 DETERMINATION OF PERMEABILITY IN ANISOTROPIC FORMATIONS OF SUBSURFACE
专利摘要:
A method and system may include a sensor positioned in a borehole, characteristics of the earth formation may be measured and logged by the sensor, and actual permeability may be determined on the basis of logging characteristics. Multiple component induction (MCI) data can be measured by a logging tool, the 3D components of the resistivity can be determined by inversion of the MCI data, and the 3D components of the resistivity can be logging. The triaxial components of the permeability can be determined on the basis of the effective permeability and diagrams of the 3D components of the resistivity. Sand permeability of the earth formation can be determined on the basis of the triaxial components of permeability, effective permeability, and stratified shale volume. The permeability of the sand can be logged and modifications of the operation (operations) can be initiated on the basis of sand permeability. 公开号:FR3057605A1 申请号:FR1759224 申请日:2017-10-03 公开日:2018-04-20 发明作者:Junsheng Hou 申请人:Halliburton Energy Services Inc； IPC主号:
专利说明:
TECHNICAL FIELD This disclosure relates generally to oilfield applications, and in particular downhole tools, drilling and related systems, and techniques for determining permeability of sandy layers in a stratified sand-shale formation in response to the resistivity measurements of the anisotropic subsurface formations penetrated by a wellbore (or borehole). BACKGROUND OF THE INVENTION Modern operations for the exploration and production of oil and gas rely on access to a variety of information relating to subsurface geological parameters and conditions. This information typically includes characteristics of the earth formations traversed by a borehole as well as data relating to the size and sludge of the borehole itself. The collection of information relating to the subsurface conditions, which is usually called "logging", can be carried out by several methods, in particular wired line logging and well drilling logging ("LWD"). In wireline logging, a probe is lowered into the borehole after some or all of the well has been drilled. The probe is suspended from the end of a cable line which provides mechanical support for the probe and which also provides an electrical connection between the probe and the electrical equipment located on the surface. In accordance with existing logging techniques, various parameters of the earth formations are measured and correlated to the position of the probe in the borehole while the probe is pulled at the top of the well. In the LWD, a drilling assembly includes sensing instruments that measure various parameters as the formation is penetrated, allowing measurement of the formation during the drilling operation. Among the wired line and LWD tools available include a variety of logging tools including devices configured to take measurements by multicomponent induction (MCI), nuclear magnetic resonance (NMR) and multipolar sonic logging (MSL). The permeability of the formation can be characterized using such measures. Current models can be used for the determination of permeability in isotropic formations. However, the permeability of the formation can exhibit anisotropy in the anisotropic formations and is often dependent on the direction of measurement. Therefore, it will be easily understood that improvements in the techniques for determining the permeabilities of subsurface earth formations surrounding a wellbore or a borehole are always necessary. BRIEF DESCRIPTION OF THE DRAWINGS The various embodiments of the present disclosure will be better understood on reading the detailed description given below and from the appended drawings of the various embodiments of the disclosure. In the drawings, like reference numbers may indicate like or functionally similar items. The embodiments are described in detail below with reference to the appended figures, in which: Figure 1 is a partial sectional view representative of a subsurface measurement data capture system in a logging operation during drilling (LWD), according to one or more embodiments given as examples; Figure 2 is a partial sectional view representative of a subsurface measurement data capture system in a wired line logging operation, according to one or more embodiments given as examples; Figure 3 is a partial sectional view representative of a spiral tube logging system for capturing subsurface measurement data, according to one or more embodiments given in examples; Figure 4 is a diagram of a permeability model with several components, according to one or more embodiments given in examples; Figure 5 is a diagram illustrating a bimodal permeability model consisting of isotropic sand and bi-axially isotropic shale, according to one or more embodiments given in examples; Figures 6 and 7 are diagrams of graphical solution points given as examples for the permeability of the sand k sd and the volume of laminated shale V iam in the stratified formations, according to one or more embodiments given as examples; Figures 8 and 9 are point diagrams which illustrate the components of the permeability in the direction of the x, y and z axis, k x , k y and k z , the effective permeability k e , and the anisotropic ratios k xz = k x fk z and k yz = k y jk z as a function of the volume of laminated shale according to one or more embodiments given in examples; Figure 10 is a flowchart illustrating a method for evaluating the anisotropy of the permeability of the formation, according to one or more embodiments given as examples; Figures 11 to 14 are a set of plots which provide a set of error-free synthetic data intended to predict the permeability of the sand (^), the equivalent permeability of the earth formation (k e ) and the components of the permeability in the direction of the x-axis, y-, and z (k x, k y and k), according to one or more embodiments given as examples; Figure 15 is a block diagram of a permeability determination system, according to one or more embodiments given in examples; and [0018] FIG. 16 is a diagrammatic representation of a machine in the form given as an example of a computer system in which a set of instructions asking the machine to carry out a process for determining the permeability can be executed, according to one or more embodiments given in examples. DETAILED DESCRIPTION OF THE DISCLOSURE The disclosure may repeat reference numbers and / or letters in the various examples or figures. This repetition is for the sake of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and / or the various configurations discussed. In addition, terms relating to space, such as under, below, ► lower, above, upper, top of well, bottom of well, upstream, downstream and the like can be used in this document to facilitate description to describe the relationship of an element or characteristic with one or more other elements or characteristics as illustrated, the upward direction being upwards of the corresponding figure and the downward direction being downwards of the corresponding figure, the upward direction of a well being towards the surface of the borehole, the downward direction being towards the end of the borehole. Unless otherwise indicated, the terms relating to space are intended to encompass different orientations of the apparatus in use or in operation in addition to the orientation shown in the figures. For example, if an appliance in the figures is returned, the elements described as being "below" or "under" other elements or characteristics will be oriented "above" the other elements or characteristics. Therefore, the term "below" given as an example may include both an orientation above and below. The device can be oriented differently (rotated 90 degrees or in other directions) and the space descriptors used in this document can also be interpreted accordingly. In addition, even if a figure can represent a horizontal borehole or a vertical borehole, unless otherwise indicated, those skilled in the art must understand that the device according to the present disclosure is also well suited for use in drill holes with other orientations, such as vertical drill holes, deviated drill holes, multilateral drill holes or the like. Likewise, unless otherwise indicated, even if a figure can represent an operation on land, the skilled person must understand that the method and / or the system according to the present disclosure is also well suited for use in operations at sea and vice versa. In addition, unless otherwise indicated, even if a figure may represent a cased hole, those skilled in the art should understand that the method and / or system according to the present disclosure is also well suited for use in open hole operations. As used here, the words "understand", "have", "include" and all the grammatical variations thereof are each intended to have an open, non-limiting meaning which does not exclude elements or steps additional. Although compositions and methods are described in terms of "comprising", "containing", or "including" various components or steps, the compositions and methods may also "consist essentially of" or "consist of" various components and stages . It should also be understood that, as used herein, the terms "first", "second" and "third" are arbitrarily assigned and are simply intended to distinguish two or more objects, etc., as the case may be, and does not indicate any sequence. In addition, it should be understood that the simple use of the word "first" does not require that there is a "second", and that the simple use of the word "second" does not require that there is a "first" or a "Third" etc. The terms in the claims have their ordinary meanings, unless explicitly stated otherwise clearly defined by the patent holder. Furthermore, the indefinite articles "a" or "an", as used in the claims, are defined here to mean one or more of the element which is introduced. In the event of a conflict in the use of a word or term in this memorandum and one or more patent (s) or other documents which may be incorporated into this document for reference, the definitions which are consistent with this memorandum must be adopted. The following detailed description refers to the accompanying drawings which show various details of the examples chosen to illustrate how the aspects of this disclosure can be practiced. The discussion presents various examples of the object disclosed at least partially with reference to these drawings, and describes the embodiments presented in sufficient detail to allow those skilled in the art to practice the object described herein. Many other embodiments can be used to practice the disclosed object other than the illustrative examples discussed herein, and structural and operational changes, in addition to the alternatives specifically discussed herein, can be made without departing from the scope of the object described. The subsurface formations can have the capacity to allow the formation fluids (for example, oil, water or gas) or the polyphase fluids to pass through them, which will be designated by the term permeability formations. The permeability of the formations is an important parameter in the evaluation of the formations and the characterization of the reservoirs. For example, information on permeability can be used for reservoir simulation, improved oil recovery, well completion design, and field development / development strategies. Unlike isotropic petro-physical parameters such as porosity and saturation, the permeability of formations can be anisotropic, for example, in three common types of subsurface formations (for example, layered sand-shale sequences, sands of different grain sizes, and sand with thin resistive / conductive bands). Consequently, permeability is often strongly dependent on the direction of measurement in anisotropic formations. Various interpretation models intended to derive the permeability of the formation of logging data (for example, multicomponent induction [MCI], nuclear magnetic resonance [NMR] and multipolar sonic logging [MSL]) have been developed. However, such models are typically used to determine permeability in isotropic formations. Current logging tools and their measured data can be used to determine scalar or isotropic permeability. These conventional "logging" permeabilities (ie permeabilities derived from "logging" data for the borehole, from samples with similar properties of the earth formation surrounding the borehole, etc.) do not provide not an anisotropy of the permeability and its components (such as horizontal and vertical permeabilities). A precise determination of the permeability taking into account the anisotropy can improve the evaluation of the formations and the characterization of the reservoirs. The permeability can be determined using an anisotropy model of the permeability which is based at least in part on the relationship between the permeability and the resistivity of the formations in the transversely isotropic (TI) and bi-axially anisotropic formations ( BA). In MCI logging, the resistivity of the formations (or conductivity, which is inversely proportional to the resistivity) presents an azimuthal anisotropy of the horizontal resistivity in the stratification plane of the formations. Unless the text or context clearly indicates otherwise, "horizontal" or "transverse" refers to a direction or a plane substantially coinciding with a stratification plan of the relevant formation, and "vertical" indicates a direction of a plan substantially orthogonal to the stratification plan of the relevant formation. The processing of the MCI logging data can be carried out on the basis at least in part of the BA parameterization, giving a more precise description of the complex anisotropic formations than that based on the transversely isotropic models (TI). The IT training model is a model which represents the simulated resistivity characteristics of the formations taking into account the transverse isotropy of the formations in terms of resistivity. The TI model can take into account differences in resistivity between the orthogonal axes located in a formation or stratification plane (for example, the horizontal or transverse plane) and an axis perpendicular to the formation or the stratification plane (for example, l 'vertical axis). Consequently, the TI model takes into account the anisotropy between the vertical axis and the horizontal plane, but supposes an isotropy between the different axes of the horizontal plane. The BA model also takes into account the anisotropy between the orthogonal axes in the transverse plane. One or more embodiments given as examples described below provide a method and a system for processing the logging data in determining the anisotropy of the permeability. The description of the embodiments given in the examples which follow describes the use of the anisotropy model of the permeability to derive a relationship between the anisotropy of the permeability of the formations and the anisotropy of the resistivity in the BA formations. As is known, MCI tools are capable of measuring data which can be used to determine the anisotropy of 3D resistivity in formations. An inversion of the MCI data can give anisotropy of the 3D resistivity. In addition, an effective permeability or a component of the permeability can be used to calibrate conventional permeabilities (for example, which take into account scalar or isotropic permeability) derived from data diagrams to calculate the other components of the permeability. The limited vertical resolution of the logging tools is sometimes unable to capture the permeability of the reservoir (or sand) in the stratified formations. Therefore, in some embodiments, the permeability of the sand is determined from the computation of the components of the permeability in the direction of the x, y, and z axis based on a multi permeability model. -modal, as discussed in more detail below. The implementations of the embodiments given in the disclosed examples can provide the anisotropy of the permeability using an integrated interpretation of the anisotropy of the resistivity by MCI with conventional permeability diagrams from other sensors. (for example, resistivity, NMR or sonic logging). Therefore, the tri-axial components of the permeability (for BA formations) of the permeability anisotropy tensor can be determined and applied to interpretations of the field logging data. Figure 1 is a representative illustration of a logging environment during drilling (LWD) given as an example. A drilling rig 102 may be equipped with a derrick 104 which supports a hoist 106 for raising and lowering a drill string 108. The hoist 106 suspends an upper drive mechanism 110 suitable for rotate the drill string 108 and lower the drill string 108 through the wellhead 112. A drill bit 114 can be connected to the lower end of the drill string 108. When the drill bit 114 rotates, it creates a borehole (or borehole) 116 which passes through various formations 118. A pump 120 can be used to circulate a drilling fluid through a supply line 122 towards the upper drive mechanism 110, down through the interior of the drill string 108, through holes in the drill bit 114, to the surface through an annular space around the drill string 108, and in a retention pit 124. The drilling fluid transports the cuttings from the borehole 116 towards the pit 124 and participates in maintaining the integrity of the borehole 116. Various materials can be used for the drilling fluid, comprising conductive sludge based on salt water. A set of LWD tools 126, which may include one or more sensors 127, can be integrated into a downhole assembly (BHA) near the drill bit 114. As the drill bit 114 extends the hole drilling 116 through the formations 118, the LWD tools 126 can collect measurements relating to the various properties of the formation as well as the orientation of the tools and various other drilling conditions. LWD 126 tools can take the form of a drill collar, a thick-walled tubular member that provides weight and rigidity to facilitate the drilling process. In various examples, Your LWD 126 tools can include a tri-axial multi-array induction tool to measure the resistivity of formations and produce MCI measurement data, as described here in more detail. Additionally, the LWD tools 126 can include one or more sensors 127, such as an NMR tool and / or a sonic logging tool, for measuring and providing logging data. A telemetry fitting 128 may be included to transfer images and measurement data to a surface receiver and to receive commands from the surface. In some embodiments, the telemetry fitting 128 does not communicate with the surface, but instead stores the log data for later surface retrieval when the log set is retrieved. At various times during the drilling process (or after), the drill string 108 can be withdrawn from the borehole 116, as shown in Figure 2. After the withdrawal of the drill string 108, logging operations can be carried out by means of a wired line logging probe 234, which can be a probe suspended by a cable 242 having conductors for supplying power to the probe 234, and for transmitting telemetry data from probe 234 towards the surface. The exemplary wired line logging probe 234 may have buffers and / or centering springs to hold the probe 234 close to the central axis of the borehole 116 while the probe 234 is pulled at the top of the well . Like LWD tools, the 234 logging probe can include a variety of sensors including a tri-axial multi-array induction tool to measure the resistivity of formations and provide MCI measurement data. The logging probe 234 may also include one or more sensors 127, such as an NMR tool and / or a sonic logging tool, for measuring and providing measurement data. A logging installation 244 collects the measurements from the logging probe 234, and includes a processing circuit 245 for processing and storing the measurements collected by the sensors 127 and other logging devices in the logging probe 234. In another alternative, a logging technique is schematically illustrated in FIG. 3, which shows an exemplary embodiment of a logging system using a spiral tube 300. In the system 300, a spiral tube 354 is drawn of a body 352 by a tube injector 356 and injected through a seal 358 and a plug block 360 in the borehole 116. In the borehole 116, a supervisory fitting 364 and one or more tools Logging 365, with one or more sensors 127, are coupled to the spiral tube 354 and configured to communicate with a surface computer system 366 via information channels or other telemetry channels. An interface at the top of the well 367 can be provided for exchanging communications with the supervisory connector 364 and receiving data to be routed to the surface computer system 366. A processing circuit, in the form of a surface computer system 366, is configured to communicate with the supervision fitting 364 to adjust the logging parameters and collect the logging information from one or more tools. Logging 365. The surface computer system 366 is configured by software (illustrated in FIG. 3 as being stored in the embodiments given in examples of the removable storage media 372) for monitoring and controlling the downhole instruments 364 , 365. The surface computer system 366 can be a computer system such as that described here in more detail. Direct modeling comprises a numerical solution of the Maxwell equation in a problem of mathematical limit values, where the relevant formation or the model specifies the limits and the forms of the regions of different resistivity. The method for deriving the parameters of the formations from a set of given terrain diagrams is known as reverse modeling, and typically comprises the iterative adjustment of the training parameters chosen in one or more layers of a training model, and repetition of direct modeling (for example, by calculation or with reference to pre-calculated data from a bank), until the observed terrain diagrams are reproduced satisfactorily, for example until 'a set of variable borehole-formation parameters is found for a better fit with the observed logging data based on the applicable formation model. Some of the treatment schemes given in the examples disclosed here are based at least in part on a bi-axial anisotropy model (BA) and / or a transversely isotropic model (TI). The TI model can take into account the resistivity differences between the orthogonal axes located in a formation or a stratification plane (sometimes called horizontal or transverse plane) and an axis perpendicular to the formation or the stratification plane (sometimes called vertical axis). The TI model can thus take into account the anisotropy between the “vertical” axis and the “horizontal” plane, but supposes an isotropy between the different axes of the “horizontal” or transverse plane. For this reason, the TI model is also referred to as anisotropic TI. The BA model also takes into account the anisotropy between the orthogonal axes in the transverse plane, and is therefore also considered to take into account the tri-axial anisotropy. Note that, unless otherwise indicated, "biaxial anisotropy" and its derivatives refer to transverse bi-axial anisotropy. Consistently with this terminology, a TI model does not take into account the bi-axial anisotropy, even if it takes into account the anisotropy between two axes (for example, between the horizontal plane and the vertical axis). We describe the resistivity / conductivity of the BA formation in the main coordinate system of the formation. This system is chosen so that the direction of the x or y axis coincides with a main axis of the conductivity tensor having the highest conductivity component (or lowest resistivity) in the stratification plane; the z-axis is parallel to the main conductivity axis having the lowest conductivity component in the stratification plane. In this coordinate system along the main axes, the conductivity of the formation can be expressed by a diagonal tensor: t = diag (C x, C y, C:), where σ the conductivity tensor from the formation, its entirety C x and C y are the two conductivities in the two main axes (e.g., x- and y) of the stratification plane, and C- is the conductivity in the direction of the main axis (for example, z-axis) perpendicular to the stratification plane. If equation (1) is expressed in terms of resistivity, the resistivity of the formation can be expressed by the following diagonal tensor: R, = diag (R x , R y , R :) , (2) From where 'is the resistivity tensor of the formation, and its elements R x , R y , and R : are the tri-axial components of the resistivity in the three directions of main axis (x, y, and z), respectively. It is noted that in a TI formation, the resistivity can be represented as being a diagonal tensor which is only described using two components of resistivity: Rh (in which R b = R x - R y ) and R v ( in which R v = R :) in the main axis system (for example, coordinate system xyz), however, the resistivity tensor of the BA model is better described using the tri-axial components of the resistivity: R x , R y and R :. On the basis of equations (1) and (2), we can derive the relationships between the resistivity and conductivity components R x = 1 / C X , R y = Î / C y and R : = 1 / VS-. If R x = R y ~ A: then the resistivity of the formation is isotropic. If only R x = R y R f:, then the resistivity of the formation is transversely isotropic (TI); therefore, only one component of the resistivity is required in the stratification plan. In this case, R x and R y are usually both called horizontal resistivity and are often indicated by Rh (= R x = R y ); and R- is called vertical resistivity and is usually indicated by R v . If R x fR y f R-, the resistivity of the formation is of the bi-axial anisotropy (BA) type. It can be seen that isotropy and transverse isotropy are special cases of bi-axial anisotropy (BA). For practical applications, different report notations are used. For example, the ratios Rxy - Rx / Ry, Rzx - Rz / Rx and R Z y - R z / Ry. As discussed here, when the permeability is anisotropic, a permeability tensor (as opposed to a scalar) is used to express the permeability of the formation. The pressure in the formations can be applied in three directions, and for each direction, the permeability can be measured (via Darcy's law) in three directions, which leads to a tensor of 3 by 3. A differential form of the law of Darcy can be expressed by a matrix equation in a three-dimensional (3D) space as given by: q = KG where q is the so-called Darcy velocity vector, G is a modified pressure gradient vector, and K is the permeability of training, and K is a second-order tensor. This equation shows that pressure can be applied in three orthogonal directions, and that for each direction, permeability can be measured in three directions. In a three-dimensional (3D) coordinate system, the second rank tensor can be made using a 3 by 3 matrix being both symmetrical and positive defined, and it can be represented using the following equation: u xx 'xy' xz K - k X y kyy ky Z J _ (kij) 3 * 3 (3) L xz L ZZ, In equation (3), K is the permeability tensor of the real formation, i indicates the direction pressure, and j is the direction of the permeability measurement. Consequently, the component kjj represents the j-th directional component of the permeability in the i-th direction of the pressure. This permeability tensor K is diagonalizable (since it is both symmetrical and defined positive). The eigenvectors will give the main directions of the flow, representing the directions where the flow is parallel to the pressure drop, and the three eigenvectors represent the three main components of the permeability. In the 3D main coordinate system, the permeability tensor K is expressed by a diagonal tensor after the diagonalization of the matrix, which is equivalent to finding the eigenvectors of the matrix, and which can be represented using the following equation: K = diag (k x> k y , k z ) (4) In equation (4), k x and k y are the two components of the permeability in the directions of the two main axes (X and Y ) of the stratification plane, and k z is the component of the permeability in the direction of the main axis Z perpendicular to the stratification plane. Like the descriptions of the resistivity of the formation, the permeability of the formation is isotropic if k x = k y = k z . If k x = k y Φ k z , then the permeability is transversely isotropic (TI). In IT training, only two components are necessary to describe the anisotropy of the training permeability. In the stratification plan, the permeability component can be indicated by k x = k y = k h and is designated as the horizontal permeability. For the directional component Z, k z , can be indicated by k z = k v and is designated as the vertical permeability. Therefore, the permeability tensor can also be represented using the equation: K = diag (k h , k h , k v ). When k x Φ k y Φ k z , the permeability is of the bi-axial anisotropy (BA) type. In electrically anisotropic formations, the anisotropy of the resistivity can be obtained from induction diagrams, such as MCI diagrams. If the formations are anisotropic in terms of both permeability and resistivity, the anisotropy of the permeability can be assessed from the anisotropy of the resistivity. We can assume that the pore space is represented as a bundle of independent and tortuous tubes of different radii in isotropic formations. If the flow is low enough to be laminar and not turbulent, then the permeability scalar can be determined using the following Kozeny-Carman equation: k = A --- A 4F iR w 4R + d '< (5) where k represents the permeability in an isotropic formation, A represents a form factor for porous tubes having a diameter of d, and F represents the formation factor. The training factor can be represented using the following equation: F = = -Î £ - (6) " lR w where R o represents the resistivity of the formation containing 100% water, R w represents the resistivity of the water of the formation, R t represents the real resistivity of the formation, and I represents the index of resistivity. The resistivity index can be represented using the following equation: In BA formations, the permeability, the formation factor and the resistivity (or conductivity) index are not scalars. Instead, the permeability, the formation factor and the resistivity (or conductivity) index can be represented using tensors, namely: K, F and I, respectively. As K as given above in equation (4), F and I can be represented using the following two diagonal tensor equations in the same main 3D system: (8) (9) F = diag (F x , F y , F z ) I = diag (l x , I y , I z ) A generalization of all the values for the anisotropic formations gives the expressions of tensor. For example, the following equations represent the components of permeability in BA formations: ik x A x k ,, = k 7 = d 2 - - = Ax-d 2 1 x 4FX XX 4Rx A z -d 2 4F 7 _ Iy-R v y 4R V d 2 ·! ^ Z 4R 7 (10) (11) (12) where F X 'Fy, and F z represent three components of training factor measured along the directions of the axes x, y and z, respectively, which can be and F z = —The three components of the tensor Iz'R '· represented by F x = ——, F y = —ly'Rw ly'Rw RR R of resistivity index, I, can be represented by l x = -7, I y = -y, and l z = -7, R o R o R o where R x , R y , and R z represent the resistivity components of the formation along the x, y and z axis, respectively. In the BA permeability formations, the relationship between permeability and resistivity factor of the formation obtained along the three directions of the perpendicular main axis (for example, x, y and z axis) can be represented by fc using the following equations. Anisotropy - can be determined by equation (13) and R zk anisotropy can be determined by equation (14): kx A x -d x . ZF z kz A z -d. z F X J & (13) l .y k-Z Ay'dy (H) As a variant, the relationship between anisotropy of permeability and anisotropy of resistivity (or conductivity) can be represented using the following equations: R x _ Α χ · άχ I x . Ζ / ζ λ _ Αχ · άχ Ι χ . / _ / -xz. ζ, <->. k z ~ A z d z l z R X ) ~ A z d z Ι ζ C Z J ~ RP R X J ' Γ = τ ^ τ (γ) = τ ^ τ (γ) = UJ · (γ) < 16 > ^ ζ * ζ n y / * ^ ζ u z * ζ / vy j where C E p = y, Cpp = d % -7-, with C x , C y , and C z being both Az '&z' z Az'dz 'z y horizontal conductivities (i.e. x and y axis), and vertical conductivity (i.e. z axis), respectively. Two anisotropy ratios of resistivity (or conductivity) can be defined as: R zx = -f- - -f- = C xz , R zy = -f- = -fi- = C yz and two R x fi anisotropy ratios of permeability can be defined as: k xz = -f- and k yz = This anisotropy relationship of permeability-resistivity shows that the anisotropy of permeability can be evaluated on the basis of the anisotropy of the resistivity (as derived from the MCI diagrams) and the shape and / or diameter of the pores. A simplified relationship between the anisotropy of the permeability and the resistivity of equations (15), (16) can be determined if we assume that A x l x = A y I y = A z l z and can be represented using the following equations: (17) = 3 '(ιζ)' ° u ° u 'zx = / y - / y. ( or b - Γ γζ -P or R - kz ~ d 2 z R y ) ' K y z ~ Lrp Kz y' Kz y ~ _L_ b r xz ^ xz l rp -L- b r yz Kyz '' RP (18) Rj / χ, OR Ryx k xy (19) Furthermore, if we assume that Cpp = C% p = = ^ 7 = 1, then equations (17), (18) and (19) can also be reduced and represented using the following equation: (20) Where k h = k x = k y , k v = k z , R h = R x = R y , and R v = R z . According to equation (20), the anisotropy of the permeability can be estimated if the anisotropy of the resistivity is known, as according to the inversion processing of the MCI diagrams. An effective permeability (or geometric mean) in the BA formations can be represented using the following equation: k e / he yjk-χ ky 'k z (21) Where k he is an effective horizontal permeability which combines the permeabilities k x and k y . The effective permeability, k e , must be between k he and k z . . It is noted that k he - k z = k e for isotropic media, and that k he = ^ Jk x k y . For measurements made on cores, it is possible to measure a component of the permeability or a multi-component permeability, such as k x , k y , k z or all different components. In one case, if it is assumed that the permeabilities derived from logging data (for example, using resistivity diagrams, sonic logging and / or NMR) are calibrated by k e , then they are approximately equal to this effective permeability, k e . In another case, assuming that the permeabilities derived from the logging data are calibrated by k h or k v , they are approximately equal to the horizontal or vertical permeability, k h or k v . In general, k e and k he can be considered as two functions of a permeability derived from variable logging data (for example from sensors 127). They can be represented using the following equations: > <,, = (22) kte = f & îiAg) (23) Here, fiog (kiog) and fiog (kio g ) are two known functions, k Log and ki og are two types of permeabilities derived from conventional logging data. In equation 22, if it is assumed that the permeabilities derived from the log data k iog are calibrated by k e (for example, using resistivity diagrams, sonic logging and / or NMR, etc. .), then they can be * approximately expressed by k e = Ci og xk log , where C / og is a known calibration coefficient. In equation 23, assuming that the permeabilities derived from the logging data are calibrated by k he , they can be approximately expressed by / c he = Cifg xk R og, where Cif g is also a calibration coefficient known. If we assume that Crp = 1, CpJ = 1, and C pp = 1 for BA formations, then a relationship between the anisotropy of permeability and resistivity can be expressed by the following equations: L ·f ^ XZ = * x = k z - - R R x zx (24) kyz kykz R Z _ n Ry ~ Kzy (25) ky X ky k x R x _ n ÏT y - Hxy (26) L ·r ^ xy _ kx _ky £ = Ryx = 1 / Rxy (27) Rzy - Rzx R X y (28) If we assume that the BA of the resistivity can be obtained from the MCI diagrams, then the permeabilities can be determined from the above equations if the conventional permeabilities derived from the logging data are equal to the permeability effective, k e . When the tri-axial components of the resistivity (R x , R y , and R z ) and the effective perm k e (or a component of the permeability such as fc x ), are determined, then the tri-axial components of the permeability (k x , k y , and k z ) plus the biaxial anisotropy ratios of the permeability (e.g., -, γ-, and γ-) can be determined. Therefore, the following equations can be used to determine k x , k y and k z : It is known that the laminated structures of the stratified tanks are often much finer than the vertical resolution of a logging tool. Therefore, the permeabilities derived from the logging data can be represented as weighted averages of the actual reservoir permeability and shale permeability. Figure 4 is a diagram of a multicomponent permeability model consisting of a number M of types of isotropic sands and a type of shale BA. In the model, is the real or sand permeability of the i-th type and kf h , k ^ h , and kf h represent the permeabilities in the direction of the x, y and z axis of the shale formation pure, respectively, and BA can be caused by fractures 400. According to the multicomponent permeability model, the following equations can be used for the determination of the actual permeability of the reservoir in a stratified formation, such as sandstone formations : For the permeabilities in the direction along the x-axis and the y-axis which are in a direction parallel (for example, horizontal) to the stratification plane, the permeabilities along the x-axis and the axis y's can be represented using the following equations: k, = ZS.OçS '· k%) + k x sh Σ, v ^, = Σ ife® · fc «) + k x sh V lam (32) k, - · / î) + k ( h Σ, v, = Σ & Χΰ '* £) + k v sh v lan (33) For the permeability in the direction of the z-axis which is perpendicular (for example, vertical) to the stratification plane, the permeability according to l z axis can be represented using the following equation: In equations (32), (33) and (34), it is assumed that all the sands are isotropic and that the shale is BA anisotropic. M represents the total number of types of sand. kf h , k y sh and kf h are the permeabilities in the direction of the x, y and z axis (or in other words, two horizontal permeabilities and a vertical permeability) of the pure shale formation, respectively, V tam = Σ ^ ι is f ract i ° n by volume of the total stratified shale, is the volume percentage for the i-th type of sand, k ^ is the permeability of sand of the i-th type and Σ ^ ι ^ 0 ) + V lam = 1. If we assume that Μ = 1 or k ^ = k ^ d = ··· = k ^ p = k sd , the above equations can be reduced to a bimodal permeability model for the determination of the permeability of the reservoir. Figure 5 is a diagram illustrating a bimodal permeability model consisting of isotropic sand and BA shale. Here, k sd is the actual permeability of the sand (or reservoir), and k * h , k v sh, and k z h are the permeabilities in the direction of the x, y and z axis of the formation pure shale. As illustrated, a multi-layer model can be reduced to an equivalent two-layer bimodal model. The permeability component in the direction x can be represented using the following reduced equation: kx = (1 “Vlam) ' k sd + V l lam κχ K sh (35) The permeability component in the direction y can be represented using the following reduced equation: ky ~ Vlam) '^ sd i ”^ lam' ^ sh. (36) The permeability component in the direction z can be represented using the following reduced equation: t (1 Vlam) i Vlam j, _1_ k z ~ k sd k z sh , Z ~ Υ-νlam), Vlam k sd k sh (37) In equations (35), (36) and (37 ), if k x , k y , k z k * h , k ^ h , and ks h are known, for example from calculations and / or logging data, then the permeability of the sand k sd and V lam can be resolved. For example, the graphical solution of the permeability of the sand k sd and the volume of laminated shale V lam in equations (35), (36) and (37) for the laminated shale at kf h (or kshHx) = 10 md and ( or kshZ) = 1 md is indicated in Figure 6. In Figure 6, the dotted line contours correspond to the values of the constant V Lam , and the continuous line contours represent the values of the constant k sd . Similarly, Figure 7 illustrates a graphical solution of the permeability of sand k sd and the volume of laminated shale V tam for laminated shale at k $ h (or kshHy) = 10 md and k z h (or kshZ) = 1 md. In Figure 7, the dotted line contours correspond to the values of the constant Vi am , and the continuous line contours represent the values of the constant k sd . However, if we assume that the sand and the shale are both isotropic (for example, k * h = kf. H = k z h = k sh ), equations (35), (36) and (37) can be expressed using the following equations: (t Vlam) | Vlam k-sd ksh am '^ sh (38) / am 'k s h (39) k - 1 Kz ~ (i-Vlam) . Vlam (40) ksd k shguess the sand and the shale are However, even if Γ are both isotropic, the macro anisotropy of the permeability of the formation can be observed. For example, Figures 8 and 9 show a pair of plots showing the permeability in the direction of the x, y and z axis, k x , k y , and k z , the effective permeability k e , and the anisotropic ratios k xz = k x / k z and k yz = k y / k z as a function of the volume of laminated shale V lam . If V lam * θ 'ksd and k sh represent the permeability of sandstone and shale, respectively. If we assume that the tri-axial components of the permeability, k x , k y , k z , and the volume of laminated shale V lam are known, then k sd and k sh can be solved using equations ( 38), (39) and (40). After the effects of lamination on the measured / calculated permeabilities, k x , k y , and k z , are corrected, a more precise permeability k sd for sand can be obtained. In Figure 8, the permeability of sandstone k sd = 100 md, and the permeability of shale k /% (or kshXZ) = k ^ (or kshYZ) = 1 md, which indicates that the shale is isotropic. In Figure 9, the permeability of sandstone k sd = 100 md, and the permeability of shale k ^ (or kshXZ) = 10 md and k ^ (or kshYZ) = 1 md, which indicates that the shale is isotropic. Figures 8 and 9 show that k xz and k yz approach a maximum value around 50% of shale, that all the curves are sensitive to the volume of stratified shale, and that k y , k z , k yz are identical. Using equations (38) and (40), the anisotropy ratio of the permeability k xz = can be represented using the following equation: k „= g = [0 - V lam ) k si + v, am · fej,]. i sh = (1 - Vlam) [(1 - Vlam) + V lam g] + V lam [(1 - V lam ) g + = 1 - 2V iam + V, am (l - V lam ) [iâ + £ g] + V tam V lam [1 + * £] = 1 + T „ m [(l - ω [g + jg] + V ,, m [1 + fc £] - 2] (41) OR k xz 1 ~ Vlam) 5 ++ v '“” [1 + ~ 21 (42) [0071] Using equations (39) and (40), the anisotropy ratio of the / c permeability k yz = - can be represented using l following equation: k yz = £ = [d - k, d + v, am · tj,]. Kz = (1 - V lam ) (iv, am ) + v lam ! Ÿ · K shi k sd Έ V [ am Vlam) Vlam k z K sh r Iam [(l - ω [& + g] + V lam [1 + * £] - 2] (43) or kyz 1 ~ Vlaml (l Vlam) + V iam [1 + kg b ] ~ 2} (44) In addition, the following equations can be used to calculate R x , R y , and R z : t _ (1 Vlam) _ | _ Vlam Ry Rvd Re 'sh _ (1 Vlam) _j_ Viam Rx Rsd. sh R Z ~ (1 Vlam) Rsd 4 Vlam 'R. z sh (45) (46) (47) The following equations can be used to calculate the anisotropy ratio of the resistivity R zx : p - 22. - n ZX p ~ K x (1-Viam) Rsd + M [d _ l /, om ). Rsd + v lam RJ,] K sh J ZX lamPsh. VlnmR = (1 - K to „) [(1 - V lam ) + v, am gj] + v lam (ΐ-ω ^ + x sh = i-2v lam -l · r, am r, am (i + "S + r, am (i - v lam ) [j & + g] (48) OR "z, - 1 = V tam [il - K lam ) [g + g] + V, am (l + s" - 2} (49), R Z , [0074] According to the above, it can be observed that: if -5- = -, "sft R sd 10 ir = ÿ- ' and k ïh = R sh' then k xz = R zx (or C ^ p = 1). Otherwise, = k xz / R zx , ou = K sd K sà fe d fe (k xz - T) / (R ZX - 1), and C R p is a non-linear function of V iam , -γ, -γ-, k / ff , and k $ h ksd rZ R to -, -γ, Rgf (, and can be represented using the following equation: R sd R sh pxz _ C RP - {(l-Uam) k sh 1 k sd k sd k sh + V lam [ 1 + fc sh] ~ 2 d {(1-Uam) R sh, R sd [ R sd RX sh + ^ (1 + ^) - 2} (50) kk y [0075] Similarly, C ™ is a nonlinear function of Vi am, τγ, ^ k ksd sh sh 'R sh> and C an be represented using the following equation: r yz - u rp ~ {(1-P / am) k sh 1 k sd k sd k z sh + V lam [ 1 + / c sh] ~ 2 d {(1-Ptam) R sh, R sd R sd + Ry sh _ + Uam (l + ^) - 2 } (51) Once all the V lam , k %%, and Rg% are k sh k sd R sd R sh k fi known, equation (50) can be used to estimate C R p. Once all of the U am , -γ, k sh ΐ yz -, k ^, and -, ^ γ, Rs% are known, equation (51) can be used to estimate C pp . By k sd R sd sh elsewhere, the relations given by the following equations must also be understood, where: k xz Rzx · kyz Rzy and k X y Ryx · [0077] Figure 10 is a flowchart illustrating a method 1000 comprising a processing multi-level data based on direct models with BA anisotropies. The method 1000 allows the evaluation of the anisotropy of the permeability of a formation using an integration of the MCI logging data with diagrams coming from other conventional / advanced sensors (for example, conventional ones such as triple combo diagrams, or advanced such as sonic logging, NMR, RDT, or other conventional / advanced sensors 127). In operation 1002, the MCI measurement data captured by a tri-axial MCI tool in a borehole extending through a subsurface geological formation can be entered after calibration, temperature correction and other preliminary processing. . This prior treatment may not include correction of the wall effect. MCI data can be multi-frequency data, and can be taken at multiple spacings. In certain embodiments, the measurement data MCI can be measurements at a single frequency of the respective networks of the tool. In addition, other logging data captured, for example, by sonic or NMR 127 sensors can also be entered. In operation 1004, an inversion processing is applied to the MCI measurement data to produce inverted parameters to be used for the evaluation of the permeability. For example, a BA-based inversion can be applied to produce the inverted BA parameters of R x , R y and R :. BA-based reversal processing can be based on various training models, including, but not limited to: radially one-dimensional (R1D) and dimensionless (0D) models. The inverted parameters can be used for the determination, for example, of the anisotropy ratios of the resistivity (R x -_, R yz , R xy ). The anisotropy ratios of the permeability (k xz , k y :, kxy) can be determined from the anisotropy of the resistivity using, for example, equations (13) to (19) as discussed above. In operation 1006, the effective permeability k e (or a component of the permeability) can be determined using the conventional permeabilities derived from the logging data (for example, using NMR, RDT, sonic and / or resistivity logging). In operation 1008, the permeability components can be determined using the resistivity anisotropy data obtained from the MCI measurement data and the effective permeability k e from conventional permeability diagrams. In one embodiment, the tri-axial components of the resistivity (R x , R y and / -) and the effective permeability (or a component of the permeability), can be used to determine the tri-axial components of the permeability (k x , k y , and k z ) and the anisotropy of the permeability (for example, and -) using the equations Ky k-2 (29) to (31) as discussed above. The permeability components can be used to solve equations (32) to (34) as discussed above to recover the permeability constants k * h , k y sh, and kf h of a pure shale formation. Equations (32) to (34) can also be used to determine the volume of laminated shale V lam . With a known volume of laminated shale V tam , equations (35), (36) and (37) as discussed above can be solved to obtain the permeability of the sand k s d in the stratified formations. Once the above data are determined, equations (50) and (51) as discussed above can be used to estimate the coefficients Cflp and C yz p. In some embodiments, the calculated k x , k y , and k z , and k sd (as well as k sh ) can be evaluated in terms of data quality at operation 1010 before output for use in evaluation training at 1012. The benefits of the methods and systems described for the evaluation of the permeability anisotropy using both the MCI data and the conventional permeability diagrams include a more precise evaluation of the reservoir, detection of fractures, and development / oil production. Figures 11 to 14 are plots which provide a set of synthetic data intended to predict the anisotropy ratios of the permeability and the components of the permeability (k x , ky and k-) from an interpretation integrated of Vi am , Rx, Ry, Rz, and the effective permeability (k e ). Figure 11 illustrates the simulated resistivities in the direction of the x, y and z axis (Rx, Ry, Rz) having units of ohm-m over a range of depths. The resistivities Rx, Ry and Rz, can be calculated using equations (45), (46) and (47), as discussed above, for a given R sd and R * h = 1 (or R ^ f = 4), R y h = 2 (or R z % = 2), Rl h = 4 ohm-m plus the V [am known as given in Figure 12. Fe log V) am of the volume of laminated shale can be simulated using the equation below: V lam (z, AA, BB) = AA - BB "i '9ifr b t , cf) (52) where z represents the depth of the log (in units of feet), AA = 0.95, BB = 0, 85, and N sh = 7, and gAz, b ^, cf) represents multiple modified Gaussian functions, which can be expressed using the equation below: _ArizÈi) 2 gAz.bi.cf) = e c i 1, i = 1,2, N sh (53) where ai = l, bi = -70, -50, -25, 0, 25, 50, 70, and q = 5, 5, 10, 5, 10, 5, 5. Figure 13 illustrates the simulated permeabilities in the direction of the x, y and z axis (k x , k y , and kf), the effective permeability (k e ), where the permeabilities (k x , k y , k-, and k e ) can be determined by equations (38), (39), (40) and (30) with a given k sd , and k * h = 16, k y sh = 8 , k z sh = 4, and further with the known V iam of Figure 12. Figure 14 illustrates the predicted permeabilities (k x , ky and kf), and the permeability of the sand (ksd), using the flowchart described in Figure 10. Due to the macro-anisotropy of the permeability caused by the laminated structures and the limitation of the vertical resolution of the tools, the effective permeability k e obtained by conventional diagrams is not the same as the permeabilities k x , k y and k-. In addition, it can be seen that all the permeabilities k e , k x , k y and k : are significantly different from the diagram k sd for the same reason of laminated structure. However, by comparing Figures 13 and 14, it can be seen that the k x , k y , k_ and k sd predicted in Figure 14 are substantially the same as their actual values in Figure 13. Figure 15 is a block diagram of a system 1500 given as an example for estimating the properties of formation and invasion in the subsurface, according to an embodiment given as an example. The system 1500 exemplified in Figure 15 can be configured to perform one or more of the methods described above with reference to Figure 10. The system 1500 is described in terms of a number of modules for performing the respective operations described previously. As used herein, a "module" can be a motor, a logic element or a mechanism capable of performing the operations described and / or configured or arranged in a certain way. The modules can constitute either software modules, with a code incorporated on a medium readable by a non-transient machine (namely, such as any conventional storage device, such as a volatile or non-volatile memory, disk drives or solid state storage devices (SSDs, etc.), or modules implemented in hardware. In some exemplary embodiments, one or more computer systems (for example, a stand-alone, client or server-based computer system) or one or more components of a computer system (for example, a processor or a group of processors ) can be configured by software (for example, an application or part of an application) or firmware (note that software and firmware can generally be used interchangeably here as is known to an expert in the field ) as a module which has the function of carrying out the operations described. In various embodiments, a module implemented in the hardware can be implemented mechanically or electronically. A module implemented in hardware is a tangible unit capable of carrying out certain operations and can be configured or arranged in a certain way. In the exemplary embodiments, one or more computer systems (for example, a stand-alone, client or server-based computer system) or one or more processors can be configured by software (for example, an application or a part of it). 'an application) as a module implemented in the hardware which has the function of carrying out certain operations as described here. For example, a module implemented in hardware can include a dedicated circuit or logic which is permanently configured (for example, in a specialized processor, an application-specific integrated circuit (ASIC) or a network of doors) to carry out the identified operations. A module implemented in hardware can also include a programmable logic or circuit (for example, as incorporated in a universal processor or other programmable processor) which is temporarily configured by software or firmware to perform some or all of such operations. The term "module implemented in hardware" must be understood as encompassing a tangible entity, an entity which is physically constructed, permanently configured (for example, wired), or temporarily or transiently configured ( for example, programmed) to operate in a certain way and / or to perform certain operations described here. Considering the embodiments in which the modules implemented in the hardware are configured temporarily (for example, programmed), all the modules implemented in the hardware do not need to be configured or instantiated at a any moment. For example, when the modules implemented in the hardware include a universal processor configured using software, the universal processor can be configured as different modules implemented in the respective hardware at different times. The software can configure a processor accordingly, for example, to constitute a module implemented in the particular hardware at a time and to constitute a module implemented in the different hardware at a different time. The modules implemented in the hardware can provide information to other modules implemented in the hardware, and receive information from other modules implemented in the hardware. Consequently, the modules implemented in the hardware described can be considered as being coupled in communication. When several such modules implemented in the hardware exist simultaneously, communications can be obtained by signal transmission (for example, on appropriate circuits and buses) which connect the modules implemented in the hardware. In embodiments in which multiple modules implemented in hardware are configured or instantiated at different times, communications between such modules implemented in hardware can be obtained, for example, by storing and retrieving information in memory structures to which the multiple modules implemented in the hardware have access. For example, a module implemented in hardware can perform an operation and store the output of this operation in a memory device to which it is coupled in communication. Another module implemented in the hardware can then, later, access the memory device to recover and process the stored output. The modules implemented in the hardware can also initiate communications with the input or output devices, and can operate on a resource (for example, gathering information). Consequently, the term “module” must be understood as encompassing a tangible entity, an entity which is physically constructed, permanently configured (for example, wired), or non-transient or temporarily configured (for example , programmed) to operate in a certain way or to perform certain operations described here. In some embodiments, modules or components can be configured temporarily (for example, scheduled), and not all modules or components need to be configured or instantiated at any time. For example, when the modules or components include a universal processor configured using software, the universal processor can be configured as different modules implemented in the respective hardware at different times. The software can configure the processor accordingly to constitute a particular module at a time and to constitute a different module at a different time. The modules can provide information to other modules and receive information from other modules. Consequently, the modules described can be considered as being coupled in communication. When several such modules exist simultaneously, communications can be obtained by signal transmission (for example, on appropriate circuits and buses) which connect the modules. In embodiments in which multiple modules are configured or instantiated at different times, communications between such modules can be achieved, for example, by storing and retrieving information in memory structures to which the multiple modules have access. For example, a module can perform an operation and store the output of this operation in a memory device to which it is coupled in communication. Another module can then, later, access the memory device to retrieve and process the stored output. The modules can also initiate communications with the input or output devices, and can operate on a resource (for example, gathering information). For the purposes of this description, the modules of Figure 15 will be described in terms of the algorithms executed in each module, as they can be executed by one or more processors, universal computer or other mechanism based on the instructions stored in the hardware as described above. In this exemplary embodiment, the system 1500 includes a data access module 1504 configured to access MCI data and other logging data from an initialization module 1502. A module for inversion 1506 is configured to perform an inversion in accordance with one or more of the exemplary embodiments discussed with reference to Figure 10, while a permeability determination module 1508 is configured to determine the components of the anisotropy of the 3D permeability based on the results of the inversion, according to the models and / or the anisotropy formulas of the permeability discussed above. In one embodiment, the inversion module 1506 can be configured to calculate the inverted BA parameters by performing an iterative inversion operation on the MCI data using a BA training model which represents the simulated resistivity characteristics. of the formation which take into account the bi-axial anisotropy of the formation in terms of resistivity as discussed above with regard to Figure 10. After the inversion treatment, the module for determining the permeability 1508 can perform the calculations of the anisotropy of the permeability. The system 1500 may further comprise an output module 1510 configured to deliver the components of the calculated permeability. The output module 1510 can in certain embodiments deliver to digital tables estimated values for the resistivity of the formation, the volume of laminated shale and / or various components of the permeability and the resistivity to invasion at multiple points. different along a drill hole. In other embodiments, a graphical plot that maps the estimated values to the positions in the borehole may be printed on a hard copy, and / or may be displayed on a display screen (e.g., a unit 1610 video display as described in greater detail below with reference to Figure 16). The various operations of the methods given as examples described here can be carried out, at least partially, by one or more processors which are temporarily configured (for example, by software) or permanently configured to carry out the relevant operations. . Whether configured temporarily or permanently, such processors can constitute modules implemented by a processor which operate to perform one or more operations or functions. The modules referred to here may, in certain embodiments given as examples, include modules implemented by a processor. Likewise, the methods described here can be at least partially implemented by a processor. For example, at least some of the operations of a method can be carried out by one or more processors or modules implemented by a processor. The performance of certain operations can be distributed among one or more processors, not only residing inside an individual machine, but also deployed in a number of machines. In some exemplary embodiments, the processor or processors may be located in a single location (for example, in a home environment, a desktop environment or as a cluster of servers), while in other modes processors can be distributed in a certain number of locations. One or more processors can also operate to support the performance of relevant operations in a "cloud" environment or as "software-service" (SaaS). For example, at least some of the operations can be carried out by a group of computers (as examples of machines comprising processors), these operations being accessible via a network (for example, Internet) and via one or more appropriate interfaces (for example , application programming interfaces (API).) [0099] Figure 16 is a diagrammatic representation of a machine in the form of an example of a computer system 1600 in which a set of instructions 1624 requesting the machine performing one or more of the methodologies discussed here can be executed. For example, the surface computer system 366 (Figure 3) or any one or more of its components can be provided by the system 1600. In other embodiments, the machine operates as a stand-alone device or can be connected (for example, networking) to other machines. In a network deployment, the machine can operate in the capacity of a server or a client machine in a server-client network environment, or as a peer machine in a peer-to-peer network environment ( or distributed). The machine can be a server computer, a client's computer, a personal computer (PC), a tablet PC, an external box (STB), a personal digital assistant (PDA), a cell phone, a web device , a network router, a switch or a bridge, or any machine capable of executing a set of instructions (sequentially or otherwise) that specify the actions to be taken by this machine. In addition, although only one machine is illustrated, the term "machine" should also be taken to include any set of machines which individually or collectively execute a set (or more sets) of instructions for performing any one or more of the methodologies. discussed here. The computer system 1600 given as an example comprises a processor 1602 (for example, a central processing unit (CPU) a graphics processing unit (GPU) or both), a main memory 1604 and a static memory 1606, which communicate with each other via a bus 1608. The computer system 1600 may further include a video display unit 1610 (for example, a liquid crystal display (LCD) device, a cathode ray tube screen (CRT) , etc.). The computer system 1600 also includes an alpha-numeric input device 1612 (for example, a keyboard), a cursor controller 1614 (for example, a mouse, a trackball, etc.), a reader unit for 1616 drives, a 1618 signal generation device (for example, a microphone / speaker) and a 1620 network interface device. The disk drive unit 1616 comprises a storage medium readable by a machine or readable by a computer 1622 on which are stored one or more sets of instructions 1624 (for example, software) incorporating one or more of any methodologies or functions described here. The instructions 1624 can also reside, completely or at least partially, inside the main memory 1604 and / or inside the processor 1602 during the execution thereof by the computer system 1600, the memory main 1604 and processor 1602 also constituting supports readable by a non-transient machine. The instructions 1624 can also be transmitted or received over a network 1626 via the network interface device 1620. Although the storage medium readable by a machine 1622 is illustrated in an embodiment given as an example in the form of a single medium, the term "medium readable by a machine" must be considered to include a single medium or multiple media (for example, a centralized or distributed database and / or caches and associated servers) that store one or more sets of 1624 instructions. The term "machine-readable media" should also be considered to include any medium which is capable of storing a set of instructions for execution by the machine and of causing the machine to perform any one or more of the methodologies of this disclosure. The term "machine readable media" should therefore be considered to include, but not be limited to, solid state memory devices of all types, as well as optical and magnetic media. Although the present disclosure has been described with reference to embodiments given in particular examples, it will be obvious that various modifications and various changes can be made to these embodiments without departing from the broader scope of disclosure. Consequently, the specification and the drawings should be considered in an illustrative rather than restrictive sense. [00105] Consequently, a method for determining the permeability of an earth formation 118 penetrated by a borehole 116 has been described. The embodiments of the method may generally include positioning a sensor 127 in the borehole 116, measuring the characteristics of the earth formation 118 using the sensor 127, logging the characteristics, and determining a permeability. effective based on log characteristics. Positioning a logging tool 126, 234, 365 in the borehole 116, measuring three-dimensional (3D) data using the logging tool 126, 234, 365, determining the 3D components of the resistivity R x , R y and R : of the earth formation 118 by inversion of 3D data, the logging of the 3D components of the resistivity R x , R y and R :, and the determination of the tri-axial components of the permeability k x , ky , k z on the basis of effective permeability and 3D component diagrams of resistivity. The determination of a permeability of sand k sd in the earth formation 118, based at least in part on the tri-axial components of the permeability k x , k y , k z , the effective permeability k e , and d a stratified shale volume V iam . Logging the permeability of the sand and initiating a modification to an operation (or operations) based on the permeability of the sand. Other embodiments of the method may generally include determining the permeability of the sand k S d in a stratified shale formation, drilling a borehole 116 through a land formation containing the shale formation stratified 118, the measurement of the parameters of the stratified shale formation 118 by a sensor 127 positioned in the borehole 116 and the logging of the parameters, the determination of an effective permeability k e on the basis of the parameters of the logging, the measurement of three-dimensional (3D) induction data for stratified shale 118 with a multi-component induction logging (MCI) tool 126, 234, 365, and calculation of the 3D components of resistivity from the data 3D induction. The determination of the tri-axial components of the permeability k x , k y , k z on the basis of the effective permeability k e and of a percentage of shale V iam which is present in the formation of stratified shale 118. The determination of the permeability of sand k s a based at least in part on the tri-axial components of the permeability k x , k y , k z , the effective permeability k e , and the percentage of shale Vi am , the logging of the permeability of sand k S ( ^, and initiation of a modification to a borehole operation based on the permeability of sand k S ( ^. For the previous embodiments, the method can comprise any one of the following elements, alone or in combination with each other: The method can also include initiating a modification to at least one of a drilling operation for a borehole, an operation for producing a borehole, an injection operation d a borehole and a borehole logging operation in response to the sand permeability diagrams k S d. It is understood that, "modification of a borehole operation" refers to the alteration of the performance of all activities which may occur during, for example, drilling, production, injection and / or RPM logging operations from the borehole. Examples of modifications to a drill hole drilling operation may be a change of direction of a drill bit, increasing / decreasing the speed of rotation of the drill bit, increasing / decreasing the forward speed of the drill bit, change in mud characteristics, etc. Examples of modifications to a borehole production operation may be changes to the screen sizes of the well and positions in a production tube, changes to cement parameters, changes to systems related to fluid flow. based on anticipated debits, etc. Examples of modifications to injection operations may be decisions made regarding the type of injection fluid to be used and the possible injection rates of the fluid. Examples of modifications to a logging operation may include performing more or less procedures for the wellbore logging parameters. The determination of the tri-axial components of the permeability k x , k y , k z can also include carrying out an iterative inversion operation on the 3D induction data. The logging tool 126, 234, 356 may include a multi-component induction measurement (MCI) device that measures 3D induction data. The effective permeability k e can represent an isotropic permeability of a stratified region of the earth formation 118, and the isotropic permeability k e can be measured by the sensor 127. The determination of the tri-axial components of the permeability k x , ky, k z can also include the calculation of one of the tri-axial components of the permeability k x , k y , k z for each of the directions along the x-axis, the y-axis and the z-axis in a shale formation. The determination of the tri-axial components of the permeability k x , k y , k z may furthermore include the calculation of the ratios -, -, and - between the pairs of the tri-axial components of ky fc z k z the permeability k x , k y , k z . Generalization of a display of one or more tri-axial components of the permeability k x , k y , k z for display on a display device 1610. Generalization of a visualization of the permeability of sand k S (i for display on the display device 1610. The sensor 127 can be chosen from a group consisting of a nuclear magnetic resonance (NMR) sensor , a multi-pole sonic logging (MSL) sensor and a resistivity sensor. Initiation of a modification to at least one of a drilling operation, a production operation, an injection operation and a logging operation in response to the display of the permeability of the sand k sd and / or of the tri-axial components of the permeability k x , k y , k z . In addition, a system for determining the permeability of an earth formation 118 penetrated by a borehole 116 has been described. System embodiments can generally include a data access module for accessing three-dimensional (3D) multicomponent induction (MCI) data captured by a logging tool 126, 234, 356 and isotropic permeability data k e captured by a sensor 127 in the borehole 116. An inversion module 1506 can calculate the inverted 3D resistivity parameters R x , R y and R- by performing an iterative inversion operation of the MCI data , a permeability determination module 1508 which can calculate the tri-axial components of the permeability k x , k y , k z based at least in part on the isotropic permeability data k e and 3D inverted resistivity parameters R x , R y and R-. A display device 1610 can generate a visualization of the tri-axial components of the permeability k x , k y , k z for the display intended for an operator or for the purpose of logging. Log or displayed data can be used to modify current and / or future operations. For any of the preceding embodiments, the system can comprise any of the following elements, alone or in combination with one another: The permeability determination module can calculate a permeability of the sand k S (i in the earth formation 118 on the basis of the tri-axial components of the permeability k x , k y , k z , of the isotropic permeability k e , and a volume of stratified shale Vi am . A volume of stratified shale V lam (which is a percentage of shale in a volume of land formation 118) and the permeability of sand k s a can be determined on the basis tri-axial components of the permeability k x , k y , k z , the isotropic permeability k e , and the permeability constants of the shale kfi, k y sh, k ^ h according to a profile of a diagram of the borehole 116. The permeability determination module 1508 can calculate the tri-axial components of the permeability k x , k y , k z based at least in part on the data and isotropic permeability ratios k e of the parameters of inverted 3D resistivity R x , R y and R - The calculations of the tri-axial components of the permeability k x , k y , k z can include compensations for the shale compaction effects. Sensor 127 can be selected from a group consisting of a nuclear magnetic resonance (NMR) sensor, a multipolar sonic logging (MSL) sensor and a resistivity sensor. In addition, the illustrative methods described here can be implemented by a system comprising a processing circuit which can include a non-transient computer-readable medium comprising instructions which, when executed by at least one processor of the circuit processing, causes the processor to perform any of the methods described here. Although various embodiments have been illustrated and described, the disclosure is not limited to these embodiments and it will be understood that it includes all the modifications and variations which would be obvious to a person skilled in the art. Therefore, it is understood that the disclosure is not limited to the particular forms disclosed; instead, the intention is to cover all modifications, equivalents and alternatives within the scope and spirit of the disclosure as defined by the appended claims.
权利要求:
Claims (15) [1" id="c-fr-0001] 1. Method for determining the permeability of an earth formation which has been penetrated by a borehole, the method comprising: positioning a sensor in the borehole; the measurement, via the sensor, of the characteristics of the earth formation, and the logging of the characteristics; determining an effective permeability based on the characteristics of the log; positioning a drilling tool in the borehole; measurement, using the three-dimensional (3D) induction tool (MCI); logging, multi-component data determination of the 3D components of the resistivity of the earth formation by inverting the 3D MCI data; the logging of the 3D components of the resistivity; determining the tri-axial components of the permeability based on the effective permeability and the 3D components of the log resistivity; determining a permeability of the sand from the sand of the earth formation, based at least in part on the tri-axial components of the permeability, the effective permeability, and a volume of stratified shale; sand permeability logging; and initiating a modification to a borehole operation based on the permeability of the sand. [2" id="c-fr-0002] 2. The method of claim 1, further comprising initiating a modification to at least one of a group consisting of an operation of drilling a borehole, an operation of producing a borehole, a borehole injection operation and a borehole logging operation in response to the logging permeability of the sand. [3" id="c-fr-0003] 3. Method according to claim 1, in which the determination of the tri-axial components of the permeability further comprises carrying out an iterative inversion operation on the 3D MCI data and / or a calculation of one of the components triaxial permeability for each of the x-axis, y-axis, and z-axis directions in a stratified formation. [4" id="c-fr-0004] The method of claim 1, wherein the logging tool comprises a multi-component induction measurement device that measures 3D MCI data, wherein the effective permeability represents an isotropic permeability of a layered region in an earth formation , and in which the isotropic permeability is measured by the sensor. [5" id="c-fr-0005] 5. Method according to claim 1, in which the determination of the tri-axial components of the permeability further comprises the calculation of the ratios between the pairs of the tri-axial components of the permeability. [6" id="c-fr-0006] 6. Method according to any one of claims 1 to 5, further comprising the generalization of a display of the tri-axial components of the permeability for display on a display device. [7" id="c-fr-0007] 7. Method according to any one of claims 1 to 5, in which the sensor is at least one of a group consisting of a nuclear magnetic resonance (NMR) sensor, of a multipolar sonic logging sensor ( MSL) and a resistivity sensor. [8" id="c-fr-0008] 8. Method according to any one of claims 1 to 5, further comprising the generalization of a visualization of the permeability of the sand for display on a display device. [9" id="c-fr-0009] 9. The method of claim 8, further comprising initiating a modification to at least one of a group consisting of an operation of drilling a borehole, an operation of producing a borehole, a borehole injection operation and a borehole logging operation in response to the display of sand permeability. [10" id="c-fr-0010] 10. System for determining the permeability of an earth formation which has been penetrated by a borehole, the method comprising: a data access module for accessing three-dimensional (3D) multi-component induction (MCI) data captured by a logging tool and isotropic permeability data captured by a sensor in the borehole; an inversion module which calculates the inverted 3D resistivity parameters by performing an iterative inversion operation of the 3D MCI data; a permeability determination module which calculates the tri-axial components of the permeability based at least in part on the isotropic permeability data and inverted 3D resistivity parameters; and a display device which generates a visualization of the tri-axial components of the permeability. [11" id="c-fr-0011] 11. The system as claimed in claim 10, in which the permeability determination module calculates a permeability of the sand of the earth formation, on the basis of the tri-axial components of the permeability, of the isotropic permeability data, and of a volume. stratified shale. [12" id="c-fr-0012] 12. The system of claim 11, wherein the volume of stratified shale and the permeability of the sand are determined on the basis of the tri-axial components of the permeability, the isotropic permeability data, and the constants of 5 permeability of the profile of a borehole diagram. [13" id="c-fr-0013] 13. The system of claim 10, wherein the permeability determination module calculates the triaxial components of the permeability based at least in part on the isotropic permeability data and the parameter reports 10 of inverted 3D resistivity. [14" id="c-fr-0014] 14. The system of claim 13, wherein the calculations of the tri-axial components of the permeability include compensations for the shale compaction effects. [15" id="c-fr-0015] 15. System according to any one of claims 10 to 14, 15 in which the sensor is at least one of a group consisting of a nuclear magnetic resonance (NMR) sensor, of a multipolar sonic logging sensor (MSL) and a resistivity sensor. 1/13 faith 104 Ζλλ ..... I / W LCÎ
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2018-09-28| PLFP| Fee payment|Year of fee payment: 2 | 2020-08-28| PLSC| Publication of the preliminary search report|Effective date: 20200828 | 2020-10-16| ST| Notification of lapse|Effective date: 20200910 |
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申请号 | 申请日 | 专利标题 PCT/US2016/014679|WO2017131608A1|2016-01-25|2016-01-25|Permeability anisotropy assessment in subsurface anisotropic formations| PCT/US2016/057138|WO2017131825A1|2016-01-25|2016-10-14|Determining permeability in subsurface anisotropic formations| 相关专利
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