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    • 专利摘要:
    A process for the exploitation of hydrocarbons from a sedimentary basin comprising at least one layer of carbonate sediments by means of a stratigraphic simulation. From measurements carried out on a rock sample of a carbonate layer of the studied basin, we determine a series of diagenetic stages undergone by the sediments, the parameters of the microstructural model representative of the final diagenetic state of these sediments, as well as the minimum and maximum variations of these parameters for each of the diagenetic steps. The mechanical parameters of the sediments of the layer considered for each of said diagenetic steps are then determined by means of an effective medium modeling and variations of the parameters of the microstructural model determined for each of said steps. Then we take into account the mechanical parameters thus determined for each of the diagenetic steps in a stratigraphic simulation, in order to evaluate the petroleum potential of the studied basin. Application particularly to the exploration and exploitation of oil deposits, for example.
    公开号:FR3037353A1
    申请号:FR1555389
    申请日:2015-06-12
    公开日:2016-12-16
    发明作者:Mathilde Adelinet
    申请人:IFP Energies Nouvelles IFPEN；
    IPC主号:
    专利说明:

    [0001] The present invention relates to the field of exploration and exploitation of oil deposits or geological gas storage sites. Oil exploration involves looking for hydrocarbon deposits within a sedimentary basin. The understanding of the principles of the genesis of hydrocarbons and their links with the geological history of the subsoil has led to the development of methods for evaluating the petroleum potential of a sedimentary basin. The general approach of the assessment of the petroleum potential of a sedimentary basin involves back and forth between a prediction of the petroleum potential of the sedimentary basin, made from available information concerning the studied basin (outcrops, seismic campaigns, drilling for example ), and exploratory drilling in the various areas with the best potential, to confirm or refute the predicted potential, and to acquire new data to feed new, more accurate studies. The oil exploitation of a deposit consists, based on information gathered during the oil exploration phase, to select areas of the deposit with the best oil potential, to define optimal exploitation plans for these zones (for example using a reservoir simulation, to define the number and position of the exploitation wells allowing optimal hydrocarbon recovery), to drill wells and, in general, to set up production infrastructure necessary for the development of the deposit. In some sedimentary basins, which have undergone a complex geological history, interacting with numerous physical processes, or where the volume of data is very important, the evaluation of the petroleum potential of a sedimentary basin usually requires the availability of computer tools. (software running on a computer) allowing the synthesis of available data, and computer tools allowing the simulation of the geological history and the multiple physical processes that control it. This is an approach called "basin modeling". The family of so-called basin modeling software can simulate in one, two or three dimensions, the sedimentary, tectonic, thermal, hydrodynamic and organic and inorganic chemistry processes that occur during the formation of an oil basin. Concerning more particularly the sedimentary processes, the specialists use tools implementing a set of equations simulating the evolution sedimentary 3037353 2 of a basin during the geological time, that is to say from the deposit of the sediments up to at a present time. The simulation of the sedimentary history of a basin requires the consideration of different parameters: (1) the evaluation of the space available for sedimentation, linked to tectonic and / or eustatic movements, (2) l sediment input into the basin, either through boundaries or through in situ production or precipitation, (3) the transport of these sediments into the available space created, (4) the evolution of these sediments during burial, what is called diagenesis. This type of simulation, called stratigraphic simulation, notably allows the specialist to test different hypotheses 10 on the sedimentary processes that have affected a basin, and to update these hypotheses by comparing the result obtained by simulation with the current observed state of sedimentary deposits. of a basin. The DionisosFlowe software (IFP Energies nouvelles, France) is an example of a software, called stratigraphic simulator, implementing a stratigraphic simulation.
    [0002] Diagenesis is therefore one of the major sedimentary processes in the history of a sedimentary basin. Diagenesis consists of the chemical, biochemical and physical transformation of sediments deposited in a basin of compact sedimentary rocks. In fact, sediments that settle in a sedimentary basin are soft and rich in water. These sediments will be subjected, during their progressive burial in the basin, to pressure and temperature conditions that will transform them. This transformation usually occurs at shallow depth and proceeds in different stages depending on the nature of the sediment and the burial conditions. In comparison with clastic sedimentary rocks of the sandstone or clay type, the diagenesis of the carbonate rocks is generally complex, and may in particular consist of numerous chemical and / or biological processes which follow each other one after the other. Since diagenesis increases with time and depth, it is marked by (1) the compaction of sediments with loss of water (mechanical settlement due to the weight of the soil deposited over the sediment, this process tends to reduce the porosity in the rock and increase the contact points between the grains), (2) an increase of the temperature by burial, which favors the chemical reactions and (3) a multiplication of varied and complex reactions such as: the transformation (or epigenization ) some minerals to other minerals (eg dolomitization), dissolution of grains at their contact points, and precipitation (cementation) in intergranular spaces. Moreover, each carbonate rock of each basin undergoes diagenetic clean steps, the intensity of each step may even vary from one point to another of the basin considered. We are talking about a diagenetic path, which can be more or less complex. STATE OF THE ART The following documents will be cited in the description: Adelinet, M., Fortin, J., & Guéguen, Y., 2011a. Dispersion of elastic moduli in a porous-cracked rock: Theoretical predictions for squirt-flow. Tectonophysics, 503 (1), 173-181. Adelinet, M., Dorbath, C., The Ravalec, M., Fortin, J., & Guéguen, Y., 2011b. Deriving microstructure and fluid state within the lcelandic crust from the inversion of tomography data. Geophysical Research Letters, 38 (3). Granjeon, D. & Joseph, P., 1999. Concepts and applications of a 3-D multiple lithology, diffusive model in stratigraphic modeling. Numerical Experiments in Stratigraphy Recent Advances in Stratigraphy and Sedimentology Computer Simulations SEPM Special Publications No. 62. Xu, S., & Payne, M.A. (2009). Modeling elastic properties in carbonate rocks. The Leading Edge, 28 (1), 66-74. The processes involved in the diagenesis of a carbonate rock have the effect of modifying the microstructural parameters of a rock (nature and geometry of the grains forming the rock matrix, nature and geometry of the pores of the rock). In fact, the mechanical properties of the carbonate rock are affected by the chemical and / or biological processes involved during diagenesis. Thus, the diagenetic transformations undergone by a rock during the course of time result in the variation during geological time of the mechanical properties of the rocks (elastic moduli), and even more so in their petrophysical properties (porosity, permeability, for example). The consideration of diagenesis in stratigraphic computer simulation tools is currently limited, since only the impact of sedimentary compaction on the mechanical parameters is simulated numerically. Thus, in the document (Granjeon & Joseph, 1999), conventional compaction laws are described which relate the sediment porosity to burial, thus making it possible to quantify the volume of the sedimentary layers. If such a restriction can be satisfactory (that is, producing a simulation result sufficiently close to reality) for clastic-type sedimentary rocks, it can not lead to a satisfactory simulation of the diagenesis of carbonate rocks. However, carbonate rocks represent more than 50% of the reservoir rocks currently exploited in the world, and it therefore appears important to be able to take into account the phenomenon of diagenesis, in its complexity, in the case of sedimentary basins containing rocks. In particular, it seems important to take into account, in a stratigraphic simulation, the evolutionary aspect in time, induced by diagenesis, of the mechanical parameters of a carbonate rock.
    [0003] The document (Xu and Paine, 2009) which discloses a method for determining mechanical properties of a carbonate rock from experimental measurements is known. More precisely, the mechanical properties are determined from a microstructure model, by testing different values of the parameters of this one (flattening and increase of the porosity). These tests, however, do not consider a change over time in the parameters of the microstructural model, and therefore in the mechanical parameters of the carbonate rocks. The document (Adelinet et al., 2011a) is also known which relates to a method for determining structural properties of a basaltic rock from measurements made in the field and from an actual medium representation. The modeling in an effective medium makes it possible, from a fine description of the microstructure of a rock at the scale of a representative elemental volume (VER), to calculate homogenized mechanical properties on the scale of this volume. In this document, seismic tomography data is used to reverse two microstructural parameters of the actual model: the crack density and the incompressibility modulus of the fluid filling the porosity inclusions. This document does not consider an evolution in time of the parameters of a microstructural model, and therefore of the mechanical parameters of the rock considered.
    [0004] The present invention relates to a method for determining an evolution of the mechanical parameters of a carbonate rock during the different stages of the diagenesis undergone by this rock within a sedimentary basin. These parameters are then taken into account in a stratigraphic simulation, in order to contribute to a better understanding of a sedimentary basin comprising carbonate rocks, and thus to a more reliable oil evaluation of this type of basin.
    [0005] The method according to the invention Thus, the present invention relates to a method of oil exploitation of a sedimentary basin, said basin comprising at least one layer of carbonate sediments. Using a stratigraphic simulator to reconstruct the sedimentary history of said basin from geological time t to present time, using at least one rock sample of said layer and a scale of one Representative Elemental Volume, said scale being determined according to said sample, the method comprises the following steps for said layer: from measurements made on said sample, parameters of a microstructural model representative of the diagenetic state are determined from said layer to said current time, said parameters of said microstructural model being defined at said scale; B. from measurements made on said sample, at least one diagenetic step undergone by said sediments of said layer is identified from said geological time t until said current time, and minimum and maximum variations of said parameters of said microstructural model are determined; for each of said diagenetic steps; C. at least one mechanical parameter of said sediments of said layer is determined for each of said diagenetic steps by means of an effective medium modeling and said variations of said parameters of said microstructural model determined for each of said diagenetic steps; and the following steps: D. the petroleum potential of said basin is evaluated at least by means of said simulator and of said mechanical parameters determined for each of said diagenetic stages, and at least one zone of said basin having said highest petroleum potential is selected. ; E. the basin is operated according to said selected area. Preferably, said measurements may consist of measurements of characterization of said rock carried out under the microscope, by X-ray diffractometry, or by porosimetry.
    [0006] According to one embodiment of the invention, said microstructural parameters may comprise the flexibility of the interfaces between grains of said rock.
    [0007] According to one embodiment of the invention, said flexibility can be assumed to be invariant during said diagenetic steps. According to one embodiment of the invention, at least one of said parameters of said microstructural model can be determined by inverse modeling.
    [0008] Preferentially, said minimum and maximum variations can be determined from measurements made on a number of samples of said rock at least equal to the number of said diagenetic steps.
    [0009] Advantageously, said minimum and maximum variations of the micro-porosity, the macro-porosity, and the mineralogical composition can be determined. According to one embodiment of the invention, from the mechanical parameters determined for each of said diagenetic steps, it is possible to determine the permeability of said layer for each of said diagenetic steps.
    [0010] According to one embodiment of the invention, from the mechanical parameters determined for each of said diagenetic steps, it is possible to determine a cube of synthetic seismic data for each of said diagenetic steps.
    [0011] Preferably, in step D, at least one of the tectonic, thermal, hydrodynamic, and organic and inorganic chemistry processes affecting said pool may be further simulated.
    [0012] Advantageously, in step E, at least one exploitation and / or exploration drilling may be carried out in said zones selected for the recovery of the hydrocarbons present within said basin. Furthermore, the invention relates to a computer program product downloadable from a communication network and / or recorded on a computer-readable and / or executable medium by a processor, including program code instructions for implementation. of the method as described above, when said program is run on a computer.
    [0013] Other features and advantages of the method according to the invention will become apparent on reading the description hereafter of nonlimiting examples of embodiments, with reference to the appended figures and described hereinafter.
    [0014] BRIEF DESCRIPTION OF THE FIGURES FIG. 1 presents an illustrative example of a diagenetic path consisting of four different diagenetic steps. FIG. 2 shows the evolution during diagenesis of the microstructural parameters associated with the example presented in FIG. 1. FIG. 3 shows the evolution of the elastic moduli and elastic velocities as a function of the diagenetic steps determined for FIG. FIG. 4 shows the evolution of the permeability during the diagenetic steps determined for the example presented in FIG. 1.
    [0015] DETAILED DESCRIPTION OF THE PROCESS The following definitions are used during the description of the invention: Modeling in an effective medium: it is a physical model for estimating the effective properties of a medium from the 10 properties of its constituents. Elementary Volume Representative of a medium: it is a volume large enough to define homogeneous and representative properties of the medium studied. Carbonated inclusions: These are solid elements that make up a carbonate rock. It can be bioclasts (fossil elements of animal or vegetable origin, mostly in fragments) or oolites (spheres formed of a nucleus and different envelopes). Study of thin sections: from a sample of thinned rock until it is transparent, the microstructure of the rock is observed in light transmitted by optical microscope. Microstructural model: this is the simplification of the microstructure, seen in microscopy for example, in order to translate it into an effective medium model. The description of a microstructural model comprises at least the characterization of the mineral matrix (nature and geometry of the grains forming the matrix) and the characterization of the porosity inclusions (nature and geometry of the pores). By nature of the mineral matrix, we mean the lithological nature of the grains (for example quartz, clays, limestone). By geometry of the grains forming the matrix, we mean the shape of the grains of the matrix (ellipsoids more or less flattened). By nature of the pores, it is intended to distinguish crack porosity, porosity resulting from dissolution, etc. And by pore geometry, we mean the shape of the pores (coins for cracks for example, or ellipsoids for equant pores).
    [0016] 3037353 9 Parameters or mechanical properties: these are the elastic modules defined in DC mechanics. The elastic behavior of an isotropic and linear homogeneous material is characterized by two independent elastic modules (incompressibility and shear modules) which are intrinsic constants of the material. The invention relates to a method of oil exploitation of a sedimentary basin comprising at least one layer of carbonate sediments. In particular, the invention relates to the modeling, within a stratigraphic simulation, of the phenomenon of diagenesis suffered by carbonate sediments. An important step in the process according to the invention is the mechanical characterization of the diagenesis phenomenon suffered by the carbonate sediments of the studied basin. By petroleum extraction process of a sedimentary basin is meant a process for the exploitation of hydrocarbons present within said sedimentary basin. The present invention requires: to have a stratigraphic simulator according to the prior art: a stratigraphic simulator is a software aimed at reconstructing the sedimentary processes having affected the basin from a geological time t to the present time. The simulation of the sedimentary history of a basin requires the development of systems of equations allowing to estimate: (1) the evaluation of the space available for the sedimentation, linked to tectonic and / or eustatic movements, (2) 25 sediment supply into the basin, either through boundaries, or through in situ production or precipitation, (3) the transportation of such sediments into the available space created, (4) the evolution of these sediments during burial, that is to say diagenesis. By stratigraphic simulator according to the prior art is meant a stratigraphic simulator modeling diagenesis by the single phenomenon of sediment compaction; to have at least one rock sample from each of the carbonate sediment layers of the sedimentary basin studied: this sample may have been taken in situ, for example by coring; To define a scale of a Representative Elemental Volume (VER): the scale of a VER depends on the size of the rock samples made available. This is to overcome any microstructural element disturbing the representativeness of the volume (large crack 5 running through the entire sample, holes not associated with porosity throughout the sample, etc ...). The present invention comprises at least the following steps: Mechanical characterization of diagenesis 1.1. Determination of the parameters of a microstructural model of the current diagenetic state 1.2. Identification of the different diagenetic stages 1.3. Determination of the minimum and maximum variations of microstructural model parameters for each diagenetic step 1.4. Determination of the Mechanical Parameters by Modeling in an Effective Medium for Each of the Diagenetic Steps Evaluation of the Petroleum Potential Exploitation of the Sedimentary Basin The main steps of the present invention are detailed below. They are illustrated on a (non-limiting) example of a diagenetic pathway undergone by a given layer of carbonate sediments. 1. Mechanical Characterization of Diagenesis The purpose of this first step consists in the mechanical characterization of the diagenesis that affected the carbonate sediment layers of the sedimentary basin studied. This step can be divided, not limited, into four substeps, applicable parallel or sequentially to each of the carbonate sediment layers of the studied basin. The four substeps in question are detailed for a given carbonate sediment layer. 3037353 11 1.1. Determining the parameters of a microstructural model of the current diagenetic state 5 During this sub-step, it is necessary to determine the parameters of a microstructural model representative of the current diagenetic state of the carbonate sediment layer considered. , based on experimental measurements carried out on at least one rock sample of the considered layer. According to the invention, the parameters of the microstructural model are defined on the scale of a Representative Elemental Volume (VER), so that these parameters can be exploited by an effective medium approach in the sub-step 1.4 described later. A sample of rock, taken for example by coring, gives access to the parameters of the microstructural model of the final diagenetic state of the rock studied. Indeed, some steps in the process of forming the rock 15 taken at the present time are no longer visible only in the form of traces or geometric elements (mineral phase included or surrounding another for example). Thus, during this step, measurements are taken on a sample taken at the current time in order to determine the microstructural parameters representative of the mineral matrix (nature and geometry of the grains forming the matrix) and the microstructural parameters representative of the porosity inclusions. (nature and geometry of the pores). According to the invention, direct sample measurements are used by at least one of the following techniques: a microscopic study, carried out for example using an optical or scanning electron microscope: a microscopic study makes it possible to characterize the matrix of the studied rock as well as its porosity. Thus, by microscopic study, one can access the geometry and arrangement of the solid phases (the matrix), and the geometry and arrangement of the porosity of the rock. The matrix, the crystalline inclusions and the porosity supports (spherical pores or cracks for example) can then be indicated on the scale of a representative elementary volume (VER); X-ray diffractometry (XRD), carried out using a diffractometer: X-ray diffractometry makes it possible to quantify the various mineralogical phases of a given sample, which makes it possible to provide a volume fraction of the solid inclusions to the scale of a Representative Elemental Volume (VER); A porosimetry, performed using a nuclear magnetic resonance spectrometer (NMR), a mercury porosimeter or a helium porosimetron: this type of measurement makes it possible to quantify the ratio between the micro -porosity and macro-porosity at the scale of a Representative Elemental Volume (VER). According to one embodiment of the invention, in order to complete the microstructural model, it is possible to resort to inverse modeling carried out on the basis of measurements on at least one sample of the carbonate rock studied.
    [0017] Indeed, the carbonate rocks are often characterized by a heterogeneous mineralogical arrangement, which leads to a complexification in the mechanical response of these rocks. Certain parameters of the microstructural model, in particular the flexibility existing between the different carbonate inclusions (bioclasts, oolites, for example), can not then be directly approximated by measurements. To quantify these parameters, we can then resort to inverse modeling. Reverse modeling is an iterative inversion technique. More precisely, an objective function is constructed measuring the difference between experimental data and theoretical data, calculated from initial values for the parameters to be determined, and then the values of these parameters, iteration after iteration, are modified until find a minimum of the objective function. Numerous objective function minimization algorithms are known to the specialist, such as the Gauss-Newton method, the Newton-Raphson method or the conjugate gradient. According to a preferred embodiment of the present invention, the Gauss-Newton method is used. According to an embodiment of the present invention, the experimental data of the objective function are ultrasonic measurements of the compression seismic wave velocities (P waves) and seismic shear waves (S waves). These measurements may have been obtained in the laboratory, or may have been obtained by a seismic acquisition campaign followed by seismic treatment, and scaling as presented in the application FR 2951555 (US 12/908130 ). According to an embodiment of the present invention, the calculation of the theoretical speeds, from values of the microstructural parameters to the current iteration, can be obtained by modeling in an effective medium as described in (Adelinet et al, 2011b).
    [0018] Theoretical data are then compared to the experimental data, and the inverse modeling makes it possible to minimize the difference between these two data sets, by adjusting the values of the microstructural parameters sought.
    [0019] Thus, at the end of this first sub-step, a microstructural model is obtained, given at the scale of a Representative Elemental Volume (ERV) representative of the diagenetic state at the present time of the carbonate sediment layer. considered. 10 1.2. Identification of the different diagenetic stages During this sub-step, it is a question of identifying the different diagenetic stages through which the carbonate rock of the studied sedimentary basin has passed, based on measurements made on at least one sample of the rock. carbonate studied. According to the invention, at least one diagenetic step is identified. Preferentially, several diagenetic steps are identified. If the rock samples taken at the current time provide information on a final diagenetic state from a mechanical properties point of view, a fine study of the microstructure via thin sections provides information on the diagenetic history experienced by the rock. Indeed, some early stages have only been partially erased by the late stages and can therefore still be identified. From different thin slats, the carbonatic geologist is able to identify and order the different processes undergone by the carbonate rock during diagenesis, such as cementation, dolomitization, aragonitization or dissolution. Figure 1 presents an illustrative diagram of the diagenetic path followed by a given carbonate rock. Thus, this Figure presents a succession of images, each image simulating a microscopic visualization of a sample of the rock considered for a given diagenetic step. The diagenetic path of the rock considered consists of four diagenetic stages: a cementing step 50 (the grains being represented in medium gray), a dissolution step 51 (resulting in the formation of macro-porosity, represented by white ellipses) , a S2 dolomitization step (resulting in the replacement of calcite minerals by dolomite), and an S3 dissolution step (resulting in the formation of micro-porosity, represented by white intra-grain ellipses). 1.3.3. Determination of the Minimum and Maximum Variations of the Parameters of the Microstructural Model for Each of the Diagenetic Steps During this sub-step, it is necessary to determine the limits of variation of the parameters of the microstructural model determined in step 1.1, and this, for each of the diagenetic steps identified in step 1.2. For this step, it is assumed that a sample of the carbonated layer considered, or even a part of a sample, has not undergone the same diagenetic progress stage as another sample of this layer, respectively, or another part of the same sample. Thus, measurements of microstructural parameters can be different from one sample to another, or even from one part of a sample to another. According to the invention, the minimum and maximum values of the parameters of the microstructural model are determined from measurements made on at least one rock sample of the carbonate layer. Preferentially, the minimum and maximum values of the parameters of the microstructural model are evaluated on several samples in order to benefit from the dispersion of the measurements. Preferentially, the minimum and maximum values of the microstructural model parameters are determined from a number of rock samples at least equal to the number of diagenetic steps identified in step 1.2.
    [0020] According to the invention, the measurements used for the determination of the minimum and maximum values of the mechanical parameters are carried out by at least one of the techniques described in step 1.1 (that is to say a microscopic study, a diffractometry, a porosimetry). In particular, the study of thin sections allows quantification of microstructural parameters such as the replacement of calcite crystals by dolomite crystals, the incomplete filling of a porosity with a mineral phase. According to one embodiment of the invention, the specialist fixes at least one terminal of variations of at least one mechanical parameter to a predefined value. For example, if a sample or the number of available samples does not allow access to a variation terminal of one of the mechanical parameters, the specialist can set this bound from existing database in the domain, from this general knowledge, etc. According to a preferred embodiment of the invention, at least the minimum and maximum values of the micro-porosity, the macro-porosity and the mineralogical composition are identified. By varying the parameters of the microstructural model between these minimum and maximum values over time (the duration of each diagenetic step can be chosen arbitrarily), the evolution of the parameters of the microstructural model during the various stages is then available. diagenetic diagenetic path established in step 1.2 above. Thus, FIG. 2 shows the evolution, during diagenesis, of the microstructural parameters associated with the example 5 presented in FIG. 1. More specifically, FIG. 2A shows the evolution of the (macro) porosity of magnitude. without unit between 0 and 1) during the diagenetic step Si, Figure 2B shows the evolution of the ratio R (unitless quantity between 0 and 1) of replacement of calcite by dolomite during the diagenetic step S2, and Figure 20 shows the evolution of the (micro) porosity 10 during the diagenetic step S3. According to one embodiment in which the microstructural model comprises the flexibility of the inter-grain interfaces (see step 1.1), it is assumed that this flexibility is invariant during the diagenetic steps. 1.4. Determination of the mechanical parameters by modeling in an effective medium for each of the diagenetic steps During this step, starting from the microstructural parameters defined in step 1.1 and the evolution of these parameters during the different diagenetic stages determined at step 1.3, at least one mechanical parameter of the carbonate rock studied by modeling in an effective medium is determined for each of the diagenetic steps identified in step 1.2. Preferably, and in the case of an isotropic rock, two mechanical parameters are determined: the incompressibility module and the shear modulus. The modeling in an effective medium allows, from a fine description of the microstructure of a rock at the scale of a Representative Elemental Volume (VER), to calculate the homogenized mechanical properties. As the evolution of the microstructural parameters has been determined during the different diagenetic steps identified, the mechanical properties are calculated directly by homogenization for each of the steps of the diagenetic path. This calculation is based on the resolution of the Eshelby problem, that is to say on the resolution of the perturbation induced in the first order by the presence of an ellipsoidal inclusion in a matrix.
    [0021] In the example shown in FIG. 1, several inclusions being present in the matrix, this is referred to as an Eshelby auxiliary problem. In this case, averaging methods are used to calculate the mechanical parameters of the medium. These calculations are done in one isotropic case and two independent EM elastic moduli are calculated during the diagenetic path. Thus, FIG. 3A shows in full line the evolution during diagenesis of the bulk modulus, which is a constant specific to the material studied, relating the stress to the deformation rate of an isotropic material subjected to isostatic compression. FIG. 3A also shows in dashed line the evolution during diagenesis of the shear modulus ("shear modulus"), which is an intrinsic constant of the studied material, which is involved in the characterization of the deformations caused by stress. Shear connecting the stress to the deformation rate of an isotropic material subjected to isostatic compression. Moreover, from the evolution of the elastic modules during the diagenesis and by solving the Christoffel equation, we can deduce the evolution of the velocities V of the seismic waves P (solid curve in Figure 3B) and S (dotted line curve in Figure 3B) during diagenesis. According to an embodiment of the present invention, during this step the consistency between the result of the modeling obtained by the present invention and the experimental measurements representative of the terminal diagenetic step is checked. Thus, FIG. 3B shows by triangles the measurements of seismic wave velocities P and S made in the laboratory (ultrasonic measurements for example) on rock samples. According to another embodiment of the present invention, from the mechanical properties evaluated for each step of the diagenetic path, the permeability of the carbonate rock is determined for each step of the diagenetic path. To do this, the effective medium models, initially filled in mechanical properties, are converted into permeability. We thus have access to the evolution of the permeability k during the various stages of diagenesis, as shown in FIG. 4. The specialist has perfect knowledge of methods for transforming mechanical parameters into permeability. According to another embodiment of the present invention, from the mechanical properties determined for each step of the diagenetic path, so-called synthetic seismic data cubes are constructed for each of the diagenetic steps identified. To do this, a seismic impedance cube is constructed for each diagenetic step, based on the mechanical properties determined for the step in question. Then, a seismic data simulation technique is used which makes it possible, from a seismic wavelet, to transform these impedance cubes into synthetic seismic data. The specialist has perfect knowledge of methods for transforming mechanical properties into seismic impedances, and transforming seismic impedances into synthetic seismic data. The synthetic seismic data cube obtained by the present invention can then be compared for the final diagenetic step with a cube of actual seismic data. Depending on the conclusions of this comparison, the specialist can deduce if certain assumptions made about the parameters of the stratigraphic simulation are relevant or not, and, consequently, modify or not the parameters in question.
    [0022] Thus, the present invention makes it possible to make the link between the geological and sedimentological description of the different diagenetic stages undergone by a carbonate rock and the mechanical, and possibly petrophysical and / or seismic, properties of the rock during these different diagenetic stages. 2. Evaluation of the petroleum potential At the end of the preceding step, a modeling of the evolution of the mechanical parameters of a carbonate rock over time is obtained. According to the invention, this modeling is taken into account in a stratigraphic simulation, thus making it possible to contribute to a better understanding of the sedimentary history of the studied basin. In addition, other tools of the pond modeling family can be used to simulate the tectonic, thermal, hydrodynamic and organic and inorganic chemistry processes that have affected the studied basin. An example of such a basin modeling tool is the TEMISFLOW software (IFP Energies nouvelles, France). Thus, at the end of this step, the specialist can have information on: i. the establishment of sedimentary layers, ii. the effects of diagenesis on the deposited sediments, iii. their warming during their burial, iv. changes in fluid pressures resulting from this burial, formation of hydrocarbons formed by thermogenesis, viii. the displacement of these hydrocarbons in the basin under the effect of buoyancy, capillarity, differences in pressure gradients, vii. the quantity of hydrocarbons resulting from thermogenesis. On the basis of such information, the specialist then has knowledge of the zones 5 of said basin containing hydrocarbons, as well as the content, the nature and the pressure of the hydrocarbons trapped therein. The specialist is then able to select the zone (s) of the studied basin presenting the best oil potential. 3. Exploitation of the sedimentary basin The petroleum exploitation of the basin can then take several forms, in particular: the carrying out of exploratory drilling in the various zones selected as presenting the best potential, in order to confirm or invalidate the previously estimated potential, and to acquire new data to feed new and more accurate studies, the definition of optimal exploitation schemes for the selected areas, for example using a reservoir simulation, in order to define the number and 20 positions of exploitation wells allowing optimal hydrocarbon recovery, the realization of exploitation drilling (producing wells or injectors) for the recovery of hydrocarbons present in the sedimentary basin in the areas selected as having the best potential, 25 the implementation place the necessary production infrastructure for the development of the is lying. Furthermore, the invention relates to a computer program product downloadable from a communications network and / or recorded on a computer-readable and / or executable medium by a processor, comprising program code instructions. for the implementation of the method as described above, when said program is run on a computer.
    权利要求:
    Claims (12)
    [0001]
    CLAIMS1) A method of oil exploitation of a sedimentary basin, said basin comprising at least one layer of carbonate sediments, using a stratigraphic simulator to reconstruct the sedimentary history of said basin from a geological time t up to a time current, by means of at least one rock sample of said layer and a scale of a representative Elemental Volume, said scale being determined according to said sample, characterized in that the following steps are carried out for said layer: A. from measurements made on said sample, parameters of a microstructural model representative of the diagenetic state of said layer are determined at said current time, said parameters of said microstructural model being defined at said scale; B. from measurements made on said sample, at least one diagenetic step undergone by said sediments of said layer from said geological time t is identified until said current time, and minimum and maximum variations of said parameters of said microstructural model are determined for each of said diagenetic steps; C. at least one mechanical parameter of said sediments of said layer is determined for each of said diagenetic steps, by means of an effective medium modeling and said variations of said parameters of said microstructural model determined for each of said diagenetic steps; and in that the following steps are carried out: D. the petroleum potential of said basin is evaluated at least by means of said simulator and of said mechanical parameters determined for each of said diagenetic stages, and at least one zone of said basin having said petroleum potential is selected The highest ; E. said basin is operated according to said selected area. 3037353 20
    [0002]
    2) Method according to the preceding claim, wherein said measurements consist of measurements of characterization of said rock carried out under the microscope, by X-ray diffractometry, or by porosimetry. 5
    [0003]
    3) Method according to one of the preceding claims, wherein said microstructural parameters comprise the flexibility of the interfaces between grains of said rock.
    [0004]
    4. The method of claim 3, wherein said flexibility is assumed to be invariant during said diagenetic steps.
    [0005]
    5) Method according to one of the preceding claims, wherein is determined at least one of said parameters of said microstructural model by inverse modeling. 15
    [0006]
    6) Method according to one of the preceding claims, wherein said minimum and maximum variations are determined from measurements made on a number of samples of said rock at least equal to the number of said diagenetic steps. 20
    [0007]
    7) Method according to one of the preceding claims, wherein said minimum and maximum variations of the micro-porosity, the macroporosity, and the mineralogical composition are determined. 25
    [0008]
    8) Method according to one of the preceding claims, wherein from the mechanical parameters determined for each of said diagenetic steps, the permeability of said layer is determined for each of said diagetic steps. 30
    [0009]
    9) Method according to one of the preceding claims, wherein from the mechanical parameters determined for each of said diagenetic steps, is determined a cube of synthetic seismic data for each of said diagenetic steps. 3037353 21
    [0010]
    10) Method according to one of the preceding claims, wherein, in step D, is further simulated at least one process selected from the tectonic processes, thermal, hydrodynamic, and organic and inorganic chemistry having affected said basin. 5
    [0011]
    11) Method according to one of the preceding claims, wherein, in step E, is carried out at least one drilling operation and / or exploration in said selected areas for the recovery of hydrocarbons present within said basin. 10
    [0012]
    12) Computer program product downloadable from a communication network and / or recorded on a computer readable medium and / or executable by a processor, comprising program code instructions for the implementation of the method according to one of the preceding claims, when said program is run on a computer.
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    同族专利:
    公开号 | 公开日
    CA2932639A1|2016-12-12|
    EP3104199B1|2021-08-04|
    EP3104199A1|2016-12-14|
    BR102016013243A2|2017-06-06|
    MX2016007403A|2017-01-24|
    AU2016203854A1|2017-01-05|
    FR3037353B1|2017-06-09|
    引用文献:
    公开号 | 申请日 | 公开日 | 申请人 | 专利标题
    DE19912250A1|1998-03-20|1999-09-30|Inst Francais Du Petrole|Method of automatic modeling of stratigraphic structure of underground region|
    EP2816377A1|2013-06-20|2014-12-24|IFP Energies nouvelles|Method for predicting the amount and composition of fluids produced by mineral reactions operating in a sedimentary basin|
    FR2951555B1|2009-10-21|2011-11-18|Inst Francais Du Petrole|METHOD FOR INTERPRETING REPEATING SEISMIC RECORDINGS IN ACCORDANCE WITH THE SEISMIC FREQUENCY BAND IN EVALUATING PORE PRESSURES|FR3067127B1|2017-06-02|2020-10-09|Ifp Energies Now|PROCESS FOR THE EXPLOITATION OF A SEDIMENTARY BASIN CONTAINING HYDROCARBONS, BY MEANS OF STRATIGRAPHIC MODELING|
    FR3067500B1|2017-06-13|2021-04-16|Ifp Energies Now|PROCESS FOR THE EXPLOITATION OF A SEDIMENTARY BASIN CONTAINING HYDROCARBONS, BY MEANS OF A MODELING OF THE ACCUMULATION OF SOIL ORGANIC MATTER|
    CN109425913A|2017-08-22|2019-03-05|中国石油化工股份有限公司|Carbonate reservoir gassiness sensibility elasticity parameter preferred method and system|
    法律状态:
    2016-06-07| PLFP| Fee payment|Year of fee payment: 2 |
    2016-12-16| PLSC| Search report ready|Effective date: 20161216 |
    2017-06-22| PLFP| Fee payment|Year of fee payment: 3 |
    2018-06-27| PLFP| Fee payment|Year of fee payment: 4 |
    2020-06-26| PLFP| Fee payment|Year of fee payment: 6 |
    2021-06-25| PLFP| Fee payment|Year of fee payment: 7 |
    优先权:
    申请号 | 申请日 | 专利标题
    FR1555389A|FR3037353B1|2015-06-12|2015-06-12|PROCESS FOR OPERATING HYDROCARBONS IN A SEDIMENT BASIN HAVING CARBONATE ROCKS USING STRATIGRAPHIC SIMULATION|FR1555389A| FR3037353B1|2015-06-12|2015-06-12|PROCESS FOR OPERATING HYDROCARBONS IN A SEDIMENT BASIN HAVING CARBONATE ROCKS USING STRATIGRAPHIC SIMULATION|
    EP16305627.8A| EP3104199B1|2015-06-12|2016-05-31|Method for extracting hydrocarbons from a sedimentary basin of carbonated rocks, using a stratigraphic simulation|
    MX2016007403A| MX2016007403A|2015-06-12|2016-06-07|Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation.|
    CA2932639A| CA2932639A1|2015-06-12|2016-06-08|Production process for hydrocarbons in a sedimentary bassin comprising carbonate rocks, by means of stratigraphic simulation|
    BR102016013243A| BR102016013243A2|2015-06-12|2016-06-09|method of exploring hydrocarbons from a sedimentary basin comprising carbonate rocks by stratigraphic simulation|
    AU2016203854A| AU2016203854A1|2015-06-12|2016-06-09|Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation|
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