CN108875109B - Method and system for predicting abnormal formation pressure - Google Patents

Method and system for predicting abnormal formation pressure Download PDF

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CN108875109B
CN108875109B CN201710345418.XA CN201710345418A CN108875109B CN 108875109 B CN108875109 B CN 108875109B CN 201710345418 A CN201710345418 A CN 201710345418A CN 108875109 B CN108875109 B CN 108875109B
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孙炜
张殿伟
何治亮
孙冬胜
沃玉进
李双建
李天义
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Sinopec Exploration and Production Research Institute
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Abstract

The invention relates to the technical field of test methods, in particular to a prediction method of abnormal formation pressure, which comprises the steps of sorting formation abnormal pressure data; analyzing the logging response characteristics of the formation abnormal pressure data; establishing a formation pressure calculation model through the logging response characteristics; and measuring formation pressure data by using the formation pressure calculation model. The method comprises the steps of carrying out statistics on abnormal formation pressure data measured in a drilling well, carrying out response characteristic analysis on each logging curve, selecting the logging curve with good correlation with the abnormal formation pressure data to construct an abnormal pressure identification factor model, further combining the measured formation pressure data to obtain a new formation pressure calculation formula, finally, carrying out geophysical inversion based on seismic data before and after stacking to obtain each parameter data body in the formula, substituting the parameter data bodies into the new formation pressure calculation formula to obtain a formation pressure data body, and further obtaining the spatial distribution characteristics of the formation pressure, thereby being beneficial to exploration and development of abnormal pressure oil and gas reservoirs.

Description

Method and system for predicting abnormal formation pressure
Technical Field
The invention relates to the technical field of testing methods, in particular to a prediction method of abnormal formation pressure.
Background
The formation pressure, namely the pore fluid pressure, is the pressure generated by the action of geological fluids such as formation water, oil, natural gas and the like in rock pores, under any geological background, the normal formation pressure is equal to the hydrostatic column pressure from the earth surface to a target layer, and the pressure deviating from the normal pressure trend line is considered as abnormal formation pressure.
With the deepening of oil and gas exploration and development research, particularly the continuous deepening of the research on the southern abnormal pressure oil reservoir, petroleum geological exploration workers continuously explore and research the abnormal formation pressure and the development mechanism thereof, the abnormal formation pressure and the relation between oil and gas generation, migration and aggregation, and the significance of the abnormal formation pressure research in the oil and gas exploration is increasingly emphasized. Research on formation pressure prediction methods at home and abroad has been going through decades, and the problem has been a research difficulty in the field of oil and gas exploration.
At present, the abnormal formation pressure prediction has more documents and less patents, and the methods are mainly classified into the following categories: and (one) calculating abnormal formation pressure based on the velocity. Such as an equivalent depth method, an Eaton formula method and a filliptone formula method (zhonghong, a high-precision stratum pressure prediction method, petroleum geophysical exploration 2014), the method firstly establishes a relation between stratum pressure and seismic velocity at a well point, then obtains a relatively accurate seismic velocity data body through technical means such as velocity analysis or inversion in seismic data processing, and the like, and finally substitutes velocity data into a calculation formula of the stratum pressure to predict the spatial distribution characteristics of the stratum pressure; the prediction accuracy of such methods is limited by the accuracy of the velocity data volume itself, and seismic velocities are only well correlated with abnormal pressure due to under-compaction, which is not the main cause of overpressure in overpressured formations in the southern Sichuan basin. And (II) calculating the formation pressure according to the effective stress. Patent CN201310664099.0, a method for calculating anomalous formation pressure, is a representative patent of this type of technology, which calculates effective stress from petrophysical parameters, and then calculates formation pressure according to the effective stress principle of Terzaghi. However, the effective stress principle has limited applicability and is only approximately applicable to loose porous media. And (III) a pressure prediction method while drilling, such as a DC index method and a Sigma method (Chenggen, research on a real-time prediction method of exploratory well formation pressure, drilling and production process, 2008), wherein the method firstly calculates a DC value or a Sigma value under a normal trend based on drilling parameters such as the average drilling speed, the average rotating speed and the average drilling pressure of a drill rod, and when a drilling tool encounters an abnormal pressure formation, the index deviates, so that overpressure is predicted. This type of method is based on the well location already determined, while the task of the exploration phase is to determine the advantageous targets, i.e. to propose well location recommendations, and therefore this type of method is not applicable in the exploration phase.
Disclosure of Invention
Aiming at the defects existing in the problems, the invention provides a method for predicting abnormal formation pressure.
In order to achieve the above object, the present invention provides a method for predicting abnormal formation pressure, the method comprising the steps of:
arranging the abnormal pressure data of the stratum;
analyzing the logging response characteristics of the formation abnormal pressure data;
establishing a formation pressure calculation model through the logging response characteristics;
and calculating the formation pressure data by using a formation pressure calculation model.
The above-described method of predicting abnormal formation pressure,
the formation pressure data is sorted out according to actual drilling information, and then data of pressure change influenced by engineering factors in the formation pressure data is removed;
the formation pressure data includes normal pressure and abnormal formation pressure;
the abnormal formation pressures include low, high and ultra high pressures.
The above-described method of predicting abnormal formation pressure,
analyzing different logging curves of the abnormal formation pressure and the normal pressure of each well in the work area, analyzing the different logging curves, the normal pressure and the abnormal formation pressure to obtain a correlation coefficient, and selecting a curve with a large numerical value from the correlation coefficients of the different logging curves, the normal pressure and the abnormal pressure according to the correlation coefficient;
the different logging curves and the correlation coefficient are subjected to corresponding normalization processing, and the correlation coefficient is aiThe specific calculation formula is as follows:
Figure BDA0001295273760000021
wherein, the aiRepresenting a correlation coefficient of the ith said different log with said formation pressure,
Figure BDA0001295273760000033
represents the sum of the correlation coefficients, a'iThe correlation coefficient after the normalization processing is represented.
The above-described method of predicting abnormal formation pressure,
further comprising:
processing the different well logs;
constructing an abnormal pressure identification factor model through the processed different logging curves;
and establishing a formation pressure calculation formula according to the abnormal pressure identification factor model.
The above-described method of predicting abnormal formation pressure,
Liis a single said different log, L'iFor a single said different well log after normalization, min (L)i) Minimum value, max (L), for a single one of said different well logsi) The maximum value of a single different logging curve;
the calculation formula is as follows:
Figure BDA0001295273760000031
the above-described method of predicting abnormal formation pressure,
in S1032, the m different well logs having good correlation with the high pressure and the ultrahigh pressure in the abnormal formation pressure are log'1、log′2To log'mAnd n different logging curves with good correlation with the normal pressure are log'1、log′2To log'nCombining:
Figure BDA0001295273760000032
wherein API identifies factor model for abnormal pressure constructed, Sigma is summation operation, log'iIs the different well log curves, A ', which are well correlated with the high pressure and the ultrahigh pressure and are subjected to normalization treatment'iThe correlation coefficient is the corresponding correlation coefficient subjected to normalization processing;
log′jis the different well log curves, B ', which have good correlation with the normal pressure and are subjected to normalization processing'jThe correlation coefficient is the corresponding correlation coefficient after normalization processing.
The above-described method of predicting abnormal formation pressure,
further comprising that the l different well logs having good correlation with the low pressure in the abnormal formation pressure are log'1，log′2To log'lThe n different logging curves with good normal pressure correlation are log'1，log′2To log'nCombining:
Figure BDA0001295273760000041
wherein, sigma is summation operation, the different well logging curves which have good correlation with the low pressure and are processed by normalization are log'k，C′kThe correlation coefficient is the corresponding correlation coefficient subjected to normalization processing; log'jIs the different well log curves, B ', which have good correlation with the normal pressure and are subjected to normalization processing'jThe correlation coefficient is the corresponding correlation coefficient after normalization processing.
The above-described method of predicting abnormal formation pressure,
calculating the abnormal pressure identification factor value, fitting the abnormal pressure identification factor value and the formation abnormal pressure data in a linear, polynomial and exponential relationship, and finding out a formula with high correlation from a plurality of fitting relational expressions:
P＝Fun(API)
wherein P is the formation pressure data, API is the abnormal pressure identification factor value, and Fun (API) is a relational expression with good correlation between the formation pressure data and the abnormal pressure identification factor value.
The above-described method of predicting abnormal formation pressure,
and selecting a proper pre-stack and post-stack geophysical inversion method according to the relational expression, calculating corresponding seismic parameter data, substituting the seismic parameter data into a formation pressure calculation formula, solving formation pressure data, and showing the spatial distribution characteristics of the formation pressure.
A system for predicting abnormal formation pressure, comprising:
the data arrangement module is used for arranging the formation abnormal pressure data;
the analysis module is used for analyzing the logging response characteristics of the formation abnormal pressure data;
the building module is used for building a stratum pressure calculation model;
and the prediction module is used for calculating formation pressure data.
In the technical scheme, compared with the prior art, the method for predicting the abnormal formation pressure provided by the invention has the advantages that the abnormal formation pressure data actually measured by drilling is counted, the response characteristic analysis of each logging curve is carried out, then, the logging curve with better correlation with the abnormal formation pressure data is selected to construct the abnormal pressure identification factor model, a new formation pressure calculation formula is further obtained by combining the actually measured formation pressure data, finally, each parameter data body in the formula is obtained by utilizing the geophysical inversion based on the seismic data after pre-stack and post-stack, and the parameter data bodies are substituted into the new formation pressure calculation formula to obtain the formation pressure data body, so that the spatial distribution characteristic of the formation pressure is obtained, and the exploration and development of the abnormal pressure oil-gas reservoir are facilitated.
Since the above method for predicting abnormal formation pressure has the above technical effects, a system including the method should also have corresponding technical effects.
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The invention will be described in more detail hereinafter on the basis of embodiments and with reference to the accompanying drawings. In the figure:
FIG. 1 is a flow chart of a method for predicting abnormal formation pressure in an embodiment of the present application.
FIG. 2 is a flow chart of step 103 of a method for predicting abnormal formation pressure in an embodiment of the present application.
FIG. 3 is a block diagram of a system for predicting abnormal formation pressure in an embodiment of the present application.
Detailed Description
The invention will be further explained with reference to the drawings.
As shown in fig. 1, the method for predicting abnormal formation pressure includes the following steps:
step S101: arranging the abnormal pressure data of the stratum;
step S102: analyzing the logging response characteristics of the formation abnormal pressure data;
step S103: establishing a formation pressure calculation model through the logging response characteristics;
step S104: and calculating the formation pressure data by using a formation pressure calculation model.
In a specific embodiment, in step S101, the formation pressure data is sorted out according to actual drilling data, and then data of pressure changes affected by engineering factors in the formation pressure data is removed;
specifically, the formation pressure data includes normal pressure and abnormal formation pressure;
specifically, the abnormal formation pressures include low pressure (formation pressure coefficient less than 1), high pressure (formation pressure coefficient between 1 and 1.5), and ultra high pressure (formation pressure coefficient greater than 1.5).
In a specific embodiment, in step S102, different well logs of the abnormal formation pressure and the normal pressure of each well in the work area are analyzed, the different well logs, the normal pressure and the abnormal formation pressure are analyzed to obtain correlation coefficients, and then a curve with a large value among the correlation coefficients of the different well logs, the normal pressure and the abnormal pressure is selected according to the correlation coefficients;
specifically, the different well logging curves and the correlation coefficient are subjected to corresponding normalization processing, and the correlation coefficient is aiThe specific calculation formula is as follows:
Figure BDA0001295273760000061
wherein, the aiRepresenting a correlation coefficient of the ith said different log with said formation pressure,
Figure BDA0001295273760000062
represents the sum of the correlation coefficients, a'iThe correlation coefficient after the normalization processing is represented.
As shown in fig. 2, in a specific embodiment, step S103 includes the following steps:
step S1031: processing the different well logs. Specifically, LiIs a single said different log, L'iFor a single said different well log after normalization, min (L)i) Minimum value, max (L), for a single one of said different well logsi) Is a single stripA maximum of the different well logs;
the calculation formula is as follows:
Figure BDA0001295273760000063
step S1032: and constructing an abnormal pressure identification factor model through the processed different logging curves. Specifically, the m different logging curves with good correlation with the high pressure and the ultrahigh pressure in the abnormal formation pressure are log'1、log′2To log'mAnd n different logging curves with good correlation with the normal pressure are log'1、log′2To log'nCombining:
Figure BDA0001295273760000064
wherein API identifies factor model for abnormal pressure constructed, Sigma is summation operation, log'iIs the different well log curves, A ', which are well correlated with the high pressure and the ultrahigh pressure and are subjected to normalization treatment'iThe correlation coefficient is the corresponding correlation coefficient after normalization processing. log'jIs the different well log curves, B ', which have good correlation with the normal pressure and are subjected to normalization processing'jThe correlation coefficient is the corresponding correlation coefficient after normalization processing.
Step S1033: and establishing a formation pressure calculation formula according to the abnormal pressure identification factor model. Calculating the abnormal pressure identification factor value, fitting the abnormal pressure identification factor value and the formation abnormal pressure data in a linear, polynomial and exponential relationship, and finding out a formula with high correlation from a plurality of fitting relational expressions:
P＝Fun(API)
wherein P is the formation pressure data, API is the abnormal pressure identification factor value, and Fun (API) is a relational expression with good correlation between the formation pressure data and the abnormal pressure identification factor value.
In a particular embodiment, further included in S1032 is that the l different log curves having good correlation to the low pressure in the anomalous formation pressure are log'1，log′2To log'lThe n different logging curves with good normal pressure correlation are log'1，log′2To log'nCombining:
Figure BDA0001295273760000071
wherein, sigma is summation operation, the different well logging curves which have good correlation with the low pressure and are processed by normalization are log'k，C′kThe correlation coefficient is the corresponding correlation coefficient subjected to normalization processing; log'jIs the different well log curves, B ', which have good correlation with the normal pressure and are subjected to normalization processing'jThe correlation coefficient is the corresponding correlation coefficient after normalization processing.
In a specific embodiment, step S104 selects a suitable pre-stack and post-stack geophysical inversion method according to the relational expression in step S1033, calculates corresponding seismic parameter data, and substitutes the seismic parameter data volume into a formation pressure calculation formula to obtain formation pressure data and display spatial distribution characteristics of formation pressure.
The method is characterized by comprising the following steps in specific application: (1) according to the existing drilling data, the formation pressure data is arranged; (2) carrying out sensitivity analysis on various logging curves of abnormal formation pressure, finally selecting two logging curves with better correlation with the abnormal formation pressure, namely longitudinal wave impedance and Poisson ratio, wherein the longitudinal wave impedance is in negative correlation with the abnormal formation pressure, the Poisson ratio is in positive correlation with the abnormal formation pressure, and then constructing an abnormal pressure factor identification model based on the longitudinal wave impedance and the Poisson ratio; (3) fitting a formation pressure calculation formula for calculating the abnormal formation pressure through the longitudinal wave impedance and the Poisson ratio according to the abnormal pressure identification factor value calculated by the actually measured formation pressure well section and the actually measured formation pressure; (4) and performing prestack inversion based on prestack seismic data, solving the velocity and density of longitudinal and transverse waves, further calculating a longitudinal wave impedance and Poisson's ratio data volume, and substituting the longitudinal wave impedance and Poisson's ratio data volume into a formation pressure calculation formula to obtain a three-dimensional data volume of the formation pressure. By applying the technology, the spatial distribution characteristic of the formation pressure of the target layer is accurately obtained, and the coincidence with the actually measured formation pressure of the well drilling is better.
As shown in fig. 3, the present application further provides a system for predicting abnormal formation pressure, the system comprising,
and the data arrangement module is used for arranging the formation abnormal pressure data.
And the analysis module is used for analyzing the logging response characteristics of the formation abnormal pressure data.
And the establishing module is used for establishing a stratum pressure calculation model.
And the prediction module is used for calculating formation pressure data.
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the technical features mentioned in the embodiments can be combined in any way as long as there is no structural conflict. It is intended that the invention not be limited to the particular embodiments disclosed, but that the invention will include all embodiments falling within the scope of the appended claims.

Claims (6)

1. A method for predicting abnormal formation pressure, the method comprising the steps of:
step S101: arranging the abnormal pressure data of the stratum;
step S102: analyzing the logging response characteristics of the formation abnormal pressure data;
step S103: establishing a formation pressure calculation model through the logging response characteristics;
step S104: calculating formation pressure data by using the formation pressure calculation model;
step S103 includes:
step S1031: processing different well logs;
step S1032: constructing an abnormal pressure identification factor model through the processed different logging curves;
step S1033: establishing a formation pressure calculation formula according to the abnormal pressure identification factor model;
in S1032, the m different logs associated with the high and ultra high pressures in the anomalous formation pressure are log1、log2To logmAnd n of said different logs associated with atmospheric pressure are log1'、log'2To log'nCombining:
Figure FDA0003349177390000011
wherein API is the abnormal pressure identification factor model constructed, Σ is the summation operation, logiIs the normalized different log curves, A ', correlated with the high pressure and the ultra-high pressure'iThe correlation coefficient is corresponding to the correlation coefficient subjected to normalization processing;
log'jis the different log, B ', correlated to the atmospheric pressure and normalized'jThe correlation coefficient is corresponding to the correlation coefficient subjected to normalization processing;
in S1033, the abnormal pressure identification factor model is calculated, and then the abnormal pressure identification factor model and the formation abnormal pressure data are fitted in a linear, polynomial, exponential relationship, and a formula with the highest correlation is found out from a plurality of fitting relationships:
P＝Fun(API)
wherein P is the formation pressure data, API is the abnormal pressure identification factor model, and Fun (API) is a relational expression representing the correlation of the formation pressure data and the abnormal pressure identification factor model;
and S104, selecting a pre-stack and post-stack geophysical inversion method according to the relational expression in the step S1033, calculating corresponding seismic parameter data, substituting the seismic parameter data into a formation pressure calculation formula, solving the formation pressure data, and showing the spatial distribution characteristics of the formation pressure.
2. The method of predicting abnormal formation pressure of claim 1, wherein:
in step S101, the formation pressure data is sorted out according to actual drilling data, and then data of pressure change influenced by engineering factors in the formation pressure data is removed;
the formation pressure data includes normal pressure and abnormal formation pressure;
the abnormal formation pressures include low, high and ultra high pressures.
3. The method of predicting abnormal formation pressure of claim 2, wherein:
in step S102, analyzing different well logs of the abnormal formation pressure of each well in the work area and different well logs of the normal pressure of each well in the work area, analyzing the different well logs, the normal pressure and the abnormal formation pressure to obtain a correlation coefficient, and then selecting a curve with the largest value among the correlation coefficients of the different well logs, the normal pressure and the abnormal pressure according to the correlation coefficient;
the different logging curves and the correlation coefficient are subjected to corresponding normalization processing, and the correlation coefficient is aiThe specific calculation formula is as follows:
Figure FDA0003349177390000021
wherein, the aiRepresenting a correlation coefficient of the ith said different log with said formation pressure,
Figure FDA0003349177390000022
represents the sum of the correlation coefficients, a'iThe correlation coefficient after the normalization processing is represented.
4. The method of predicting abnormal formation pressure of claim 1, wherein:
in S1031, LiIs a single said different log, L'iFor a single said different well log after normalization, min (L)i) Minimum value, max (L), for a single one of said different well logsi) The maximum value of a single different logging curve;
the calculation formula is as follows:
Figure FDA0003349177390000023
5. the method of predicting abnormal formation pressure of claim 1, wherein:
also included in S1032 is that the/different log associated with the low pressure in the anomalous formation pressure is log* 1,log* 2To log* lThe n different log curves associated with the normal pressure are log'1，log'2To log'nCombining:
Figure FDA0003349177390000031
where Σ is a summation operation, the different well logs associated with the low pressure and normalized are log* k，C'kThe correlation coefficient is the corresponding correlation coefficient subjected to normalization processing; log'jIs the different log, B ', correlated to the atmospheric pressure and normalized'jThe correlation coefficient is the corresponding correlation coefficient after normalization processing.
6. A system for a method of predicting anomalous formation pressures as in any one of claims 1 to 5 and including:
the data arrangement module is used for arranging the formation abnormal pressure data;
the analysis module is used for analyzing the logging response characteristics of the formation abnormal pressure data;
the building module is used for building a stratum pressure calculation model;
and the prediction module calculates formation pressure data.
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