AU2016203854A1 - Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation - Google Patents
Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation Download PDFInfo
- Publication number
- AU2016203854A1 AU2016203854A1 AU2016203854A AU2016203854A AU2016203854A1 AU 2016203854 A1 AU2016203854 A1 AU 2016203854A1 AU 2016203854 A AU2016203854 A AU 2016203854A AU 2016203854 A AU2016203854 A AU 2016203854A AU 2016203854 A1 AU2016203854 A1 AU 2016203854A1
- Authority
- AU
- Australia
- Prior art keywords
- diagenetic
- parameters
- basin
- determined
- stages
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Abandoned
Links
- 239000011435 rock Substances 0.000 title claims abstract description 72
- 238000000034 method Methods 0.000 title claims abstract description 51
- BVKZGUZCCUSVTD-UHFFFAOYSA-L Carbonate Chemical compound [O-]C([O-])=O BVKZGUZCCUSVTD-UHFFFAOYSA-L 0.000 title claims abstract description 44
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 16
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 16
- 238000004088 simulation Methods 0.000 title abstract description 21
- 239000013049 sediment Substances 0.000 claims abstract description 36
- 238000005259 measurement Methods 0.000 claims abstract description 29
- 239000003208 petroleum Substances 0.000 claims abstract description 21
- 230000008569 process Effects 0.000 claims description 12
- 230000035699 permeability Effects 0.000 claims description 8
- 238000002441 X-ray diffraction Methods 0.000 claims description 5
- 238000011084 recovery Methods 0.000 claims description 5
- 238000001311 chemical methods and process Methods 0.000 claims description 4
- 238000004590 computer program Methods 0.000 claims description 4
- 238000002459 porosimetry Methods 0.000 claims description 4
- 238000004891 communication Methods 0.000 claims description 3
- 239000000203 mixture Substances 0.000 claims description 3
- 239000011159 matrix material Substances 0.000 description 13
- 230000006870 function Effects 0.000 description 8
- 239000011148 porous material Substances 0.000 description 8
- 238000009933 burial Methods 0.000 description 7
- 238000012512 characterization method Methods 0.000 description 7
- 238000005553 drilling Methods 0.000 description 7
- 229910052500 inorganic mineral Inorganic materials 0.000 description 7
- 239000011707 mineral Substances 0.000 description 7
- 230000015572 biosynthetic process Effects 0.000 description 6
- 239000000463 material Substances 0.000 description 6
- 238000004090 dissolution Methods 0.000 description 5
- 238000004519 manufacturing process Methods 0.000 description 5
- 239000004215 Carbon black (E152) Substances 0.000 description 4
- 238000004364 calculation method Methods 0.000 description 4
- 238000005056 compaction Methods 0.000 description 4
- 239000012071 phase Substances 0.000 description 4
- 230000009466 transformation Effects 0.000 description 4
- 229910021532 Calcite Inorganic materials 0.000 description 3
- 239000010459 dolomite Substances 0.000 description 3
- 229910000514 dolomite Inorganic materials 0.000 description 3
- 239000012530 fluid Substances 0.000 description 3
- 238000011065 in-situ storage Methods 0.000 description 3
- 238000001556 precipitation Methods 0.000 description 3
- 239000000126 substance Substances 0.000 description 3
- 238000012360 testing method Methods 0.000 description 3
- 238000005481 NMR spectroscopy Methods 0.000 description 2
- 230000008901 benefit Effects 0.000 description 2
- 230000031018 biological processes and functions Effects 0.000 description 2
- 238000006243 chemical reaction Methods 0.000 description 2
- 230000006835 compression Effects 0.000 description 2
- 238000007906 compression Methods 0.000 description 2
- 238000005094 computer simulation Methods 0.000 description 2
- 239000013078 crystal Substances 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 239000006185 dispersion Substances 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000003287 optical effect Effects 0.000 description 2
- 238000011002 quantification Methods 0.000 description 2
- 238000004062 sedimentation Methods 0.000 description 2
- 239000007787 solid Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 230000035924 thermogenesis Effects 0.000 description 2
- 238000003325 tomography Methods 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 101100494265 Caenorhabditis elegans best-15 gene Proteins 0.000 description 1
- 101000684437 Homo sapiens Selenoprotein M Proteins 0.000 description 1
- 235000019738 Limestone Nutrition 0.000 description 1
- 238000002940 Newton-Raphson method Methods 0.000 description 1
- 102100023647 Selenoprotein M Human genes 0.000 description 1
- 238000013459 approach Methods 0.000 description 1
- 230000008859 change Effects 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- -1 clays Substances 0.000 description 1
- 238000002939 conjugate gradient method Methods 0.000 description 1
- 239000000470 constituent Substances 0.000 description 1
- 230000008021 deposition Effects 0.000 description 1
- 238000010586 diagram Methods 0.000 description 1
- 238000006073 displacement reaction Methods 0.000 description 1
- 238000002474 experimental method Methods 0.000 description 1
- 239000012634 fragment Substances 0.000 description 1
- 239000000446 fuel Substances 0.000 description 1
- 239000007789 gas Substances 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 239000001307 helium Substances 0.000 description 1
- 229910052734 helium Inorganic materials 0.000 description 1
- SWQJXJOGLNCZEY-UHFFFAOYSA-N helium atom Chemical compound [He] SWQJXJOGLNCZEY-UHFFFAOYSA-N 0.000 description 1
- 238000000265 homogenisation Methods 0.000 description 1
- 238000002347 injection Methods 0.000 description 1
- 239000007924 injection Substances 0.000 description 1
- 239000006028 limestone Substances 0.000 description 1
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 description 1
- 229910052753 mercury Inorganic materials 0.000 description 1
- 238000000386 microscopy Methods 0.000 description 1
- 238000012856 packing Methods 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 239000010453 quartz Substances 0.000 description 1
- 238000011160 research Methods 0.000 description 1
- 230000004044 response Effects 0.000 description 1
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N silicon dioxide Inorganic materials O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 1
- 239000007790 solid phase Substances 0.000 description 1
- 238000003860 storage Methods 0.000 description 1
- 238000003786 synthesis reaction Methods 0.000 description 1
- 238000000844 transformation Methods 0.000 description 1
- 235000013311 vegetables Nutrition 0.000 description 1
- 238000012800 visualization Methods 0.000 description 1
Classifications
-
- G01V20/00—
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
-
- 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
- G01V2210/66—Subsurface modeling
- G01V2210/661—Model from sedimentation process modeling, e.g. from first principles
Abstract
- Method of exploiting hydrocarbons from a sedimentary basin comprising at least one layer of carbonate sediments, by means of stratigraphic simulation. - From measurements carried out on a rock sample from a carbonate layer of the basin studied, a series of diagenetic stages undergone by the sediments, the parameters of the microstructural model representative of the final diagenetic state of these sediments, and the minimum and maximum variations of these parameters for each diagenetic stage are determined. The mechanical parameters of the sediments of the layer considered are subsequently determined for each of said diagenetic stages, using effective medium modelling and the microstructural model parameter variations determined for each of said stages. The mechanical parameters thus determined are then taken into account for each diagenetic stage in a stratigraphic simulation in order to assess the petroleum potential of the basin studied. - Application: notably petroleum reservoir exploration and exploitation for example. 7R47504 1 (GHMattr) P1 03290 Al J . . . . .. . . . . . . . . . . . . . . . . . . . . . . . . . . "Xx 'Nx N' x, .. .. . .. . ... x > K*xxx:X 'Figure
Description
1 2016203854 09 Jun2016
METHOD OF EXPLOITING HYDROCARBONS FROM A SEDIMENTARY BASIN COMPRISING CARBONATE ROCKS, BY MEANS OF STRATIGRAPHIC
SIMULATION
FIELD OF THE INVENTION 5 The present invention relates to the field of petroleum reservoir or geological gas storage site exploration and exploitation.
Petroleum exploration consists in seeking hydrocarbon reservoirs within a sedimentary basin. Understanding the principles of hydrocarbon genesis and the connections thereof with the subsurface geological history has allowed to develop 10 methods for assessing the petroleum potential of a sedimentary basin. The general procedure for assessing the petroleum potential of a sedimentary basin comprises shuttles between a prediction of the petroleum potential of the sedimentary basin, from available data relative to the basin studied (outcrops, seismic surveys, drilling data for example), and exploratory drilling operations in the various zones having the best 15 potential, in order to confirm or invalidate the previously predicted potential and to acquire new data intended to fuel new and more precise studies.
Petroleum reservoir exploitation consists, from data collected during the petroleum exploration phase, in selecting the reservoir zones with the best petroleum potential, in defining optimum exploitation schemes for these zones (using reservoir simulation for 20 example in order to define the number and positions of the exploitation wells allowing optimum hydrocarbon recovery), in drilling exploitation wells and, in general terms, in putting in place the production infrastructures necessary for reservoir development.
In some sedimentary basins having a complicated geological history involving many physical processes, or when the volume of data is very large, petroleum potential 25 assessment of a sedimentary basin generally requires software tools (softwares executed by a computer) allowing synthesis of the available data, as well as software tools allowing simulation of the geological history and of the many physical processes that govern it. This procedure is referred to as “basin modelling”. The family of softwares referred to as basin modelling softwares allows to simulate in one, two or 30 three dimensions the sedimentary, tectonic, thermal, hydrodynamic, organic and inorganic chemical processes involved in the formation of a petroleum basin.
Concerning more particularly the sedimentary processes, specialists use tools involving a set of equations simulating the sedimentary evolution of a basin over
7847504J (GHMatters) P103290.AU 2 2016203854 09 Jun2016 geological times, i.e. from sediment deposition to a current time. Simulation of the sedimentary history of a basin requires taking account of various parameters: (1) the assessment of the space available for sedimentation, linked with tectonic and/or eustatic movements, (2) the sediment supply to the basin, either through boundaries, 5 or through the agency of in-situ production or precipitation, (3) the transport of these sediments in the available space created, and (4) the evolution of these sediments during burial, referred to as diagenesis. This type of simulation, referred to as stratigraphic simulation, notably allows specialists to test different hypotheses about the sedimentary processes that have affected the basin and to update these 10 hypotheses by comparing the simulation result obtained with the observed current state of the sedimentary deposits of a basin. The DionisosFlow® software (IFP Energies nouvelles, France) is an example of such a software, referred to as stratigraphic simulator, implementing stratigraphic simulation.
Diagenesis thus is one of the major sedimentary processes in the history of a 15 sedimentary basin. Diagenesis consists in the chemical, biochemical and physical changes affecting sediments that have settled in a basin as compact sedimentary rocks. Indeed, the sediments that settle in a sedimentary basin are loose and water rich. As they are progressively buried in the basin, these sediments undergo pressure and temperature conditions leading to their transformation. This transformation 20 generally occurs in shallow environments and in several stages that vary according to the nature of the sediments and the burial conditions.
In comparison with clastic sedimentary rocks of sandstone or clay type, the diagenesis of carbonate rocks is generally complex and it can notably consist of many chemical and/or biological processes linked together. As diagenesis increases with 25 time and depth, it is characterized by (1) the compaction of the sediments with loss of water (mechanical packing linked with the weight of the layers deposited above the sediments; this process tends to reduce the porosity of the rock and to increase points of contact between grains), (2) an increase in the burial temperature, which promotes chemical reactions, and (3) a multiplication of various complex reactions such as: the 30 transformation (or epigenization) of some minerals to other minerals (dolomitization for example), the dissolution of grains at their contact points and the precipitation (cementation) in inter-grain spaces. Furthermore, each carbonate rock of each basin undergoes specific diagenetic stages, and the intensity of each stage can even vary from one point of the basin considered to another. This is referred to a diagenetic path, 35 which can be more or less complex.
7847504_1 (GHMatters) P103290.AU 3 2016203854 09 Jun2016
BACKGROUND OF THE INVENTION
The following documents are mentioned in the description: - Adelinet, M., Fortin, J., & Gueguen, Y., 2011a. Dispersion of elastic moduli in a porous-cracked rock: Theoretical predictions for squirt-flow. Tectonophysics, 503(1), 5 173-181. - Adelinet, M., Dorbath, C., Le Ravalec, M., Fortin, J., & Gueguen, Y., 2011b. Deriving microstructure and fluid state within the Icelandic 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 10 lithology, diffusive model in stratigraphic modeling. Numerical Experiments in
Stratigraphy Recent Advances in Stratigraphic and Sedimentologic 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. 15 The processes involved in the diagenesis of a carbonate rock result in a change in the microstructural parameters of a rock (nature and geometry of the grains forming the matrix of the rock; 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 that take place during diagenesis. Thus, the diagenetic 20 transformations undergone by a rock over time result in a variation over geological times in the mechanical properties of the rocks (elastic moduli) and, a fortiori, in their petrophysical properties (porosity, permeability for example).
To date, limited consideration is given to diagenesis in stratigraphic computer simulation tools since only the impact of sedimentary compaction on the mechanical 25 parameters is numerically simulated. Thus, the document (Granjeon & Joseph, 1999) describes conventional compaction laws that relate the sediment porosity to the burial, thus allowing the volume of the sedimentary layers to be quantified. Although such a restriction can be satisfactory (i.e. producing a simulation result sufficiently close to reality) for clastic type sedimentary rocks, it cannot lead to a satisfactory simulation of 30 the diagenesis of carbonate rocks.
Now, carbonate rocks represent over 50 % of the reservoir rocks currently exploited worldwide. It is therefore important to be able to properly take account of the diagenesis phenomenon in its complexity in the case of sedimentary basins comprising
7847504 1 (GHMatters) P103290.AU 4 2016203854 09 Jun2016 carbonate rocks. Notably, it seems important to take account, in a stratigraphic simulation, of the diagenesis-induced evolution over time of the mechanical parameters of a carbonate rock.
The document (Xu and Paine, 2009) discloses a method for determining 5 mechanical properties of a carbonate rock from experimental measurements. More precisely, the mechanical properties are determined from a microstructure model by testing various values of the parameters thereof (flattening and porosity increase). These tests do however not consider an evolution over time of the parameters of the microstructural model, and therefore of the mechanical parameters of the carbonate 10 rocks.
The document (Adelinet et al., 2011a) concerns a method for determining structural properties of a basaltic rock from measurements carried out in the field and an effective medium representation. Effective medium modelling allows, from a fine description of the microstructure of a rock on the scale of a Representative Volume 15 Element (RVE), to calculate homogenized mechanical properties on the scale of this volume. In this document, seismic tomography data are used to invert two microstructural parameters of the effective model: the crack density and the bulk modulus of the fluid filling the porosity inclusions. This document does not consider an evolution over time of the parameters of a microstructural model, and therefore of the 20 mechanical parameters of the rock considered.
The object of the present invention is a method allowing to determine an evolution of the mechanical parameters of a carbonate rock over 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 better 25 apprehension of a sedimentary basin comprising carbonate rocks, and therefore to a more reliable petroleum assessment of this type of basin.
SUMMARY OF THE INVENTION
The present invention thus relates to a method for oil exploitation in a sedimentary basin, said basin comprising at least one layer of carbonate sediments. Using a 30 stratigraphic simulator allowing to reconstruct the sedimentary history of said basin from a geological time i to a current time, by means of at least one rock sample from said layer and of a Representative Volume Element scale, said scale being determined as a function of said sample, the method comprises the following stages for said layer:
7847504J (GHMatters) P103290.AU 5 2016203854 09 Jun2016 A. from measurements carried out on said sample, determining parameters of a microstructural model representative of the diagenetic state of said layer at said current time, said parameters of said microstructural model being defined on said scale; B. from measurements carried out on said sample, identifying at least one 5 diagenetic stage undergone by said sediments of said layer from said geological time t to said current time, and determining minimum and maximum variations of said parameters of said microstructural model for each of said diagenetic stage; C. determining at least one mechanical parameter of said sediments of said layer for each of said diagenetic stages, using effective medium modelling and said 10 variations of said parameters of said microstructural model determined for each of said diagenetic stages; and the following stages: D. assessing the petroleum potential of said basin at least by means of said simulator and of said mechanical parameters determined for each of said diagenetic 15 stages, and selecting at least one zone of said basin with the highest said petroleum potential; E. exploiting said basin as a function of said selected zone.
Preferably, said measurements can consist in measurements characterizing said rock carried out with a microscope, by X-ray diffraction or by porosimetry. 20 According to an embodiment of the invention, said microstructural parameters can include the flexibility of the interfaces between grains of said rock.
According to an embodiment of the invention, said flexibility can be supposed to be invariant during said diagenetic stages.
According to an embodiment of the invention, at least one of said parameters of 25 said microstructural model can be determined by inverse modelling.
Preferably, said minimum and maximum variations can be determined from measurements carried out on a number of samples of said rock at least equal to the number of said diagenetic stages.
Advantageously, said minimum and maximum variations can be determined from 30 the microporosity, the macroporosity and the mineralogical composition.
7847504_1 (GHMatters) P103290.AU 6 2016203854 09 Jun2016
According to an embodiment of the invention, from the mechanical parameters determined for each of said diagenetic stages, the permeability of said layer can be determined for each of said diagenetic stages.
According to an embodiment of the invention, from the mechanical parameters 5 determined for each of said diagenetic stages, a synthetic seismic data cube can be determined for each of said diagenetic stages.
Preferably, in stage D, at least one process selected from among the tectonic, thermal, hydrodynamic, organic and inorganic chemical processes that have affected said basin can additionally be simulated. 10 Advantageously, in stage E, at least one exploitation and/or exploration well can be drilled in said selected zones for recovery of the hydrocarbons present in said basin.
Furthermore, the invention relates to a computer program product downloadable from a communication network and/or recorded on a computer-readable medium and/or processor executable, comprising program code instructions for implementing 15 the method according to the description above, when said program is executed on a computer.
BRIEF DESCRIPTION OF THE FIGURES
Other features and advantages of the method according to the invention will be clear from reading the description hereafter of embodiments given by way of non 20 limitative example, with reference to the accompanying figures wherein: - Figure 1 illustrates an example of a diagenetic path made up of four different diagenetic stages, - Figure 2 shows the diagenetic evolution of the microstructural parameters associated with the example shown in Figure 1, 25 - Figure 3 shows the evolution of the elastic moduli and of the elastic velocities as a function of the diagenetic stages determined for the example shown in Figure 1, and - Figure 4 shows the evolution of permeability during the diagenetic stages determined for the example shown in Figure 1.
7847504J (GHMatters) P103290.AU 7 2016203854 09 Jun2016
DETAILED DESCRIPTION
The following definitions are used in the description of the invention: - effective medium modelling: physical modelling allowing to assess the effective 5 properties of a medium from the local properties of its constituents, - Representative Volume Element of a medium: it is a volume of sufficiently large size to be able to define homogeneous properties representative of the medium studied, - carbonate inclusions: solid elements making up a carbonate rock. It can be bioclasts (fossil pieces of animal or vegetable origin, most often in form of fragments) or ooliths 10 (spheres consisting of a nucleus and various envelopes), - thin section study: from a rock sample thinned until it is transparent, the microstructure of the rock is observed by an optical microscope using transmitted light, - microstructural model: simplification of the microstructure, using microscopy techniques for example, for translating it into an effective medium model. The 15 description of a microstructural model comprises at least characterization of the mineral matrix (nature and geometry of the grains forming the matrix) and characterization of the porosity inclusions (nature and geometry of the pores). The nature of the mineral matrix is understood to be the lithologic nature of the grains (quartz, clays, limestone for example). The geometry of the grains forming the matrix is understood to be the 20 shape of the grains of the matrix (more or less flattened ellipsoids). By nature of the pores, it is intended to distinguish between the crack porosity, dissolution porosity, etc. And the geometry of the pores is understood to be the shape of the pores (coin-like shaped cracks for example, or ellipsoids for equant pores), - mechanical parameters or properties: elastic moduli defined in continuous media 25 mechanics. The elastic behaviour of an isotropic and linear homogeneous material is characterized by two independent elastic moduli (bulk and shear moduli) that are intrinsic constants of the material.
The invention relates to a method for oil exploitation in a sedimentary basin comprising at least one layer of carbonate sediments. In particular, the invention 30 relates to modelling, within a stratigraphic simulation, the diagenesis phenomenon undergone by carbonate sediments. An important stage of the method according to the invention is the mechanical characterization of the diagenesis phenomenon undergone
7847504_1 (GHMatters) P103290.AU 8 2016203854 09 Jun2016 by the carbonate sediments of the basin studied. A method for oil exploitation in a sedimentary basin is understood to be a method allowing exploitation of the hydrocarbons present within said sedimentary basin.
The present invention requires: 5 - a stratigraphic simulator according to the prior art: a stratigraphic simulator is a software designed to reconstruct the sedimentary processes that have affected the basin from a geological time ft o the current time. Simulation of the sedimentary history of a basin requires developing systems of equations allowing to appraise: (1) the space available for sedimentation, linked with tectonic and/or eustatic movements, (2) the 10 sediments supplied to the basin, either through the boundaries or through in-situ production or precipitation, (3) the transport of these sediments in the available space created, (4) the evolution of these sediments during burial, i.e. diagenesis. A stratigraphic simulator according to the prior art is understood to be a stratigraphic simulator modelling this diagenesis through the sediment compaction phenomenon 15 alone; - at least one rock sample for each carbonate sediment layer of the sedimentary basin studied: this sample can be taken in situ, by core drilling for example; - defining a Representative Volume Element (RVE) scale: the scale of an RVE is a function of the size of the rock samples available. The goal is to overcome 20 microstructural elements likely to disturb the volume representativity (large crack running through the sample, holes not associated with a porosity in the entire sample, etc.).
The present invention comprises at least the following stages: 1. Mechanical characterization of diagenesis 25 1.1 Determining the parameters of a microstructural model of the current diagenetic state 1.2 Identifying the different diagenetic stages 1.3 Determining the minimum and maximum variations of the microstructural model parameters for each diagenetic stage 30 1.4 Determining the mechanical parameters by effective medium modelling for each diagenetic stage 2. Petroleum potential assessment
7847504J (GHMallers) P103290.AU 9 2016203854 09 Jun2016 3. Sedimentary basin exploitation
The main stages of the present invention are detailed hereafter. They are illustrated with a (non limitative) example of a diagenetic path undergone by a given layer made up of carbonate sediments. 5 1. Mechanical characterization of diaaenesis
The object of this first stage is the mechanical characterization of the diagenesis that has affected the carbonate sediment layers of the sedimentary basin studied. This stage can be broken down, by way of non limitative example, into four substages applicable in parallel or sequentially to each carbonate sediment layer of the basin 10 studied. These four substages are detailed for a given carbonate sediment layer. 1.1 Determining the parameters of a microstructural model of the current diagenetic state
This substage consists in determining the parameters of a microstructural model representative of the current diagenetic state of the carbonate sediment layer 15 considered, from experimental measurements carried out on at least one rock sample from the layer considered. According to the invention, the microstructural model parameters are defined on the scale of a Representative Volume Element (RVE) so as to be able to exploit these parameters through an effective medium approach in substage 1.4 described below. 20 A rock sample taken for example by core drilling allows to obtain the microstructural model parameters of the final diagenetic state of the rock studied. Indeed, some stages of the formation process of the rock taken at the current time are only visible as traces or geometric elements (mineralogical phase included in or surrounding another one for example). 25 Thus, in this stage, measurements are carried out 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). 30 According to the invention, direct measurements are carried out on the sample using at least one of the following techniques:
7847504 1 (GHMatters) P103290.AU 10 2016203854 09 Jun2016 - a microscopic study performed for example with an optical microscope or a scanning electron microscope: a microscopic study allows to characterize the matrix of the rock studied and the porosity thereof. Thus, a microscopic study allows to have access to the geometry and the arrangement of the solid phases 5 (matrix), and to the geometry and the arrangement of the rock porosity. The matrix, the crystalline inclusions and the porosity supports (spherical pores or cracks for example) can then be input at Representative Volume Element (RVE) scale; - X-ray diffraction (XRD) performed using a diffractometer: X-ray diffraction allows 10 to quantify the various mineralogical phases of a given sample, which allows input of a volume fraction of the solid inclusions at Representative Volume Element (RVE) scale; - porosimetry performed using a nuclear magnetic resonance (NMR) spectrometer, a mercury porosimeter or a helium porosimeter: this type of 15 measurement allows to quantify the ratio between microporosity and macroporosity at Representative Volume Element (RVE) scale.
According to an embodiment of the invention, in order to complete the microstructural model, inverse modelling can be applied from measurements on at least one sample of the carbonate rock studied. 20 Indeed, carbonate rocks are often characterized by a heterogeneous mineralogical arrangement, which leads to a complexification in the mechanical response of these rocks. Some parameters of the microstructural model, notably the flexibility that exists between the various carbonate inclusions (bioclasts, ooliths for example), thus cannot be directly approximated by measurements. Quantification of these parameters can 25 then be achieved through inverse modelling.
Inverse modelling is an iterative inversion technique. More precisely, an objective function measuring the difference between experimental data and theoretical data calculated from initial values for the parameters to be determined is constructed, then the values of these parameters are modified iteration after iteration until a minimum is 30 found for the objective function. Many objective function minimization algorithms are known to specialists, such as the Gauss-Newton method, the Newton-Raphson method or the conjugate gradient method. According to a preferred embodiment of the present invention, the Gauss-Newton method is used.
7847504_1 (GHMatters) P103290.AU 11 2016203854 09 Jun2016
According to an embodiment of the present invention, the experimental data of the objective function are ultrasonic measurements of the velocities of the seismic compressional waves (P waves) and of the seismic shear waves (S waves). These measurements may have been obtained in the laboratory or through a seismic 5 acquisition survey, followed by seismic processing and scaling as presented in patent application FR-2,951,555 (US-12/908,130).
According to an embodiment of the present invention, calculation of the theoretical velocities from values of the microstructural parameters at the current iteration can be obtained by effective medium modelling as described in (Adelinet et al., 2011b). 10 The theoretical data are then compared with the experimental data, and inverse modelling allows to minimize the difference between these two sets of data by adjusting the values of the microstructural parameters sought.
Thus, at the end of this first substage, a microstructural model input into a Representative Volume Element (RVE), representative of the diagenetic state at the 15 current time of the carbonate sediment layer considered, is obtained. 1.2 Identifying the different diagenetic stages
This substage consists in identifying the different diagenetic stages undergone by the carbonate rock of the sedimentary basin studied, from measurements carried out on at least one sample of the carbonate rock studied. According to the invention, at 20 least one diagenetic stage is identified. Preferably, several diagenetic stages are identified.
While the rock samples taken at the current time provide information on a final diagenetic state regarding the mechanical properties, a fine study of the microstructure via thin sections provides information about the diagenetic history undergone by the 25 rock. Indeed, some early stages have been only partly erased by later stages and they can therefore still be identified. From different thin sections, the carbonate geologist can identify and order the various processes undergone by the carbonate rock during the diagenesis, such as cementation, dolomitization, aragonitization or dissolution. Figure 1 is an illustrative diagram of the diagenetic path followed by a given carbonate 30 rock. Thus, this figure shows a succession of images, each image simulating a microscope visualization of a sample of the rock considered for a given diagenetic stage. The diagenetic path of the rock considered consists of four diagenetic stages: a cementation stage SO (grains shown in medium grey), a dissolution stage S1 (causing
7847504J (GHMallers) P103290.AU 12 2016203854 09 Jun2016 the formation of macroporosity represented by white ellipses), a dolomitization stage 52 (causing replacement of the calcite minerals by dolomite) and a dissolution stage 53 (causing the formation of microporosity represented by white intra-grain ellipses). 5 1.3 Determining the minimum and maximum variations of the microstructural model parameters for each diaaenetic stage
This substage consists in determining the variation boundaries of the microstructural model parameters determined in stage 1.1 for each diagenetic stage identified in stage 1.2. 10 For this stage, it is assumed that a sample of the carbonate layer considered, or even part of a sample, has not undergone the same state of diagenetic progress as another sample of this layer or another part of a sample respectively. Thus, the microstructural parameter measurements may be different from one sample to another, or from one part of a sample to another. According to the invention, the minimum and 15 maximum values of the microstructural model parameters are determined from measurements carried out on at least one rock sample of the carbonate rock. Preferably, the minimum and maximum values of the microstructural model parameters are assessed with several samples so as to take advantage of the measurement dispersion. Preferably, the minimum and maximum values of the microstructural model 20 parameters are determined from a number of rock samples at least equal to the number of diagenetic stages identified in stage 1.2.
According to the invention, the measurements used for determining the minimum and maximum values of the mechanical parameters are carried out using at least one of the techniques described in stage 1.1 (i.e. microscopic study, X-ray diffraction, 25 porosimetry). In particular, the thin section study allows quantification of the microstructural parameters such as the replacement of calcite crystals by dolomite crystals, the incomplete filling of a porosity by a mineral phase.
According to an embodiment of the invention, the specialist sets at least one variation boundary for at least one mechanical parameter at a predetermined value. 30 For example, if a sample or the number of samples available do not enable access to a variation boundary of one of the mechanical parameters, specialists can set this boundary from existing databases, from their general knowledge, etc.
7847504_1 (GHMatters) P103290.AU 13 2016203854 09 Jun2016
According to a preferred embodiment of the invention, at least the minimum and maximum values of the microporosity, the macroporosity, and the mineralogical composition are identified.
Varying the microstructural model parameters between these minimum and 5 maximum values over time (the duration of each diagenetic stage can be arbitrarily selected) allows to obtain the evolution of the microstructural model parameters during the various diagenetic stages of the diagenetic path established in stage 1.2 above. Thus, Figure 2 shows the evolution, during diagenesis, of the microstructural parameters associated with the example shown in Figure 1. More precisely, Figure 2A 10 shows the evolution of (macro)porosity φ (unitless quantity ranging between 0 and 1) during diagenetic stage S1, Figure 1B shows the evolution of ratio R (unitless quantity ranging between 0 and 1) of replacement of the calcite by dolomite during diagenetic stage S2, and Figure 2C shows the evolution of (micro)porosity φ during diagenetic stage S3. 15 According to an embodiment where the microstructural model comprises the interface flexibility between grains (see stage 1.1), this flexibility is assumed to be invariant during the diagenetic stages. 1.4 Determining the mechanical parameters bv effective medium modelling for each diagenetic stage 20 This stage consists, from the microstructural parameters defined in stage 1.1 and from the evolution of these parameters during the various diagenetic stages determined in stage 1.3, in determining at least one mechanical parameter of the carbonate rock studied by effective medium modelling, for each diagenetic stage identified in stage 1.2. Preferably, in the case of an isotropic rock, two mechanical 25 parameters are determined: the bulk modulus and the shear modulus.
Effective medium modelling allows, from a fine description of the microstructure of a rock at Representative Volume Element (RVE) scale, to calculate the homogenized mechanical properties. Since the evolution of the microstructural parameters has been determined for the various diagenetic stages identified, the mechanical properties are 30 directly calculated by homogenization for each stage of the diagenetic path. This calculation is based on the solution of Eshelby’s problem, i.e. the solution of the first-order perturbation induced by the presence of an ellipsoidal inclusion in a matrix.
7847504 1 (GHMatters) P103290.AU 14 2016203854 09 Jun2016
In the example shown in Figure 1, several inclusions are present in the matrix, the problem is therefore referred to as auxiliary Eshelby’s problem. In this case, mean calculation methods are used to calculate the mechanical parameters of the medium. These calculations are carried out in an isotropic case and two independent elastic 5 moduli EM are calculated along the diagenetic path. Thus, Figure 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 ratio of an isotropic material subjected to isostatic compression. Figure 3A also shows in dotted line the evolution during diagenesis of the shear modulus, which is a constant intrinsic to the material 10 studied, that is involved in the characterization of the deformations caused by shear strains relating the stress to the deformation ratio of an isotropic material subjected to an isostatic compression. Furthermore, from the evolution of the elastic moduli during diagenesis and by solving Christoffel’s equation, it is possible to deduce the evolution of velocities V of the seismic P waves (curve in full line in Figure 3B) and S waves 15 (curve in dotted line in Figure 3B) during diagenesis. According to an embodiment of the present invention, the coherence between the modelling result obtained with the present invention and the experimental measurements representative of the terminal diagenetic stage is checked in this stage. Thus, Figure 3B shows with triangles the seismic P and S wave velocity measurements carried out in the laboratory (ultrasonic 20 measurements for example) on rock samples.
According to another embodiment of the present invention, from mechanical properties assessed for each stage of the diagenetic path, the permeability of the carbonate rock is determined for each stage of the diagenetic path. The effective medium models initially provided as mechanical properties are therefore converted to 25 permeability, which gives access to the evolution of permeability k during the various diagenesis stages, as shown in Figure 4. The specialist has perfect knowledge of methods for converting mechanical parameters to permeability.
According to another embodiment of the present invention, from the mechanical properties determined for each stage of the diagenetic path, seismic data cubes 30 referred to as synthetic are constructed for each identified diagenetic stage. A seismic impedance cube is therefore constructed for each diagenetic stage, from the mechanical properties determined for the stage considered. A seismic data simulation technique allowing these impedance cubes to be converted to synthetic seismic data from a seismic wavelet is then used. The specialist has perfect knowledge of methods 35 for converting mechanical properties to seismic impedances, and for converting
7847504J (GHMallers) P103290.AU 15 2016203854 09 Jun2016 seismic impedances to synthetic seismic data. The synthetic seismic data cube obtained with the present invention for the final diagenetic stage can then be compared with a real seismic data cube. Depending on the conclusions of this comparison, the specialist can deduce whether some hypotheses made on the stratigraphic simulation 5 parameters are pertinent or not and, consequently, modify or not the parameters in question.
The present invention thus allows to make the link between the geological and sedimentologic description of the various diagenetic stages undergone by a carbonate rock and the mechanical, and possibly petrophysical and/or seismic, properties of the 10 rock during these different diagenetic stages. 2. Petroleum potential assessment
Modelling of the evolution of the mechanical parameters of a carbonate rock over time is obtained at the end of the previous stage. According to the invention, this modelling is taken into account in a stratigraphic simulation, thus allowing to contribute 15 to better understanding of the sedimentary history of the basin studied.
Other tools of the basin modelling family can furthermore be used to simulate the tectonic, thermal, hydrodynamic, organic and inorganic chemical processes that have affected the basin studied. An example of such a basin modelling tool is the TEMISFLOW software (IFP Energies nouvelles, France). 20 Thus, at the end of this stage, the specialist can have information about: i. the emplacement of the sedimentary layers, ii. the effects of diagenesis on the sediments thus deposited, iii. the heating thereof during burial, iv. the fluid pressure changes resulting from this burial, 25 v. the formation of hydrocarbons by thermogenesis, vi. the displacement of these hydrocarbons in the basin under the effect of buoyancy, capillarity, pressure gradient differences, vii. the amount of hydrocarbons resulting from thermogenesis.
From such information, the specialist then has knowledge of the zones of said 30 basin comprising hydrocarbons, and of the amount, the nature and the pressure of the
7847504J (GHMatters) P103290.AU 16 2016203854 09 Jun2016 hydrocarbons trapped therein. The specialist can then select the zone(s) of the basin studied with the best petroleum potential. 3. Sedimentary basin exploitation
The petroleum exploitation of the basin can then take a variety of forms, notably: 5 - exploration drilling in the various zones selected for having the best potential, so as to confirm or to invalidate the previously estimated potential and to acquire new data for fuelling new and more precise studies, - definition of optimum exploitation schemes for the zones selected, for example by means of reservoir simulation, in order to define the number and position of the 10 exploitation wells allowing optimum hydrocarbon recovery, - exploitation drilling (production or injection wells) for recovery of the hydrocarbons present within the sedimentary basin in the zones selected for having the best potential, - establishment of the production infrastructures necessary for reservoir development. 15 Computer program product
Furthermore, the invention concerns a computer program product downloadable from a communication network and/or recorded on a computer-readable medium and/or processor executable, comprising program code instructions for implementing the method as described above, when said program is executed on a computer. 20 In the claims which follow and in the preceding description of the invention, except where the context requires otherwise due to express language or necessary implication, the word “comprise” or variations such as “comprises” or “comprising” is used in an inclusive sense, i.e. to specify the presence of the stated features but not to preclude the presence or addition of further features in various embodiments of the 25 invention.
It is to be understood that, if any prior art publication is referred to herein, such reference does not constitute an admission that the publication forms a part of the common general knowledge in the art, in Australia or any other country. 30
7847504J (GHMatters) P103290.AU
Claims (12)
- THE CLAIMS DEFINING THE INVENTION ARE AS FOLLOWS: 1) A method for oil exploitation in a sedimentary basin, said basin comprising at least one layer of carbonate sediments, using a stratigraphic simulator allowing to reconstruct the sedimentary history of said basin from a geological time t to a current time, by means of at least one rock sample from said layer and of a Representative Volume Element scale, said scale being determined as a function of said sample, characterized in that the following stages are carried out for said layer: A. from measurements carried out on said sample, determining parameters of a microstructural model representative of the diagenetic state of said layer at said current time, said parameters of said microstructural model being defined on said scale; B. from measurements carried out on said sample, identifying at least one diagenetic stage undergone by said sediments of said layer from said geological time t to said current time, and determining minimum and maximum variations of said parameters of said microstructural model for each of said diagenetic stage; C. determining at least one mechanical parameter of said sediments of said layer for each of said diagenetic stages, using effective medium modelling and said variations of said parameters of said microstructural model determined for each of said diagenetic stages; and the following stages are carried out: D. assessing the petroleum potential of said basin at least by means of said simulator and of said mechanical parameters determined for each of said diagenetic stages, and selecting at least one zone of said basin with the highest said petroleum potential; E. exploiting said basin as a function of said selected zone.
- 2) A method as claimed in claim 1, wherein said measurements consist in measurements characterizing said rock carried out with a microscope, by X-ray diffraction or by porosimetry.
- 3) A method as claimed in any one of the previous claims, wherein said microstructural parameters include flexibility of the interfaces between grains of said rock.
- 4) A method as claimed in claim 3, wherein said flexibility is supposed to be invariant during said diagenetic stages.
- 5) A method as claimed in any one of the previous claims, wherein at least one of said parameters of said microstructural model is determined by inverse modelling.
- 6) A method as claimed in any one of the previous claims, wherein said minimum and maximum variations are determined from measurements carried out on a number of samples of said rock at least equal to the number of said diagenetic stages.
- 7) A method as claimed in any one of the previous claims, wherein said minimum and maximum variations are determined from the microporosity, the macroporosity and the mineralogical composition.
- 8) A method as claimed in any one of the previous claims wherein, from the mechanical parameters determined for each of said diagenetic stages, the permeability of said layer is determined for each of said diagenetic stages.
- 9) A method as claimed in any one of the previous claims wherein, from the mechanical parameters determined for each of said diagenetic stages, a synthetic seismic data cube is determined for each of said diagenetic stages.
- 10) A method as claimed in any one of the previous claims wherein, in stage D, at least one process selected from among the tectonic, thermal, hydrodynamic, organic and inorganic chemical processes that have affected said basin is additionally simulated.
- 11) A method as claimed in any one of the previous claims wherein, in stage E, at least one exploitation and/or exploration well is drilled in said selected zones for recovery of the hydrocarbons present in said basin.
- 12) A computer program product downloadable from a communication network and/or recorded on a computer-readable medium and/or processor executable, comprising program code instructions for implementing the method as claimed in any one of the previous claims, when said program is executed on a computer.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| FR1555389A FR3037353B1 (en) | 2015-06-12 | 2015-06-12 | PROCESS FOR OPERATING HYDROCARBONS IN A SEDIMENT BASIN HAVING CARBONATE ROCKS USING STRATIGRAPHIC SIMULATION |
| FR15/55.389 | 2015-06-12 |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| AU2016203854A1 true AU2016203854A1 (en) | 2017-01-05 |
Family
ID=54066040
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| AU2016203854A Abandoned AU2016203854A1 (en) | 2015-06-12 | 2016-06-09 | Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation |
Country Status (6)
| Country | Link |
|---|---|
| EP (1) | EP3104199B1 (en) |
| AU (1) | AU2016203854A1 (en) |
| BR (1) | BR102016013243A2 (en) |
| CA (1) | CA2932639A1 (en) |
| FR (1) | FR3037353B1 (en) |
| MX (1) | MX2016007403A (en) |
Families Citing this family (6)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR3067127B1 (en) | 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 (en) | 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 (en) * | 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 |
| CN112184033A (en) * | 2020-09-30 | 2021-01-05 | 中国石油化工股份有限公司 | Carbonate rock stratum fault sealing evaluation method |
| CN113032712B (en) * | 2020-10-26 | 2023-12-22 | 中国石油天然气股份有限公司 | Determination method and device for drilling coincidence information, computer equipment and storage medium |
| CN114137011A (en) * | 2021-12-10 | 2022-03-04 | 西南石油大学 | Method for rebuilding ancient deep dolomite in multi-stage diagenesis process |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| FR2776393B1 (en) * | 1998-03-20 | 2001-09-07 | Inst Francais Du Petrole | METHOD FOR AUTOMATICALLY FORMING A MODEL SIMULATING THE STRATIGRAPHIC STRUCTURE OF AN UNDERGROUND AREA |
| FR2951555B1 (en) | 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 |
| FR3007533B1 (en) * | 2013-06-20 | 2015-07-24 | Ifp Energies Now | PROCESS FOR PREDICTING THE QUANTITY AND COMPOSITION OF FLUIDS PRODUCED BY MINERAL REACTIONS OPERATING IN A SEDIMENT BASIN |
-
2015
- 2015-06-12 FR FR1555389A patent/FR3037353B1/en not_active Expired - Fee Related
-
2016
- 2016-05-31 EP EP16305627.8A patent/EP3104199B1/en active Active
- 2016-06-07 MX MX2016007403A patent/MX2016007403A/en unknown
- 2016-06-08 CA CA2932639A patent/CA2932639A1/en not_active Abandoned
- 2016-06-09 AU AU2016203854A patent/AU2016203854A1/en not_active Abandoned
- 2016-06-09 BR BR102016013243A patent/BR102016013243A2/en not_active Application Discontinuation
Also Published As
| Publication number | Publication date |
|---|---|
| EP3104199B1 (en) | 2021-08-04 |
| CA2932639A1 (en) | 2016-12-12 |
| EP3104199A1 (en) | 2016-12-14 |
| BR102016013243A2 (en) | 2017-06-06 |
| FR3037353A1 (en) | 2016-12-16 |
| MX2016007403A (en) | 2017-01-24 |
| FR3037353B1 (en) | 2017-06-09 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| US10394976B2 (en) | Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation | |
| AU2016203854A1 (en) | Method of exploiting hydrocarbons from a sedimentary basin comprising carbonate rocks, by means of stratigraphic simulation | |
| US10712472B2 (en) | Method and system for forming and using a subsurface model in hydrocarbon operations | |
| Cui et al. | Prediction of diagenetic facies using well logs–A case study from the upper Triassic Yanchang Formation, Ordos Basin, China | |
| CA2692425C (en) | Method, program and computer system for scaling hydrocarbon reservoir model data | |
| Newsham et al. | An integrated work-flow model to characterize unconventional gas resources: part I—geological assessment and petrophysical evaluation | |
| Belhouchet et al. | A new empirical model for enhancing well log permeability prediction, using nonlinear regression method: Case study from Hassi-Berkine oil field reservoir–Algeria | |
| Liu et al. | Quantitative prediction of lower order faults based on the finite element method: A case study of the M35 fault block in the western Hanliu fault zone in the Gaoyou sag, East China | |
| Amour et al. | Effects of porosity and water saturation on the yield surface of Upper Cretaceous reservoir chalks from the Danish North Sea | |
| Martyushev et al. | Evaluation of facies heterogeneity in reef carbonate reservoirs: A case study from the oil field, Perm Krai, Central-Eastern Russia | |
| Lavenu et al. | Background fractures in carbonates: inference on control of sedimentary facies, diagenesis and petrophysics on rock mechanical behavior. Example of the Murge Plateau (southern Italy) | |
| Al-Rubaye et al. | Characterization and analysis of naturally fractured gas reservoirs based on stimulated reservoir volume and petro-physical parameters | |
| Oliveira et al. | Mechanical stratigraphy influences deformation band pattern in arkosic sandstones, Rio do Peixe Basin, Brazil | |
| Li et al. | Quantitative prediction of multi-period tectonic fractures based on integrated geological-geophysical and geomechanics data in deep carbonate reservoirs of Halahatang oilfield in northern Tarim Basin | |
| Manniello et al. | Fracture stratigraphy of Mesozoic platform carbonates, Agri Valley, southern Italy | |
| Hussain et al. | Non-destructive techniques for linking methodology of geochemical and mechanical properties of rock samples | |
| Wang et al. | Discussion of seismic diagenetic facies of deep reservoir in the East China Sea Basin | |
| Mahmoodabadi et al. | Formation evaluation and rock type classification of Asmari Formation based on petrophysical-petrographic data: A case study in one of super fields in Iran southwest | |
| Adelinet et al. | Effective medium modeling of diagenesis impact on the petroacoustic properties of carbonate rocks | |
| Franquet et al. | State-of-the-art openhole shale gas logging | |
| Ou et al. | Three-dimensional discrete network modeling of structural fractures based on the geometric restoration of structure surface: Methodology and its application | |
| Solano et al. | On the characterization of unconventional oil reservoirs | |
| Msaddek et al. | A fuzzy mathematical model for evaluation of rock-fracture and structural complexity: application for Southern Atlas in Tunisia | |
| Darjani et al. | Estimating the 3-D spatial distribution of mechanical properties of rock by seismic data and well logs | |
| Liu et al. | Quantitative prediction of the 3D permeability tensor for a fractured reservoir in the Dingbian oilfield, Ordos basin, Central China |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MK1 | Application lapsed section 142(2)(a) - no request for examination in relevant period |