is 2%~10%；Mud density conversion pressure
Power and with bore Sigma monitoring pressure trend substantially with prediction the variation of pore pressure high level it is consistent, prediction hole can be regarded as
The envelope of pressure high level, that is, mud density pressure can balance the high scope of Formation overpressure, illustrate the variation width for predicting pore pressure
Degree is closer to actual conditions.By Fig. 2 it is also seen that prediction pore pressure is jumped obviously with the amplitude of variation of depth, evaporite rock
Developing section superpressure significantly reduces, and limestone and the development of dolomite section superpressure, the prediction result may be reflected preferably and 1 well of double mausoleums
The characteristics of consistent superpressure of the multiple heterogeneity of carbonate rock interval frequently changes.
The error analysis table of 1 pair of mausoleum of table, 1 borehole logging tool data prediction superpressure and DST observed pressure
The beneficial effects of the present invention are: technical solution provided by the present invention proposed for carbonate formation it is a kind of new
Overpressure prediction method, solves that carbonate rock is fine and close and extremely uneven bring overpressure prediction is difficult, tool to a certain extent
There is certain industrial application value.
The foregoing is merely presently preferred embodiments of the present invention, is not intended to limit the invention, it is all in spirit of the invention and
Within principle, any modification, equivalent replacement, improvement and so on be should all be included in the protection scope of the present invention.
Claims (8)
1. a kind of carbonate formation overpressure prediction method, it is characterised in that: the following steps are included:
S101: according to carbonate reservoir physical property means of interpretation, the basis of Predicting Carbonate Formation is treated using well-log information
Physical parameter explains, and obtains the Basic Physical Properties parameter of carbonate formation to be predicted；The Basic Physical Properties parameter include: to
The rock shale mineral content V of Predicting Carbonate Formationsh, each mineral composition volume content Vi, matrix porosity φsWith
Rock fracture porosity φc；
S102: according to the rock shale mineral content V of carbonate formation to be predictedshWith each mineral composition volume content Vi, adopt
With Voigt-Reuss-Hill average modulus model, the Rock Matrix bulk modulus of carbonate formation to be predicted is calculated
Ks；
S103: Wood model or Patchy model are used, the pore-fluid volume of carbonate formation to be predicted is calculated
Modulus Kf；
S104: BISQ model is used, the rock matrix bulk modulus K of carbonate formation to be predicted is calculatedd；
S105: according to rock porosity φ, Rock Matrix bulk modulus Ks, pore-fluid bulk modulus KfWith rock matrix volume
Modulus Kd, using poroelasticity mechanics quantitative model, calculate the overpressure prediction value p for obtaining carbonate formation to be predicted；Wherein,
Rock porosity φ is matrix porosity φsWith rock fracture porosity φcSum.
2. a kind of carbonate formation overpressure prediction method as described in claim 1, it is characterised in that: in step S101, root
According to carbonate reservoir physical property means of interpretation, carried out using the Basic Physical Properties parameter that well-log information treats Predicting Carbonate Formation
The step of explaining, obtaining the Basic Physical Properties parameter of carbonate formation to be predicted, comprising:
S201: obtaining the logging data and log data of carbonate reservoir, and the log data includes sound wave measuring well curve, close
Spend log data, neutron well logging data and Electric Log Data；
S202: the rock shale mineral content V of carbonate reservoir is calculated using formula (1)sh:
In above formula, VshFor rock shale mineral content, GCUR is stratum constant, and layer natural gamma rays intensity refers to for the purpose of SH
Number；
S203: according to the drilling fluid filtrate conductivity in logging data, carbonate reservoir is calculated using Archie formula
Rock fracture porosity φc, shown in calculation formula such as formula (2):
In above formula, φcFor rock fracture porosity, σLLDAnd σLLSRespectively deep lateral conductivity rate and shallow lateral conductivity rate, are resistance
The inverse of rate log data, σmfAnd σwRespectively drilling fluid filtrate conductivity and stratum water conductivity are logging data,mfTo split
The porosity exponent of seam is priori value；
S204: according to rock shale mineral content VshWith rock fracture porosity φc, using macroscopical rock volume balance model,
The matrix porosity φ of carbonate reservoir is calculatedsWith mineral composition volume content V each in carbonate reservoiri, meter
It calculates shown in formula such as formula (3):
In above formula, φsFor matrix porosity, ViFor i-th kind of mineral volume content, Δ tf、Δtsh、ΔtimaDistinguish with Δ t
For the interval transit time value in fluid time difference value, shale time difference value, i-th kind of mineral time difference value and sound wave measuring well curve；ρf、ρsh、ρima
With the density value that ρ is respectively in fluid density value, shale density value, i-th kind of mineral density value and density log data；CNLf、
CNLsh、CNLimaIt is respectively subvalue in fluid, subvalue in shale, in i-th kind of mineral in subvalue and neutron well logging data with CNL
Middle subvalue；Wherein Δ t, ρ and CNL is respectively the log data of acoustic logging, density log, neutron well logging, Δ tf、Δtsh、Δ
tima、ρf、ρsh、ρima、CNLf、CNLshAnd CNLimaFor priori value；I=1,2,3 ..., N, N are the mineral in carbonate reservoir
Number of species；
S205: by matrix porosity φs, rock fracture porosity φcWith each mineral composition volume content Vi, as final
Carbonate reservoir physical property explanation results.
3. a kind of carbonate formation overpressure prediction method as claimed in claim 2, it is characterised in that: in step S202, SH
Calculation formula such as formula (4) shown in:
In above formula, GRmaxAnd GRminRespectively gamma ray curve maximum and minimum, GR are the nature of target zone containing shale gal
Horse reading is gamma ray log data；GRmax、GRminFor priori value.
4. a kind of carbonate formation overpressure prediction method as claimed in claim 2, it is characterised in that: in step S202, ground
The value of layer constant GCUR is 2.
5. a kind of carbonate formation overpressure prediction method as claimed in claim 2, it is characterised in that: in step S204, carbon
Carbonate Rocks Minerals content includes: shale content, calcite content, dolomite content mixing paste salt content；Known to shale content
In the case where, ViRespectively indicate three kinds of mineral contents: calcite content V1, dolomite content V2Mixing paste salt content V3,；Macroscopical rock
Steps are as follows for the calculating of stone volumetric balance model:
S301: the unknown number number nonsingular linear equal with equation number is obtained by formula (3) arrangement and just determines equation group；It is described not
Know that number includes: φs、V1、V2And V3；
S302: just determining equation group to the nonsingular linear by particle swarm algorithm and scan for, and obtains one close to solution
Initial value；
S303: according to the initial value, it is further that equation group is just determined to the nonsingular linear using Nonlinear Constrained Optimization Method
It solves, obtains matrix porosity φsAnd V1、V2、V3Exact Solutions.
6. a kind of carbonate formation overpressure prediction method as described in claim 1, it is characterised in that: in step S102, root
According to the rock shale mineral content V of carbonate formation to be predictedshWith each mineral composition volume content Vi, using Voigt-
Reuss-Hill average modulus model calculates the Rock Matrix bulk modulus K of carbonate formation to be predictedsCalculation formula such as
Shown in formula (5):
In above formula, MiIt is priori value for each mineralogical composition concrete moduli；It is to be predicted
The mineral species quantity contained in carbonate formation, wherein f2、f3And f4Respectively represent the body of limestone, dolomite and gypsum-salt rock
Product content.
7. a kind of carbonate formation overpressure prediction method as described in claim 1, it is characterised in that: in step S103, meter
Calculate the pore-fluid bulk modulus K of carbonate formation to be predictedfCalculation formula such as formula (6) shown in:
In above formula, KiIt is priori value for mixture fluid component volume modulus each in carbonate formation to be predicted；xiFor composition
Each section percentage by volume of the n kind component of mixture fluid, calculation formula are as follows:M, n, a, b are rock electricity ginseng
Number is priori value；RtIt is log data for true formation resistivity curve；RiIt is logging data for formation water resistivity；I=1,
2,…,n。
8. a kind of carbonate formation overpressure prediction method as described in claim 1, it is characterised in that: in step S105, root
According to rock porosity φ, Rock Matrix bulk modulus Ks, pore-fluid bulk modulus KfWith rock matrix bulk modulus Kd, calculate
Shown in the calculation formula such as formula (7) for obtaining the overpressure prediction value p of carbonate formation to be predicted:
In above formula,It is priori value for mean principle stress；β is the empirical parameter coefficient of dimensionless, is priori value；A is compound bullet
Property modulus group item；φ=φs+φc。
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Cited By (5)
| Publication number | Priority date | Publication date | Assignee | Title |
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| CN111736214A (en) * | 2019-03-25 | 2020-10-02 | 中国石油天然气集团有限公司 | Mineral matrix modulus calculation method, and method and device for establishing seismic response model |
| CN112392471A (en) * | 2019-08-13 | 2021-02-23 | 中国石油化工股份有限公司 | Carbonate reservoir porosity calculation method and device |
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| CN114492235B (en) * | 2022-01-14 | 2023-04-07 | 成都理工大学 | Stratum pore fluid pressure prediction method suitable for carbonate rock stratum |
| CN115788419A (en) * | 2022-11-23 | 2023-03-14 | 西南石油大学 | Complex overpressure cause formation pore pressure prediction method |
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