WO2012010790A2 - Procede d'estimation de parametres elastiques par inversion de mesures sismiques 4d - Google Patents
Procede d'estimation de parametres elastiques par inversion de mesures sismiques 4d Download PDFInfo
- Publication number
- WO2012010790A2 WO2012010790A2 PCT/FR2011/051720 FR2011051720W WO2012010790A2 WO 2012010790 A2 WO2012010790 A2 WO 2012010790A2 FR 2011051720 W FR2011051720 W FR 2011051720W WO 2012010790 A2 WO2012010790 A2 WO 2012010790A2
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- WO
- WIPO (PCT)
- Prior art keywords
- seismic
- measured
- trace
- elastic parameters
- well
- Prior art date
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Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- 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. analysis, for interpretation, for correction
- G01V1/30—Analysis
- G01V1/308—Time lapse or 4D effects, e.g. production related effects to the formation
-
- G—PHYSICS
- G01—MEASURING; TESTING
- 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. analysis, for interpretation, for correction
- G01V1/30—Analysis
- G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
-
- G—PHYSICS
- G01—MEASURING; TESTING
- 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. analysis, for interpretation, for correction
- G01V1/30—Analysis
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/61—Analysis by combining or comparing a seismic data set with other data
- G01V2210/612—Previously recorded data, e.g. time-lapse or 4D
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/62—Physical property of subsurface
- G01V2210/622—Velocity, density or impedance
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V2210/00—Details of seismic processing or analysis
- G01V2210/60—Analysis
- G01V2210/62—Physical property of subsurface
- G01V2210/624—Reservoir parameters
- G01V2210/6242—Elastic parameters, e.g. Young, Lamé or Poisson
Definitions
- the present invention relates to geophysical methods used to estimate parameters of the subsoil especially in the context of exploration and production of hydrocarbons.
- first seismic recordings are obtained, initially obtained during a "base survey", for example before the production of a hydrocarbon reservoir, and a "monitor survey” is carried out, for example after a few years of reservoir operation, to obtain second seismic recordings.
- the seismic recordings (or seismic traces) base and monitor are compared to estimate variations of physical parameters of the geological layers in the explored area.
- the parameters whose variations are thus estimated may include the density p, the velocity V P of propagation of the pressure waves (P waves) and the velocity V s of propagation of the shear waves (S waves) in the mediums forming the different geological layers of the explored area.
- P waves pressure waves
- S waves shear waves
- lp p ⁇ V P
- l ⁇ ⁇ ⁇ Vs
- the comparative analysis of the records includes an inversion to estimate the variations of the parameters in order to get an idea of the saturation levels in the exploited layers.
- a reversal method that can be used to analyze offsets temporal measurements in the base and monitor seismic traces (depending on the variations in propagation velocities) at the same time as the amplitude changes (depending on the variations in impedances) is described in EP 1 865 340 A1.
- Another method for analyzing 4D seismic data uses a model-based inversion at one or more wells where logs have been recorded. .
- the document does not describe the inversion method nor how to parameterize the model.
- the results of the inversion are then extended away from the well by a statistical method.
- a correlation calculation is performed to reduce the time mark of the monitor recordings to that of the base records.
- the method seeks to directly estimate changes in saturation levels and pressure variations in the geological layers.
- the invention aims to enrich the 4D seismic techniques, in particular by taking them into account geological and dynamic constraints.
- a method for estimating elastic parameters of a subsoil region comprising:
- the technique uses a priori geological-dynamic to estimate the 4D parameters at the reservoir scale. This estimate is made along a predefined direction, usually vertical. It may be the direction of a well drilled in the study area or, in some embodiments, a direction chosen arbitrarily without having to be located on a well.
- the base and monitor seismic traces can be measured by sending seismic waves at normal incidence to layers succeeding one another along said direction and collecting the seismic waves reflected by interfaces between said layers.
- the method can also be extended to the estimation of shear wave propagation velocities in the permeable layers, while the base and monitor seismic traces are then measured by sending non-normal incidence seismic waves to successive layers along the said direction and collecting the seismic waves reflected by the interfaces between said layers.
- the elastic parameters whose variations are tested may also include the position, along said direction, of at least one interface delimiting one of said permeable layers.
- the elastic parameter variations are taken into account in permeable layers along a well drilled in the subsoil.
- the permeable layers are typically positioned along said direction, which is then the drilling direction of the well, from measurements (logs) made in the well.
- Another possibility, if the well is in operation, is to define the positions of the permeable layers along the well from perforation positions made in a casing of the well.
- a reservoir grid is constructed by a geomodelling technique based on structural information derived from seismic records and wells. This grid is filled with the physical properties of the rocks, including permeability and porosity, calibrated on the well data.
- the reservoir grid can be used to provide the geological a priori exploited in the 4D inversion.
- the positions of the permeable layers along the aforementioned direction are then defined from the reservoir grid. It should be noted that this makes it possible to implement the method at a well, the values of elastic parameters whose variations are tested being those located along the well in the reservoir grid, but also in the absence of wells. . In the latter case, the permeable layers where the elastic parameters are estimated are those that meet said direction in the reservoir grid. If the resolution of the reservoir grid is too fine, it is possible to aggregate several layers thereof in a single permeable layer taken into account in the 4D inversion.
- a simulated base seismic trace is computed from a wavelet representative of an incident seismic signal and the values of the elastic parameters measured at the well in the first
- a simulated monitor seismic trace is calculated from said wavelet and the values of the well-level elastic parameters obtained for the second time, and the difference between the measured seismic trace and the measured base seismic trace is compared. difference between the simulated monitor seismic trace and the simulated base seismic trace.
- the Variation hypothesis considered as having an optimal capacity, is used for the estimation of the elastic parameters in the second time (monitor).
- an amplitude disturbance of the measured base seismic trace is estimated as a result of a passage of the elastic parameters at the well of the values measured in the first time to the values obtained for the second time, it is calculated a seismic pseudo-trace by combining one of the measured seismic traces with the estimated amplitude disturbance, and comparing the other one of the seismic traces measured with the calculated seismic pseudo-trace on the same time scale. The result of the comparison can then be used to decide on the estimation of the elastic parameters.
- the estimate of the amplitude disturbance can use the logs recorded before putting the well into operation (base time). It then comprises the calculation of a simulated base seismic trace from a wavelet representative of an incident seismic signal and the values of the elastic parameters measured at the level of the well in the first step, the calculation of a simulated seismic monitor trace. from said wavelet and values of the elastic parameters at the well obtained for the second time, the simulated base and simulated seismic traces being calculated with the same depth-time conversion law, and a subtraction between the simulated base seismic trace and the simulated monitor seismic trace to obtain the estimated amplitude perturbation.
- Another approach can be adopted with or without the presence of a well. It consists of estimating an amplitude disturbance of the measured base seismic trace as a result of the variation of the elastic parameters, calculating a seismic pseudo-trace by combining one of the measured seismic traces with the estimated amplitude perturbation, and comparing, on the same time scale, the other seismic traces measured at the calculated seismic pseudo-trace.
- the amplitude perturbation can be approximated as a function of impedance variations in the permeable layers, deduced from the assumption of variation of the elastic parameters, and of a wavelet representative of an incident seismic signal.
- the ability of an elastic parameter variation assumption to account for the evolution between the measured base seismic trace and the measured monitor seismic trace is evaluated numerically by returning the trace to the base reference frame. monitor seismic deformed according to the assumptions of variation of the elastic parameters.
- the measured seismic trace that is combined with the estimated amplitude perturbation for the calculation of the seismic pseudo-trace is then the measured seismic trace, and the combination includes a modification of the time scale of the monitored seismic trace for take into account the variation in seismic wave propagation velocity according to the assumption of variation of elastic parameters, and the obtaining of the seismic pseudo-trace by subtracting the estimated amplitude disturbance from the modified measured seismic trace.
- FIG. 1 is a diagram illustrating a mode of seismic measurements near a well
- FIG. 2 is a diagram illustrating the synthesis of a seismic trace from measurements made in a well (logs);
- FIG. 3 is a diagram illustrating the evolution of a basic seismic trace towards a seismic monitor trace as a function of a hypothesis of variation of the density and rate of propagation of the pressure waves in permeable layers along the well;
- FIG. 4 is a diagram illustrating a first embodiment of the method for estimating elastic parameters according to the invention.
- FIGS. 5 and 6 are diagrams illustrating two other embodiments of the method
- FIG. 7 is a diagram illustrating another mode of acquisition of an exploitable seismic trace in one embodiment of the method.
- Figure 1 illustrates an oil field where a well 10 has been drilled. This well 10 passes through layers, represented very schematically in FIG. 1, having variable elastic parameters.
- FIG. 2 shows an example of recording the velocity V P of propagation of the pressure waves and the density p of the rock formations as a function of the depth along the well.
- a seismic wave source 11 is successively placed at different locations on the surface, or in the sea in the case of an offshore zone, and one or more seismic wave detectors 12 collect the seismic waves from the source 11 which have reflected on the interfaces between the geological layers encountered.
- FIG. 1 illustrates the particular case where the source 11 and the detector 12 are placed in the immediate vicinity of the well 10 in order to record seismic waves that have propagated vertically along the well with an approximately normal incidence on the interfaces between layers. .
- the first step consists in converting the logs V P (z), p (z) obtained as a function of the depth in the well in logs V P (t), p (t) expressed as a function of the propagation time of the waves in order to be able to to be convoluted according to (1).
- the depth-time conversion law used for this is directly deduced from the evolution of the velocity V P along the well.
- FIG. 4 illustrates a first way to carry out this verification.
- the left part of FIG. 4 shows the logs V P (t) and p (t) measured as a function of the depth at the base time and converted to be expressed as a function of the propagation time, as well as several hypotheses AVp / Vp, ⁇ / ⁇ of variation of the parameters in the permeable layers 20, 30.
- a (t) M (t) - B (t). This difference A (t) is compared to the difference
- ⁇ ( ⁇ ) ⁇ ⁇ ( ⁇ ) - A B (t) between measured base and monitor traces. The difference
- ⁇ ( ⁇ ) - ⁇ ( ⁇ ) is minimized according to the variation hypotheses ⁇ ⁇ / Vp, ⁇ / ⁇ in order to select the hypothesis that best accounts for the evolution of the seismic trace.
- the optimization can consist of scanning a large number of assumptions ⁇ ⁇ / Vp, ⁇ / ⁇ and retaining the one that provides the smallest mean value of
- Another possibility is to select a hypothesis ⁇ / ⁇ / ⁇ ⁇ / ⁇ when the time average of
- minimization algorithms may be applied, for example genetic algorithms or simulated annealing, which do not require gradient calculation and are not trapped in local minima.
- FIG. 5 Such an embodiment is illustrated in FIG. 5, where one sees in the left part logs V P (t), p (t) as a function of time and a hypothesis.
- FIG. 5 also shows a base seismic trace A B (t) measured before the production of the well.
- This pseudo-trace A ' M (t) is expressed in the time reference of the base time.
- the time scale must be modified to reduce the pseudotrace in the time reference of the monitor time and thus obtain a second pseudo-trace A " M (t) shown in the right part of Figure 5.
- the temporal change of scale is performed in order to compensate for the difference between the depth-time conversion law applicable to the base time (curve 15) and the depth-time conversion law applicable to the monitoring time (curve 16).
- the optimization uses a cost function given by the difference between the measured seismic trace M (t) and the seismic pseudo-trace A " M (t) calculated from the previously described, for example the sum of the squares or the sum of the absolute values of this difference.
- An advantageous embodiment starts from the measured seismic trace and returns it to the reference frame of the base seismic trace.
- the cost function intervening in the optimization is then given by the difference between this pseudo-trace A " B (t) and the measured basic seismic trace A B (t).
- FIG. 6 illustrates an alternative embodiment implementing an approximate method inspired by that of FIG. 5.
- this method is applicable independently of a well. It is particularly applicable to search for the evolution of the parameters V P , p in geological layers whose positioning along a typically vertical direction is determined according to the reservoir grid determined for the exploitation of the zone considered.
- the modification A (t) of the basic seismic trace expressed in the base time reference is not calculated from logs measured using formulas (2) and (3) above. It is expressed directly as a function of the impedance variation ⁇ ⁇ / ⁇ ⁇ corresponding to the assumption of variation of the propagation velocity V P and of the density p:
- the relative amplitude variation ⁇ / ⁇ is approximatively estimated as being proportional to the relative impedance variation ⁇ ⁇ / ⁇ ⁇ , the proportionality coefficient being the amplitude of the ringlet w (t) representing the signal. incident seismic.
- a second pseudo-trace A " M (t) is computed by time scale change to be compared with the measured seismic trace A M (t), the result of the comparison then serves as a cost function for the
- the trace 18 represented in dotted line corresponds to the first pseudo-trace A ' M (t) computed without approximation in the manner described with reference to FIG. 5. It can be seen that the pseudo-trace approximated differs slightly from this near the edges of the permeable layers.
- the speed of propagation of the pressure waves V P and the density p are sufficient to model the propagation of the waves picked up by the detector 12.
- the method described above is also applicable in the case where an offset exists between the source 1 1 and the detector 12 as shown in FIG. 7.
- the impedance variation ⁇ / ⁇ occurring in the approximate method illustrated in FIG. 6 also depends on the speed of propagation of the shear waves V ⁇ via the angle ⁇ d. impact of the wave on the interface:
- V s of propagation of the shear waves in the elastic parameters taken into account in the variation hypotheses.
- the method thus gives access to estimates of the speed V s .
- One possibility is to evaluate V P and p in a first step from seismic traces recorded at normal incidence (FIG. 1), and then to make hypotheses of variation of the only parameter V s to realize the optimization according to this parameter in a second step from seismic traces recorded with offset.
- the method described above in various embodiments takes advantage of geophysical information (seismic traces) and information commonly available to reservoir engineers (the layered modeling of the subsoil). It provides a new mode of analysis of 4D seismic data to take into account information a priori on the geological and dynamic behavior of the study area.
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB1300805.7A GB2496329B (en) | 2010-07-21 | 2011-07-19 | Method for estimating elastic parameters through inversion of 4D seismic measures |
CA2805688A CA2805688A1 (fr) | 2010-07-21 | 2011-07-19 | Procede d'estimation de parametres elastiques par inversion de mesures sismiques 4d |
US13/811,378 US9690001B2 (en) | 2010-07-21 | 2011-07-19 | Method for estimating elastic parameters through inversion of 4D seismic measures |
NO20130228A NO345295B1 (no) | 2010-07-21 | 2013-02-11 | Metode for å anslå elastiske parametere ved hjelp av inversjon av 4D seismiske målinger. |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
FR1055945A FR2963111B1 (fr) | 2010-07-21 | 2010-07-21 | Procede d'estimation de parametres elastiques par inversion de mesures sismiques 4d |
FR1055945 | 2010-07-21 |
Publications (2)
Publication Number | Publication Date |
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WO2012010790A2 true WO2012010790A2 (fr) | 2012-01-26 |
WO2012010790A3 WO2012010790A3 (fr) | 2012-05-10 |
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Application Number | Title | Priority Date | Filing Date |
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PCT/FR2011/051720 WO2012010790A2 (fr) | 2010-07-21 | 2011-07-19 | Procede d'estimation de parametres elastiques par inversion de mesures sismiques 4d |
Country Status (6)
Country | Link |
---|---|
US (1) | US9690001B2 (fr) |
CA (1) | CA2805688A1 (fr) |
FR (1) | FR2963111B1 (fr) |
GB (1) | GB2496329B (fr) |
NO (1) | NO345295B1 (fr) |
WO (1) | WO2012010790A2 (fr) |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10132945B2 (en) | 2014-07-11 | 2018-11-20 | Total S.A. | Method for obtaining estimates of a model parameter so as to characterise the evolution of a subsurface volume |
US10379244B2 (en) | 2015-01-06 | 2019-08-13 | Total S.A. | Method for obtaining estimates of a model parameter so as to characterise the evolution of a subsurface volume over a time period |
US10393900B2 (en) | 2014-02-12 | 2019-08-27 | Total S.A. | Process for characterising the evolution of an oil or gas reservoir over time |
US10705237B2 (en) | 2014-07-11 | 2020-07-07 | Total S.A. | Method of constraining an inversion in the characterisation of the evolution of a subsurface volume |
Families Citing this family (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB2512372B (en) * | 2013-03-28 | 2020-07-29 | Total Sa | Method of modelling a subsurface volume |
FR3019908B1 (fr) | 2014-04-14 | 2016-05-06 | Total Sa | Procede de traitement d'images sismiques |
CN104330822B (zh) * | 2014-10-23 | 2017-01-18 | 中国石油天然气股份有限公司 | 采用耦合四维地震反演确定剩余油气分布的方法及装置 |
EP3963371A1 (fr) * | 2019-05-02 | 2022-03-09 | BP Corporation North America Inc. | Inversion conjointe de décalage temporel et d'amplitude 4d destinée à une perturbation de vitesse |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5798982A (en) | 1996-04-29 | 1998-08-25 | The Trustees Of Columbia University In The City Of New York | Method for inverting reflection trace data from 3-D and 4-D seismic surveys and identifying subsurface fluid and pathways in and among hydrocarbon reservoirs based on impedance models |
EP1865340A1 (fr) | 2006-06-06 | 2007-12-12 | Total S.A. | Procédé et programme pour la caractérisation temporelle d'un réservoir de pétrole |
WO2008140655A1 (fr) | 2007-05-09 | 2008-11-20 | Exxonmobil Upstream Research Company | Inversion de données sismique 4d |
Family Cites Families (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6321840B1 (en) * | 1988-08-26 | 2001-11-27 | Texaco, Inc. | Reservoir production method |
US4969130A (en) * | 1989-09-29 | 1990-11-06 | Scientific Software Intercomp, Inc. | System for monitoring the changes in fluid content of a petroleum reservoir |
US5487001A (en) * | 1993-05-28 | 1996-01-23 | Neff; Dennis B. | Method for determining petrophysical properties of a subterranean layer |
DK1746443T3 (en) * | 1999-10-22 | 2014-03-17 | Fugro N V | A method of calculating the elastic parameters and stone composition of subterranean formations using seismic data |
US6480790B1 (en) * | 1999-10-29 | 2002-11-12 | Exxonmobil Upstream Research Company | Process for constructing three-dimensional geologic models having adjustable geologic interfaces |
FR2933499B1 (fr) * | 2008-07-03 | 2010-08-20 | Inst Francais Du Petrole | Methode d'inversion conjointe de donnees sismiques representees sur des echelles de temps differentes |
FR2965066B1 (fr) * | 2010-09-20 | 2012-10-26 | Total Sa | Procede d'estimation de parametres elastiques |
-
2010
- 2010-07-21 FR FR1055945A patent/FR2963111B1/fr active Active
-
2011
- 2011-07-19 US US13/811,378 patent/US9690001B2/en active Active
- 2011-07-19 WO PCT/FR2011/051720 patent/WO2012010790A2/fr active Application Filing
- 2011-07-19 CA CA2805688A patent/CA2805688A1/fr not_active Abandoned
- 2011-07-19 GB GB1300805.7A patent/GB2496329B/en active Active
-
2013
- 2013-02-11 NO NO20130228A patent/NO345295B1/no unknown
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5798982A (en) | 1996-04-29 | 1998-08-25 | The Trustees Of Columbia University In The City Of New York | Method for inverting reflection trace data from 3-D and 4-D seismic surveys and identifying subsurface fluid and pathways in and among hydrocarbon reservoirs based on impedance models |
EP1865340A1 (fr) | 2006-06-06 | 2007-12-12 | Total S.A. | Procédé et programme pour la caractérisation temporelle d'un réservoir de pétrole |
WO2008140655A1 (fr) | 2007-05-09 | 2008-11-20 | Exxonmobil Upstream Research Company | Inversion de données sismique 4d |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10393900B2 (en) | 2014-02-12 | 2019-08-27 | Total S.A. | Process for characterising the evolution of an oil or gas reservoir over time |
US10132945B2 (en) | 2014-07-11 | 2018-11-20 | Total S.A. | Method for obtaining estimates of a model parameter so as to characterise the evolution of a subsurface volume |
US10705237B2 (en) | 2014-07-11 | 2020-07-07 | Total S.A. | Method of constraining an inversion in the characterisation of the evolution of a subsurface volume |
US10379244B2 (en) | 2015-01-06 | 2019-08-13 | Total S.A. | Method for obtaining estimates of a model parameter so as to characterise the evolution of a subsurface volume over a time period |
Also Published As
Publication number | Publication date |
---|---|
CA2805688A1 (fr) | 2012-01-26 |
FR2963111A1 (fr) | 2012-01-27 |
NO20130228A1 (no) | 2013-02-11 |
US9690001B2 (en) | 2017-06-27 |
FR2963111B1 (fr) | 2012-09-28 |
US20130121112A1 (en) | 2013-05-16 |
WO2012010790A3 (fr) | 2012-05-10 |
GB201300805D0 (en) | 2013-02-27 |
NO345295B1 (no) | 2020-11-30 |
GB2496329B (en) | 2016-08-17 |
GB2496329A (en) | 2013-05-08 |
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