CN117434599A - Method for predicting formation pressure based on seismic data - Google Patents
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- G—PHYSICS
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- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
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- G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
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- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
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- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
- G01V1/30—Analysis
- G01V1/303—Analysis for determining velocity profiles or travel times
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Abstract
The invention discloses a method for predicting formation pressure based on seismic data, and relates to the technical fields of petroleum geological exploration and seismic data inversion. The method comprises the following steps: s1, determining a prediction formula of formation pressure; s2, preprocessing a seismic velocity data body; s3, calculating and normalizing various parameter data volumes; s4, optimizing and adjusting core parameters; s5, verifying and perfecting a prediction result. The method for predicting the stratum pressure based on the seismic data provided by the invention can be applied in a large area and high efficiency under the condition of only the seismic velocity data, is suitable for estimating the pressure of a compact layer, is simple and high-efficiency, can obtain the trend of pressure change, and is beneficial to exploration and development of oil and gas resources.
Description
Technical Field
The invention relates to the technical field of petroleum geological exploration and seismic data inversion, in particular to a method for predicting formation pressure based on seismic data.
Background
The existing prediction method of the formation pressure mainly comprises an equivalent depth method and an empirical formula method, wherein the equivalent depth method is that the formation is not compacted due to unbalanced compaction of the muddy sediment and abnormal high pressure is generated, which is the theoretical basis for traditional prediction of abnormal formation pore pressure, namely, unbalance between compaction and formation pore drainage is the main cause of abnormal overpressure, and the formation pore pressure abnormality is not only influenced by the compaction degree of sediment such as mudstone, but also is closely related to the formation porosity. The common Eaton method, the bowels method, etc. are all based on equivalent depth methods. The method needs to establish a normal compaction curve to predict the formation pressure, is mainly calculated by using logging data, is often suitable for calculation of a single well, and has higher accuracy on the single well of a conventional reservoir. In tight reservoirs, limited by heterogeneity, screening of the argillaceous sediments becomes difficult, while the reference significance of individual wells to the entire horizon is reduced. The empirical formula method is usually obtained through an empirical model, and common empirical formula methods include a Fillippone method, an Eberhart-Phillips method and the like, and the empirical statistical model involves more parameters and easily causes mutual superposition of errors of all the parameters, so that the prediction accuracy of the formation pore pressure is reduced.
However, the empirical statistical model is not influenced by lithology and abnormal pressure causative mechanisms, and has great advantages to complex lithology sections and pressure causative areas compared with other stratum pore pressure prediction methods; some empirical statistical models directly calculate formation pore pressure and avoid error transfer caused by calculation of intermediate parameters using logging data. In tight reservoirs, the overpressure causes are also complex due to lithologic differences caused by extremely strong heterogeneities, making it difficult for the empirical formula prediction method to guarantee higher accuracy.
In view of the above, the present invention provides a method for predicting formation pressure based on seismic data.
Disclosure of Invention
The invention aims to provide a stratum pressure prediction method based on seismic data, which can be applied in large area and high efficiency under the condition of only seismic velocity data, is suitable for pressure estimation of a compact layer, is simple and high-efficiency, can obtain the trend of pressure change, and is beneficial to exploration and development of oil and gas resources.
In order to achieve the above purpose, the invention provides a method for predicting formation pressure based on seismic data, which specifically comprises the following steps:
s1, determining a prediction formula of formation pressure;
s2, preprocessing a seismic velocity data body;
s3, calculating and normalizing various parameter data volumes;
s4, optimizing and adjusting core parameters;
s5, verifying and perfecting a prediction result.
Preferably, the step S1 specifically includes: selecting a Fillippone method, and providing an empirical formula according to the balance relation between drilling fluid and formation pressure, wherein the empirical formula is as follows:
wherein P is p Is the formation pressure, MPa; p (P) ov The pressure of the overburden stratum is MPa; v (V) i Layer speed, m/s; v (V) max Is the matrix speed, m/s; v (V) min Is pore fluid velocity, m/s.
Preferably, the step S2 specifically includes: estimating the superposition speed according to the time difference information, converting the superposition speed into root mean square speed, and finally calculating the main speed parameter V by using a Dix formula i The Dix formula is as follows:
wherein v is R,i And v R,i-1 The root mean square speeds of the top and bottom interfaces of the stratum are m/s respectively; t is t 0,i And t 0,i-1 The travel time s of the reflected wave of the top and bottom interfaces of the stratum respectively; v i Is the layer speed, m/s.
Preferably, the step S3 specifically includes: calculating and normalizing the data volume of the secondary parameter overburden formation pressure and the overburden sediment density;
overburden formation pressure P ov Is the pressure generated by the total weight of stratum rock skeleton and pore fluid, and has the expression:
wherein H is the vertical depth of the calculation point of the overburden formation pressure, m; g is gravity acceleration, 9.8m/s 2 ；ρ s G/cm for overburden deposit density 3 ；
ρ s The expression of (2) is:
ρ s ＝0.357+1.114V i -0.182V i 2 +0.010V i 3 (5)
wherein ρ is s G/cm for overburden deposit density 3 ；V i Is the layer speed, m/s.
Preferably, the step S4 specifically includes: root mean square velocity variation causes V max And V min The specific relation is as follows:
V max ＝1.4V R0 +3kt
V min ＝0.7V R0 +0.5kt (6)
wherein t is the time of the reflected wave for double-way travel, s; v (V) R0 Is the intercept of the root mean square velocity as a function of t; k is the slope; because of the difference of lithology and compaction degree of stratum in different research areas, the actual geological conditions need to be combined for V R0 And (5) adjusting.
Preferably, the step S5 specifically includes: using pressure coefficient as quantization index, the pressure coefficient is the ratio of formation pressure to hydrostatic pressure, and the pressure coefficient alpha p The calculation formula of (2) is as follows:
wherein alpha is p Is the pressure coefficient, P h Is hydrostatic pressure, MPa; ρ is the formation water density, taken here as 1.02g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the H is the height of the static water column;
and carrying out calculation on all the parameters to obtain a data body of the pressure coefficient, and comparing the predicted value and the measured value in each horizon to confirm the accuracy of the predicted result.
Therefore, the invention provides a method for predicting the stratum pressure based on the seismic data, which has the following beneficial effects:
(1) The method can be applied in large area and high efficiency only with seismic velocity data;
(2) Preprocessing a seismic velocity data body on the basis of determining a stratum pressure prediction formula to obtain reliable calculation data; calculating and normalizing various parameter data bodies to enable various parameters to be calculated in the form of the data bodies; then, optimizing and adjusting parameters of the core to ensure the accuracy of prediction; and finally, verifying and perfecting the prediction result.
(3) The method is suitable for estimating the pressure of the compact layer, is simple and efficient, can obtain the trend of pressure change, and is beneficial to exploration and development of oil and gas resources.
The technical scheme of the invention is further described in detail through the drawings and the embodiments.
Drawings
FIG. 1 is a cross-sectional view of root mean square velocity in an embodiment of the invention;
FIG. 2 is a cross-sectional view of the layer velocity in an embodiment of the invention;
FIG. 3 is a density profile view of an embodiment of the present invention;
FIG. 4 is a graph showing the comparison of predicted values and measured values in an embodiment of the present invention;
FIG. 5 is a cross-sectional view of a pressure coefficient according to an embodiment of the present invention;
FIG. 6 is a plan view of a pressure coefficient in an embodiment of the present invention.
Detailed Description
The following detailed description of the embodiments of the invention, provided in the accompanying drawings, is not intended to limit the scope of the invention, as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
Examples
The invention provides a method for predicting formation pressure based on seismic data, which comprises the following steps:
s1, determining a prediction formula of formation pressure;
the river group belongs to a tight reservoir, the pressure causes are complex, higher accuracy is difficult to ensure by establishing a prediction method of a normal compaction trend, and an empirical formula method does not need to establish the normal compaction trend and is suitable for pressure estimation of a large-area work area, so that the method has obvious advantages in pressure prediction of the tight reservoir.
The Fillippone method is selected from the empirical formula method, and is characterized in that after a learner comprehensively researches various data of oil fields such as earthquake, logging, drilling and the like in areas such as coastal areas of the gulf of Mexico, the phenomenon that the speed of earthquake waves is reduced and the overpressure appears is found, and an empirical formula is provided according to the balance relation between drilling fluid and stratum pressure, and the method comprises the following specific steps:
wherein P is p Is the formation pressure, MPa; p (P) ov The pressure of the overburden stratum is MPa; v (V) i Layer speed, m/s; v (V) max The matrix speed is the speed when the porosity approaches zero and is approximate to the upper limit of the rock speed, m/s; v (V) min For pore fluid velocity, the rock stiffness approaches zero velocity, approximating the lower rock velocity limit, m/s.
The core of the prediction by the empirical formula method is to set and adjust key parameters, and the optimum parameters are selected to improve the accuracy of the prediction to the greatest extent.
S2, preprocessing a seismic velocity data body;
the speed parameter is an important parameter of pressure prediction, the change trend of the speed parameter is closely related to the pressure change trend, and accurate determination of the stratum speed is important. In the fillppone formula, the main parameters are all parameters related to speed, and the connection between the parameters can be established by utilizing the seismic layer speed data.
Because the seismic layer velocity cannot be directly acquired in the actual seismic data acquisition, the stacking acceleration is estimated according to the normal time difference information, and then the stacking velocity is converted into the root mean square velocity based on the assumed condition that the stratum medium level or fluctuation is not large, and the layer velocity of the stratum is calculated by using a Dix formula.
Wherein v is R,i And v R,i-1 The root mean square speeds of the top and bottom interfaces of the stratum are m/s respectively; t is t 0,i And t 0,i-1 The travel time s of the reflected wave of the top and bottom interfaces of the stratum respectively; v i Is the layer speed, m/s.
In the river group of the beard family, the phenomenon of mutual layers of sandstone and mudstone is obvious. As shown in fig. 1 and 2, the root mean square speed shows a change trend of increasing from shallow to deep, the overall speed is lower, and the real speed condition of the stratum cannot be reflected; the change trend of the layer speed is irregular, the speed value is larger than the root mean square speed, and the speed range is wider; the three sections of thicker shale layers correspond to the reduction of the speed, the two sections of speed increase also correspond to the lithology characteristics of the shale layers, and the data of the layer speed can better reflect the real speed of the stratum.
S3, calculating and normalizing various parameter data volumes;
in the Fillippone method, secondary parameters are overburden formation pressure, overburden sediment density and the like, and the accurate prediction can be ensured by calculating and normalizing data volumes of the secondary parameters of overburden formation pressure and overburden sediment density.
Overburden formation pressure P ov Is the pressure generated by the total weight of stratum rock framework and pore fluid, and the expression is:
wherein H is the vertical depth of the calculation point of the overburden formation pressure, m; g is gravity acceleration, 9.8m/s 2 ；ρ s G/cm for overburden deposit density 3 。
Early scholars counted the relationship between the layer velocity and the overburden sediment density of different rock formations and established an empirical relationship:
wherein ρ is s G/cm for overburden deposit density 3 ；V i Is the layer speed, m/s.
With the improvement of geophysical technology and processing precision, a plurality of students improve the formula (4) by utilizing high-resolution wave velocity and deep well electron density measurement. A new improved formula is used in the formation pressure prediction based on the seismic data, and a better effect is obtained, wherein the new formula is as follows:
ρ s ＝0.357+1.114V i -0.182V i 2 +0.010V i 3 (5)
as shown in FIG. 3, in the density profile of the whisker river set, the main range is 2.5-2.62g/cm 3 The density change is smaller, the density change is more consistent with the density of the well logging, and the more real density characteristics can be reflected.
S4, optimizing and adjusting core parameters;
in the Fillippone method, V max And V min Is used for counting the speed characteristics of stratum in the gulf of Mexico and other areas, and shows that the change of the root mean square speed can lead to V max And V min And establishes the following relationship:
V max ＝1.4V R0 +3kt
V min ＝0.7V R0 +0.5kt (6)
wherein t is the time of the reflected wave for double-way travel, s; v (V) R0 Is the intercept of the root mean square velocity as a function of t; k is the slope. Because of the difference of lithology and compaction degree of stratum in different research areas, the actual geological conditions need to be combined for V R0 And (5) adjusting.
In the river set of the beard, the setting of parameters is needed to be carried out by layering layers due to lithology and sand-mud ratio differences among the layers. And screening out the most suitable root mean square speed of each horizon by using the lithology characteristics of each horizon, further determining the rock skeleton speed and the pore fluid speed of each horizon, and selecting and configuring key parameters as shown in the following table 1.
TABLE 1
| Formation | V max (m/s) | V min (m/s) | V R0 (m/s) |
| T 3 x 5 | 6846 | 3107 | 4196 |
| T 3 x 4 | 7428 | 3244 | 4305 |
| T 3 x 3 | 8872 | 3989 | 4398 |
| T 3 x 2 | 8073 | 3446 | 4507 |
Each layer V is selected by the root mean square velocity data in fig. 1 R0 Parameters. Due toV in each layer R0 The values are not fixed, the key to improving accuracy is V in each horizon R0 And selecting a set of most suitable parameters in the range, wherein the set of parameters can enable errors everywhere in the horizon to be small. V of five sections R0 4196m/s, three-stage V R0 4398m/s, the two layers are greatly influenced by the mudstone occupation, and finally V R0 Selecting V in horizon R0 A smaller value; while the four-section mud rock and the two-section mud rock occupy smaller proportion, and V R0 For higher values in the respective horizons, 4305m/s and 4507m/s, respectively.
S5, verifying and perfecting a prediction result;
in order to intuitively reflect the overpressure development intensity of different areas in a research area, a pressure coefficient is used as a quantization index in the research, the pressure coefficient is the ratio of formation pressure to hydrostatic pressure and is a common parameter for judging the overpressure intensity in a sedimentary basin, and the pressure coefficient alpha p The calculation formula of (2) is
Wherein alpha is p Is the pressure coefficient, P h Is hydrostatic pressure, MPa; ρ is the formation water density, taken here as 1.02g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the H is the height of the static water column.
And carrying the data body with the pressure coefficient obtained after the calculation of each parameter, and comparing the predicted value and the measured value in each horizon to confirm the accuracy of the predicted result.
As shown in fig. 4, in the river set, the prediction results of the two-section, four-section and five-section are all good, the relative error is generally within 10%, the prediction result of the three-section is slightly bad, and the strong heterogeneity is difficult to select a set of parameters meeting the whole horizon. The parameters can be reversely adjusted and optimized through the comparison of the predicted value and the measured value, and if the overall error is higher or lower, the parameters can be adjusted and optimized through the comparison of V R0 Is optimized by re-selection, and a set of relatively good prediction results are obtained by repeated adjustment.
As shown in fig. 5, the pressure change on the section of the river set of the beard is clearly shown, so that the layer pressure intensity can be effectively shown, and particularly, the strong overpressure mainly comprising three sections and the weak overpressure mainly comprising two sections can be effectively shown. As shown in fig. 6, the plane spreading of the obtained pressure is clearly presented, and the detail is clear, so that the analysis of the action mechanism of macroscopic pressure is facilitated. In the predicted pressure plane and the sectional view, the pressure distribution trend of the river group of the beard can be obviously identified, wherein the pressure coefficient of the three sections of the river group of the beard is highest, and the pressure coefficient of the middle area in the plane view is lower. The method has important significance for the directions of oil and gas migration, development, well drilling and the like in the area through the pressure distribution prediction result.
Therefore, the invention provides a method for carrying out stratum pressure prediction based on seismic data, which is used for preprocessing a seismic velocity data body on the basis of determining a stratum pressure prediction formula to obtain reliable calculation data; calculating and normalizing various parameter data bodies to enable various parameters to be calculated in the form of the data bodies; then, the parameters of the core are optimized and adjusted, so that the prediction accuracy is ensured; and finally, verifying and perfecting the prediction result. The method can be applied in large area and high efficiency under the condition of only seismic velocity data, is suitable for pressure estimation of a compact layer, is simple and high-efficiency, can obtain the trend of pressure change, and is beneficial to exploration and development of oil and gas resources.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present invention and not for limiting it, and although the present invention has been described in detail with reference to the preferred embodiments, it will be understood by those skilled in the art that: the technical scheme of the invention can be modified or replaced by the same, and the modified technical scheme cannot deviate from the spirit and scope of the technical scheme of the invention.
Claims (6)
1. The method for predicting the formation pressure based on the seismic data is characterized by comprising the following steps of:
s1, determining a prediction formula of formation pressure;
s2, preprocessing a seismic velocity data body;
s3, calculating and normalizing various parameter data volumes;
s4, optimizing and adjusting core parameters;
s5, verifying and perfecting a prediction result.
2. The method for predicting formation pressure based on seismic data as claimed in claim 1, wherein said step S1 is specifically: selecting a Fillippone method, and providing an empirical formula according to the balance relation between drilling fluid and formation pressure, wherein the empirical formula is as follows:
wherein P is p Is the formation pressure, MPa; p (P) ov The pressure of the overburden stratum is MPa; v (V) i Layer speed, m/s; v (V) max Is the matrix speed, m/s; v (V) min Is pore fluid velocity, m/s.
3. The method for predicting formation pressure based on seismic data according to claim 2, wherein the step S2 is specifically: estimating the superposition speed according to the time difference information, converting the superposition speed into root mean square speed, and finally calculating the main speed parameter V by using a Dix formula i The Dix formula is as follows:
wherein v is R,i And v R,i-1 The root mean square speeds of the top and bottom interfaces of the stratum are m/s respectively; t is t 0,i And t 0,i-1 The travel time s of the reflected wave of the top and bottom interfaces of the stratum respectively; v i Is the layer speed, m/s.
4. A method for predicting formation pressure based on seismic data as claimed in claim 3, wherein said step S3 is specifically: calculating and normalizing the data volume of the secondary parameter overburden formation pressure and the overburden sediment density;
overburden formation pressure P ov Is the pressure generated by the total weight of stratum rock skeleton and pore fluid, and has the expression:
wherein H is the vertical depth of the calculation point of the overburden formation pressure, m; g is gravity acceleration, 9.8m/s 2 ；ρ s G/cm for overburden deposit density 3 ；
ρ s The expression of (2) is:
ρ s ＝0.357+1.114V i -0.182V i 2 +0.010V i 3 (5)
wherein ρ is s G/cm for overburden deposit density 3 ；V i Is the layer speed, m/s.
5. The method for performing formation pressure prediction based on seismic data according to claim 4, wherein the step S4 is specifically: root mean square velocity variation causes V max And V min The specific relation is as follows:
V max ＝1.4V R0 +3kt
V min ＝0.7V R0 +0.5kt (6)
wherein t is the time of the reflected wave for double-way travel, s; v (V) R0 Is the intercept of the root mean square velocity as a function of t; k is the slope; because of the difference of lithology and compaction degree of stratum in different research areas, the actual geological conditions need to be combined for V R0 And (5) adjusting.
6. The method for performing formation pressure prediction based on seismic data according to claim 5, wherein the step S5 is specifically: using pressure coefficientsFor quantitative index, the pressure coefficient is the ratio of formation pressure to hydrostatic pressure, the pressure coefficient alpha p The calculation formula of (2) is as follows:
wherein alpha is p Is the pressure coefficient, P h Is hydrostatic pressure, MPa; ρ is the formation water density, taken here as 1.02g/cm 3 The method comprises the steps of carrying out a first treatment on the surface of the H is the height of the static water column;
and carrying out calculation on all the parameters to obtain a data body of the pressure coefficient, and comparing the predicted value and the measured value in each horizon to confirm the accuracy of the predicted result.
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| CN111060986A (en) * | 2019-10-18 | 2020-04-24 | 中国石油化工股份有限公司 | Formation pressure prediction method and lithologic oil reservoir evaluation method |
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Patent Citations (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN105445791A (en) * | 2015-11-25 | 2016-03-30 | 成都理工大学 | Stratum aperture pressure prediction method based on variety earthquake attributes |
| CN106094027A (en) * | 2016-06-01 | 2016-11-09 | 中国海洋石油总公司 | A kind of vertical seismic profiling (VSP) VSP pre-drilling pressure forecasting method and system |
| CN107843927A (en) * | 2016-09-20 | 2018-03-27 | 中国石油化工股份有限公司 | Shale formation pressure prediction method and device based on well shake joint speed |
| CN108089227A (en) * | 2017-12-12 | 2018-05-29 | 中国石油天然气集团有限公司 | The new formation pore pressure Forecasting Methodology based on three dimensional seismic data |
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