FR3035674A1 - SHADE GEOMECHANICS FOR HYDRAULIC MULTI-STAGE FRACTURING OPTIMIZATION IN SCHOOL RESOURCES AND GREEN GAMES - Google Patents

Abstract

Computer systems, computer-implemented methods, and computer-readable media that allow the design of a hydraulic fracturing operation for a hydrocarbon reservoir (20), by providing for the definition of a anisotropy of a formation material in the reservoir (20); defining a heterogeneity of a formation material in the reservoir (20); creating, in a computer-readable memory (610) (600), an electronically recorded geomechanical model of at least a portion of the reservoir (20) based on at least anisotropy and heterogeneity, the geomechanical model giving predicting at least one of a pore pressure and in situ stress within the portion of the reservoir (20); defining a well bore (10) in the geomechanical model through the portion of the reservoir (20).

Description

FIELD OF THE INVENTION 10001] Embodiments presented herein generally relate to the modeling of oilfield formations, and more specifically to methods and systems for designing hydraulic fracturing operations and optimizing well production. BACKGROUND OF THE INVENTION 10002] Optimizing drilling in resource schists and tight games can be similar in some respects to that of conventional games. However, there are differences, for example with respect to the stability over time of the wellbore due to an exceptionally long horizontal well drilling. 10003] The development of hydrocarbon formations, such as resource shale and / or tight sets, can be costly and demanding, particularly when determining a suitable multi-stage fracturing stimulation (or "frac") design. Although the optimization of resource shale and tight games may be similar in some respects to that of conventional games, there are some differences, such as wellbore stability over time, due to relatively long horizontal well drilling. After successful development of eg. Barnett shale, other shale resources and tight games have been marketed throughout North America, and these efforts are now spreading elsewhere, for example in Central and South America, Europe, China, Australia and Russia. The success of resource shale and tight play derives at least in part from technological advances over the last decade, for example in the form of large volume multi-stage hydraulic fracturing in horizontal completions, passive microseismic monitoring and extensive three-dimensional seismic methods ("3D") fields. These technological advances in resource shale and tight play can result in unique geomechanical engineering challenges, such as long and horizontal well drilling and completion methods that enable complex multi-stage hydraulic fracture stimulation design. . Horizontal drilling can lead to significant stress-induced and time-dependent wellbore stability problems from a fluid-forming interaction. A common approach in some areas has been to duplicate the so-called Barnett design, such as the use of a water-based fracture fluid with a low concentration of proppant. However, Barnett's design may be relatively inefficient in fields other than Barnett Shale, such as Haynesville, Bakken and Eagle Ford shales. A recent trend in developing shale resources and tight games has been to reach an analog field, duplicate the optimized design in the analog field and then further optimize its trial-and-error design. However, this approach may require a considerable learning curve and associated costs to determine the optimal multistage fracturing design for at least one wellbore. The present disclosure relates to systems and methods for optimizing fracture designs for wellbores. BRIEF DESCRIPTION OF THE DRAWINGS [0005] Fig. 1 is a block diagram of a ground drilling system that may be used with at least one embodiment of a hydraulic fracturing process in accordance with the disclosure. Figure 2 is a schematic perspective view illustrating one of the many embodiments of a hydraulic fracturing process according to the disclosure. [0007] FIG. 3 is a table illustrating the relationships between hydraulic fracturing geometry, stress anisotropy and fragility of examples of reservoir formations in accordance with the disclosure. FIG. 4 is a perspective view illustrating one of many examples of the stress overlap in an alternative sequence fracturing operation in accordance with the disclosure. FIG. 5 is a schematic view illustrating a method of implementing at least one embodiment of a hydraulic fracturing model in accordance with the disclosure. Figure 6 is a computer system that can be used with at least one embodiment of a hydraulic fracturing process according to the disclosure.

DETAILED DESCRIPTION OF THE ILLUSTRATIVE EMBODIMENTS [0011] It will first be appreciated that the development of a real-world industrial application incorporating aspects of the disclosed embodiments will need to be carried out. DEJADE & BI SET +33142800183 T-419 P000610008 E-317 3 implementation-specific decisions to achieve the ultimate goal of the developer for the industrial embodiment. These implementation-specific decisions may include, and are not limited to, compliance with system, business, government and other constraints, which may vary depending on the implementation of the implementation. specific work, the specific place and other circumstances. While keeping in mind that a developer's efforts may be time-consuming in the strict sense, it would nevertheless be a routine undertaking for tradespeople who benefit from this disclosure. It should also be understood that the embodiments disclosed and taught herein are prone to many varied modifications and alternative forms. The present disclosure discloses systems and methods for optimizing wellbore production. The systems and methods of the present disclosure may help reduce a learning curve associated with the wellbore or formation and, in at least one embodiment, may include the provision of optimal fracture design parameters. based on geomechanical analyzes associated with geological, geophysical and / or petrophysical knowledge. In at least one embodiment, a method as disclosed herein may include defining a well direction, defining a fracturing spacing, selecting a fracturing fluid system, and optimizing a fracturing design, such as in the form of a multi-stage complex hydraulic fracturing design. A method as disclosed herein may include determining at least one geomechanical variable for at least a partial improvement in production, such as well placement, horizontal well direction, step isolation method, an interstage gap, a drilling site, a fracturing fluid system and a fracturing proppant. In at least one embodiment, a system may include at least one database integrating some or all of the geomechanical information associated with geological, geophysical, petrophysical and laboratory data for a field or for a formation. The geophysical and petrophysical analyzes of natural fractures and defects can also be understood and, in at least one embodiment, can be used for at least one stage of a fracturing design, such as for a final stage or the like, or a multi-stage hydraulic fracturing design, as explained in more detail below. The systems and methods of the present disclosure may play an important role throughout the life of a reservoir, which may be, but not necessarily, a reservoir such as a resource shale or a game. tight oil or gas. For example, while emerging fields such as those in Central / South America, Europe, China, Australia, Russia and elsewhere are being explored and placed in planning stages or well development, the advantages of the systems and methods disclosed herein can be obtained not only for the first well drilled at a particular location but for each well drilled in a particular reservoir, which may be any application-conforming reservoir. special. In addition, the systems and processes disclosed herein may be applicable during any hydrocarbon phase or other operations, such as, for example, exploration phases, planning and development phases and other phases, such as the drilling, completion and production phases, separately or in combination, in whole or in part. In at least one embodiment, a method as disclosed herein may comprise the construction of at least one model for estimating the properties or attributes of a formation, for example a model of mechanical ground for modeling at least a geomechanical feature of a formation. A terrestrial mechanical model, as well as the other models of the present disclosure, may be one-dimensional ("1D"), two-dimensional ("2D") or three-dimensional ("3D") and may be a single model, such as a model. independent, or a collective model, for example by forming part of at least one other model, for example a terrestrial model, a reservoir model or another model. A template may include any data or other application-conforming information. The model data may for example comprise information derived from a mechanical or other test, for example from major analyzes, and may include any of a number of characteristics associated with a formation, such as for example the anisotropy of shale, heterogeneity, pore pressure and other variables, such as in situ constraints. The systems and methods of the present disclosure which may, but not necessarily, be fully or partially implemented through a computer-implemented model, may be particularly advantageous for developing unconventional fields, including the drilling and completion optimization as discussed in more detail here. [0015] According to at least one embodiment, a method as disclosed herein may include the construction of a geomechanical model for a resource shale or other game, which may at least partially include the definition of anisotropy and heterogeneity of a formation and the development or optimization of a multi-stage fracturing design for the formation. A method as disclosed herein may include developing or optimizing a drilling phase for a formation, which may include performing at least one analysis to determine or estimate drilling characteristics of the formation. For example, a wellbore stability analysis may include the determination of shear failure, form shear, critical stresses (eg, fractures or critical stress defects), or other factors, such as time dependency. A method as disclosed herein may include conducting a wellbore trajectory analysis to determine the length, direction, and overall path of a wellbore. A method as disclosed herein may include determining at least one drilling tool or property, which may include identifying any number of factors, such as at least the sludge weight, the chemical composition of the mud, bit selections, trajectory, proper installation of side parts, data collection during drilling, formwork, etc. [0016] A method for optimizing a well may include the development of a reservoir-specific multi-stage hydraulic fracturing design to optimize the recovery of hydrocarbons from a formation. According to at least one embodiment, a method as disclosed herein may include a determination of a horizontal or otherwise well direction, the determination of fracability, the determination of a hydraulic fracturing geometry, the risk assessment. of reactivation by default, determination of lateral well spacing, determination of hydraulic fracturing intervals and determination of at least one fracturing location (i.e. a well, separately or in combination, in whole or in part. In at least one embodiment, a horizontal well direction may be determined based on a planned or potential fracturing design, for example longitudinal or transverse. In at least some cases, a wellbore, such as a horizontal wellbore, may be formed in the same direction or in a direction similar to the direction of a minimum horizontal stress in a formation. For example, a well may be drilled parallel to a minimum horizontal stress vector to obtain transverse hydraulic fractures in a reservoir. If stresses and stress directions within a formation are not considered or otherwise properly analyzed, the hydraulic fractures created may be less than optimal, which implies the development of undesirable complexities or formation in undesirable directions ( eg by reorienting a parallel to a maximum direction of stress). This can lead to undesirable effects, such as undesirable multiple fractures, the creation of near-well tortuosity and decreases in near-well fracturing conductivity, which can lead to an increase in treatment pressure. induction of early blockages. A local direction of maximum horizontal stress for transverse hydraulic fractures can be defined in at least one embodiment from wellbore image logs, sonic logs oriented through a dipole and / or microseismic monitoring data. Because of inherent differences, e.g. Because of the anisotropy and heterogeneity of respective tight shale reservoirs and other formations, it may be advantageous to perform multi-stage fracturing designs on tank-specific bases. While one or more embodiments of the present disclosure are described in more detail below with reference to an exemplary reservoir and associated orientations, one of ordinary skill in the art benefiting from the present The disclosure will readily understand that these examples are only one part of a multitude of examples, and that the systems and methods disclosed herein may be applicable to any reservoir formation and wellbore. Referring now to Figure 1, there is shown a terrestrial drilling system 100 which may be used for hydraulic fracturing in connection with certain aspects of the exemplary embodiments disclosed herein. The earth drilling system 100 may be used to drill a wellbore 10 in a reservoir 20 from a surface location 12, which may be a ground surface, a drilling platform, or any other location outside the well. drilling 10 from which drilling can be controlled. The earth drilling system 100 includes a drill string 26 suspended therefrom, composed of a continuous length of pipe known as a drill pipe, which consists of relatively short interconnected pipe sections 51. The drill string 26 typically contains a bottomhole assembly attached to the end thereof, which includes a rotary drill motor 30 connected to a bit 32. Drilling usually occurs in a sliding borehole where the drill bit 32 is rotated by the drill motor 30 during drilling, but the drill pipe is not rotated during drilling. The ability to perform sliding drilling allows, among other things, the control of the bit trajectory 32, which initiates drilling in a direction inclined relative to the vertical, including in a horizontal direction.

FIG. 2 is a schematic perspective view illustrating one of many embodiments of a hydraulic fracturing process in accordance with the disclosure. In at least one embodiment, a method as disclosed herein may include determining a fracture spacing, or puncture interval, for a reservoir or wellbore, such as to at least enhance the production from the reservoir depending on the complexity or the conductivity of the fracturing. Finding an optimal or other perforation interval between the hydraulic fracturing stages can improve the artificial amplification of complex network fractures and the fracturing conductivity in some formations, which may include a resource shale, tight play or formations where a planar form of hydraulic fracturing geometry is present or provided. The effects of spacing between fractures, i.e. amplification of complex network fractures and non-proppant fracturing conductivity may be universal for some of the multi-stage fracturing techniques (eg, sequence, zipper, etc.). However, for purposes of illustration, Figure 2 shows an alternative sequence fracturing ("ASF") operation known as "Texas in two steps", among many examples. During such a fracturing operation, the wellbore 10 can be perforated at a plurality of locations along its length for hydraulic fracturing of the reservoir 20, this fracturing can take place in different sequences or stages. As shown in part of the wellbore 10 of Fig. 2, for example, a fracturing operation may comprise three adjacent fracturing perforations, referred to herein and referred to in Fig. 2 as stages 1, 2 , 3 fracturing in the order in which the fracturing takes place. Once fracturing stages 1 and 2 take place, hydraulic fractures (eg planar complex) can be produced with limited reservoir contact and normal fracturing conductivity at horizontal wellbore 10. However, because stages I and 2 of fracturing take place, a stress overlap can increase the stress in at least one direction between the two fracturing stages, which can reduce stress anisotropy between the two fracture sites. For example, if the wellbore 10 is parallel to the direction of minimum horizontal stress in a formation (the direction of Sh in the example of Figure 2), the fracturing stages 1 and 2 result in a stress overlap increasing the Stress in the Sh direction between the stages. Fracturing at stage 3 can create more complex fractures, such as complex network fractures. In such an example, which is only one of many, the fracturing stage 3 can create more reservoir contact and better fracture conductivity without a proppant normally to a horizontal well. Accordingly, it may be advantageous to incorporate the effects of stress overlap in determining a multi-stage hydraulic fracturing system for a reservoir to optimize or at least partially enhance the boosted reservoir volume ("SRV"). . FIG. 3 is a table illustrating the relationships between hydraulic fracturing geometry, stress anisotropy and fragility of exemplary reservoir formations according to the disclosure. According to at least one embodiment, a method as disclosed herein may include the definition of what is called "fracability" of a formation that may, but not necessarily, take place after determining a horizontal direction or another well for a desired multi-stage fracturing design (eg transverse). The fracability and inherent hydraulic fracturing geometry can be estimated, approximated or otherwise defined by the stress anisotropy and the fragility of a formation, such as resource shale and / or tight reservoir formation. The term fracability corresponds to the anticipated geometry or the complexity of fractures likely to form in a formation (which may be any formation) because of the hydraulic fracturing operations with respect to the fracture geometry in another formation or part of the same training. As illustrated in Figure 3, in some cases this geometry can range from flat fractures to complex network fractures. Generally, a formation with a higher degree of smoothness corresponds to a formation that is more able to show relatively complex hydraulic fractures than a formation with lesser fracability. As the complexity of fracturing changes from flat to complex, reservoir contact and fracking conductivity without a proppant may increase.

According to at least one embodiment of the present disclosure, the fracability and inherent hydraulic fracturing geometry of a formation can be estimated or otherwise incorporated into a method and / or system for hydraulically fracturing a formation along a pathway. wellbore. Factors that control or otherwise affect the fracability and inherent fracture geometry of a formation may include geological constraints (eg, in situ stresses) and rock mechanical properties (fracture). In at least one embodiment, the geological stresses and mechanical properties of a formation may be represented by brittleness and stress anisotropy, and a method as disclosed herein may include determining the property among fragility and stress anisotropy that is better able to control the hydraulic fracture geometry of a formation. For example, high fragility and low stress anisotropy of a formation induce more complexity of the hydraulic fracture geometry (eg more formation contact and more production). But if either of these control parameters is unfavorable with respect to the complexity of hydraulic fracturing geometry (ie, low brittleness or high stress anisotropy). ), the complexity of the hydraulic fracturing geometry decreases markedly. This means that brittleness and stress anisotropy are the main parameters for defining hydraulic fracturing geometry. A method as disclosed herein may further include determining the direction of stress anisotropy (e.g., horizontal or vertical) that is most likely to control the hydraulic fracturing geometry of a formation, as details below. According to at least one embodiment, a multi-stage hydraulic fracturing method or system may comprise the representation of geostresses (eg in situ stresses) in the form of anisotropy in at least one horizontal or vertical direction. . The horizontal stress anisotropy can be defined according to the following equation (Equation 1): HSAI -1SH -S11 \ [0022] Sh [0023] where HSAI = horizontal stress anisotropy, SH = maximum horizontal stress and Sh = stress horizontal minimum [0024] The vertical stress anisotropy can be defined according to the following equation 10 (Equation 2): [0025] VSAI Sh (Sy-Sh) [0026] where VSAI = vertical stress anisotropy, Sv = vertical stress [0027] HSAI and VSAI can be expressed as unitless values, by another example, or percentages. A relatively high HSAI may indicate hydraulic fractures relatively more prone to growth in the SH direction. A relatively low HSAI may indicate hydraulic fractures relatively less likely to grow in the SH direction, which may result in more complex hydraulic fractures, such as a complex network. Likewise, a relatively high VSAI may indicate relatively more inclined hydraulic fractures in the Sv direction, and a relatively low VSAI may indicate relatively less inclined hydraulic fractures in the Sv direction. The results of at least Tank formation can be correlated or otherwise compared and displayed as a table, graph or graphical user interface ("GUI"). In addition or otherwise, the mechanical properties of rock (fracture) in a formation can be represented in terms of fragility. Fragility can be commonly represented using a fragility index, or pseudo-fragility index, as a function of a combination of Young's modulus and Poisson's number. Generally, a relatively high Young's modulus rock and a relatively low Poisson's number must be relatively brittle (ie, have a relatively high brittleness index). A relatively high fragility index may indicate hydraulic fractures relatively more prone to developing complex network fractures. In addition, a method as disclosed herein may include determining an optimal system of fracturing fluid, which may include determining an optimal proppant. The selection of the fluid system and the proppant may be based on the fracability or type of hydraulic fracturing geometry, which can be determined by stress anisotropy and fragility as indicates elsewhere here. Depending on the type of hydraulic fracture geometry estimated (eg complex grid plane), an optimal system of fracturing fluid and a volume of proppant, a type and a size can be selected (eg a cross-linked gel to a pool water system). According to at least one embodiment, methods or systems for designing or implementing a multistage hydraulic fracturing operation to increase the SRV of a reservoir (which may be or include any reservoir) may comprise determining at least one of modified or manipulated stress anisotropy, such as manipulated vertical stress anisotropy (VSAI *) or manipulated horizontal stress anisotropy (HSAI *). For example, manipulated horizontal and vertical stress anisotropies for at least one reservoir gap between the multistage hydraulic fracturing stages can be determined. Like HSAI and VSAI, HSAI * and VSAI * can be expressed as unitless values or percentages. We can define the horizontal stress anisotropy manipulated according to the following equation (Equation 3): HSAI- - (SH 10030] Sh [0031] where HSAI * = manipulated horizontal stress anisotropy, SH = maximum horizontal stress 25 and Sh * = minimal horizontal stress manipulated [0032] The vertical stress anisotropy manipulated can be defined according to the following equation (Equation 4): VSAI-Sv -Shi [0033] Sh [0034] where VSAI * = constraint anisotropy vertically manipulated, Sv = vertical overload stress and Sh * = minimum horizontal stress manipulated The minimum manipulated horizontal stress Sh * can correspond to the increase in stress in the Sh direction caused by stress overlap due to fracturing (eg hydraulic fracturing pressure and hydraulic fracture opening), so a more accurate SRV can be estimated for a handy reservoir. develop and implement an improved multi-stage hydraulic fracturing plan. FIG. 4 is a perspective view illustrating one of many examples of the stress overlap in an alternative sequence fracturing operation in accordance with the disclosure. As noted above, an increase in stress overlap may result from a third hydraulic fracturing between two existing or other hydraulic fractures (anywhere between them). According to at least one embodiment of the present disclosure, the stress overlap may be modeled or otherwise represented by a numerical stress analysis, which may include stress overlap modeling or the potential effects of increased complexity fractures using the discrete element method or finite element analysis. In the example shown for purposes of illustration in Figure 4, a 50% brittleness index was assumed, as well as a slip fault stress regime (ie SH> overload> sh). This is not necessarily and probably not always the case of course, as fragility, stress regime and other factors may vary from one formation to another. In the example of FIG. 4, among others, the numerical stress analysis shows that the stress in the direction Sh (normal to the hydraulic fracture planes P1, P2, P3) increases by about 55%, and that the Consecutive anisotropy of stress decreases from about 95% to about 30%. Likewise, the example analysis shows the increase in process pressure (eg more than 6%) for the third fracture to create a similar volume of fracturing. However, the treatment pressure may not represent potential complex fractures that can be created. This means that the increase in actual process pressure may be greater when it is associated with potential complex fractures created between the two previous fracture stages. FIG. 5 is a schematic view illustrating a method of implementing at least one embodiment of a hydraulic fracturing model in accordance with the disclosure. In at least one embodiment, the flowchart may include (as generally indicated in block 500) modeling, recommendation, or otherwise determining a fracturing fluid system based on geomechanical information. such as geostresses and forming properties, and an estimate or other determination of the type and complexity of hydraulic fractures likely to occur as a result of fracturing operations in a formation or part of a formation , which may be training or include any training or part of an application-specific training. The flowchart may also include the analysis of at least one set of geomechanical data, the determination of at least one fracturing geometry, the calculation of at least one value representing the fragility, the calculation of at least one value representing HSAI, the calculation of at least one value representing VSAI and the recommendation, emission or otherwise the determination of at least one characteristic of a hydraulic fracturing operation. The flowchart may further include defining at least either the fracability or the hydraulic fracturing geometry of a formation in function or at least one of the brittleness or anisotropy. 10038] As shown in the exemplary embodiment of Fig. 5, inter alia, a determination (block 502) can be made as to whether a formation has a relatively high fracability, medium fracability, or low fracability. A relatively high fractionability (block 504) can be or include a brittleness of 60 to 80% and an HSAI of 10 to 30%, and the corresponding hydraulic fractures can be of the network type complex (block 506). A relatively low fracability (block 508) may be or comprise a brittleness of less than 30% and an HSAI of any value, and the corresponding hydraulic fractures may be of the planar type or of moderate complexity (block 510). Average wrinkling (block 512) (as well as high and low fracability) may include formations having a brittleness interval and HSAI / VSAI values. A medium fracability, a medium fragility formwork (block 514) can be or comprise a brittleness of 30 to 60% and an HSAI greater than 30%, and the corresponding hydraulic fractures can be of the plane complex type. A medium fracability, a high fragility formwork (block 520) can be or comprise a brittleness of 60 to 80% and an HSAI greater than 100%, and the corresponding hydraulic fractures can be of the plane complex type. Of course, as will be understood by those skilled in the art having the present disclosure, all values and intervals shown and shown for Figure 5 and elsewhere herein are for explanation and illustration purposes only. These values and ranges may be the same or different for at least one formation subject to real world applications, and these values and ranges may and probably must differ from one formation to another and from one application to another. the other. [0039] Still with reference to FIG. 5, a method as disclosed herein may comprise the realization of at least one numerical stress analysis and a definition of the spacing between fractures, for example in the form of at least one potentially spacing. optimal fracturing for training based on at least one target stress value for formation. A target constraint value, such as target HSAI * or target VSAI *, may be or include a single value, multiple values, a combination of these, or as another example, a value that is related to one way or another to the above. A target stress value or a set of target stress values may represent or otherwise indicate at least one location for perforating a wellbore. As shown for purposes of illustration in Fig. 5, a stress target value for medium fracability, a medium fragility formwork may be or include, but not necessarily, an HSAI range greater than 10 to 30% (block 516). ). A target stress value for medium fracability, high fragility formwork may include, but not necessarily, an HSA1 range of 10 to 30%, and a VSAI range greater than 10% (block 522). According to at least one embodiment, among other things, it is possible to determine an optimal or otherwise desirable spacing between fractures by defining at least two perforation locations having one or more spacings between them, by modeling a perforation and a fracturing complexity. at at least one of the perforation locations, modeling the production obtained and repeating the above steps for different perforation locations and fracture spacings. Production models can be compared and perforation locations and fracturing spacing can be determined for a particular training at hand, which can be any training (including any part of a formation). For example, it is possible to recommend or choose perforation locations and fracturing spacing for physical training in which the production model predicts the most desirable results, which may or may not include any result, such as, but not limited to , the largest production. In addition, or otherwise, a method as disclosed herein may include determining a fracturing fluid system useful for formation, which may comprise a fracturing fluid alone or a fluid associated with at least one proppant. As shown in the exemplary embodiment of FIG. 5, inter alia, a low-viscosity fine particle propellant fracturing fluid viscosity system associated with a relatively large fracturing spacing (e.g. groundwater, a 100 mesh backing agent, and a fracture spacing of more than 300 feet, or approximately more than 91.4 m) may be advantageous for at least high fracability, complex fracturing formations 10, while a high viscosity, a coarse propellant fracturing fluid system (eg, a crosslinked gel type fluid, a 20/40 mesh proppant) may be advantageous for less fracible fracture formation weak, flat. In at least one embodiment, a method as disclosed herein may include determining a fracturing spacing based on the quality of reservoir formation, for example, by simulating the reservoir as a computer model or otherwise.

100401 In medium fracability, complex fracture planar formations, other fracture fluid systems, and fracturing spacings may be advantageous. As will be understood by one ordinary experience expert benefiting from the present disclosure, one or more of the systems and methods disclosed herein may include estimating or otherwise determining an optimized or at least partially improved fracturing fluid system. fracture spacing for improved fracability formation or production estimates derived from a comparison of at least two model constructs constructed according to the disclosure, separately or in combination, in whole or in part (usually indicated in block 518 and 524). Specifically, many shale or tight shale formations have medium fracability, which can lead to medium fragility (eg 30 to 60%) and medium to high HSAI (eg 30 to 100%). or more than 100%), or high brittleness (eg 60 to 70%) and high HSAI (eg more than 100%), separately or in combination, in whole or in part. For at least a portion of the medium-fracability formations, a hybrid fracturing fluid system may be used, which may include starting with a low viscosity fluid, a fine particulate propellant fracturing fluid and terminating with a high viscosity fracturing fluid and raw proppant. However, the fracability of these formations can be improved or increased and the inherent complexity of hydraulic fractures can be artificially improved, and in at least one embodiment, the systems and methods disclosed herein can comprise at least in part the improvement. the increase and the estimate of an amplitude of this increase or improvement. [00411] Still in reference to Fig. 5, according to at least one embodiment, a method as disclosed herein may include reducing the fracture spacing 10 in a multi-stage hydraulic fracturing design (e.g., from 300 to 150 feet, or about 91.4 to 45.7 m) and increasing stresses in a formation between at least two hydraulic fractures, as by creation or by increasing stress overlap. A method as disclosed herein may include increasing stress overlap in a direction normal to or approximately normal to at least one hydraulic fracturing (i.e., increasing Sh) and reducing HSAI in at least part of the training (see Equation 1). A method as disclosed herein may include estimating a reduction in HSAI, which may include performing a numerical stress analysis for at least a portion of the formation (see, eg, Figure 4), as an analysis based on data representing at least one geoconstraint, formation rock properties and net pressure, separately or in combination, in whole or in part. These data can be obtained, but not necessarily, from a single conventional hydraulic fracturing operation. According to at least one embodiment, a method as disclosed herein may include determining or identifying a target HSAI for training, modeling the formation and iterations or otherwise, determining at least one of fracturing spacing and a fracturing fluid system that leads at least in part to the target HSAI. A method as disclosed herein may include producing a set of instructions to achieve the target HSAI and hydraulic fracturing of a wellbore according to the instructions, which may include at least one of the initial hydraulic fracturing of a well. drilling is the modification of an earlier hydraulic fracturing system for a wellbore, for example by changing a fracturing fluid, a proppant or a spacing. According to at least one embodiment, a method as disclosed herein may include limiting or otherwise controlling a variation of Sh to maintain the VSAI at or near a certain value, or within a certain range of times. values (see Equations 1, 2). For example, in some formations, such as in medium fracability formation with high brittleness and high HSAI, a relatively low target (eg, 10-30%) HSAI fracturing pattern may result in fracture production. horizontal or other likely to be involuntary or undesirable. In these cases, or in other applications, a method according to the disclosure may include determining at least one limit for Sh to maintain a VSAI greater than zero (eg 10% or some other value greater than zero). ). However, this does not have to be the case and otherwise, or collectively, a value of Sh can result in a VSAI of less than or equal to zero. [0042] At least one further embodiment of the systems and methods of the present disclosure will now be described, which systems and methods may be combined, in whole or in part, with those described above. According to at least one embodiment, a method as disclosed herein may comprise the construction of a geomechanical model of a formation, the completion of a petrophysical fracture analysis of the formation, the realization of a hydraulic fracturing design for at least one fracture along a wellbore through or in the formation, conducting a stress analysis of the formation as a function of at least one fracture and performing a reservoir simulation of production from the formation through the wellbore as fractured. Hydrocarbon formations may exhibit various types or forms of fracturing when subjected to hydraulic fracturing operations. As noted above, for example, depending on the formation and at least one of the other factors described herein (or other factors likely to be known in the art), hydraulically fractured formations may give simple fractures, complex fractures, complex fractures with fissure openings and others, such as complex fracture networks made up of many fractures, which can include any type of fracture in fluid communication with one another. other, in whole or in part. The two types of fractures in a particular formation or in a particular reservoir may relate to at least one characteristic of the formation and / or the materials present in the formation. These characteristics may include, for example, stress anisotropy and brittleness, inter alia, eg, mineralogy, rock strength, porosity, permeability, clay content or other types of soil, total organic carbon ("TOC"), thermal maturity, gas content, gas in place, organic content and organic maturity, separately or in combination, in whole or in part. The attributes and characteristics of a formation, and the types of fractures expected to give hydraulic fracturing of this formation, may affect at least one consideration when considering potential fracturing approaches, such as for example a completion study. Other factors that may affect fracturing design may include tank or formation test results, for example, logging and core analyzes which, if present, may be incorporated. in one or more of the systems disclosed here. According to at least one embodiment, a method as disclosed herein may include the determination, estimation or definition, which may include modeling, any well direction, horizontal or otherwise, the number of sets of perforations , the spacing between the perforation sets, the location for each set of perforations, the type of fracturing fluid and the fracturing fluid injection rate, among other factors, such as the type of proppant and the amount of proppant. The systems and methods of the present disclosure may be used during any development phase of a formation, which may be any training in accordance with a particular application. For example, the systems and methods of the present disclosure may be used during exploration phases, planning phases, well development phases and other phases, such as drilling optimization or optimization. completion, singly or in combination, in whole or in part. According to at least one embodiment, a method as disclosed herein may include constructing a geomechanical model, such as a 1D, 2D or 3D model, performing a core analysis (eg to determine anisotropy and / or heterogeneity of at least one material, such as shale), performing pore pressure analysis, performing in situ stress analysis and estimating at least one mechanical property of a formation through the wellbore as fractured. In at least one embodiment, a method as disclosed herein may include conducting a drill optimization analysis, which may, but not necessarily, include performing the wellbore stability to determine the shear failure, time dependence, form shear, critical stress fractures or defects or other factors or parameters. A drill optimization analysis may include, but not necessarily, the completion of a wellbore trajectory analysis to determine (whether it is a certainty or an estimate) the trajectory of a wellbore trajectory. one of the wells. These analyzes can lead to the identification of at least one optimal drilling design parameter, such as sludge weight, sludge chemistry, trajectory, or other factors, such as formwork type. According to at least one embodiment, a method as disclosed herein may include completing completion optimization analysis, such as to determine tank-specific design, multistage, or other hydraulic fracturing. For example, a method as disclosed herein may include determining a horizontal wellbore direction, defining fracability, determining a fracturing geometry, evaluating default reactivation risks, determining determining lateral spacing of wells and other steps, such as, for example, determining the interval (i.e., spacing) of hydraulic fracturing and the precise location or otherwise the determination of at least one optimal hydraulic fracturing (ie perforation) location along at least one wellbore. In this context, the terms formation and reservoir are synonymous unless otherwise stated, and both terms may include an entire formation or part of a formation. According to at least one embodiment, a method as disclosed herein may include the creation, processing or otherwise the analysis of a series of models, which may include 1D, 2D and / or 3D models, and estimating, recommending or otherwise identifying an optimal (or at least potentially advantageous in at least one manner) hydraulic fracturing ("HF") or "fracturing design" operation for a wellbore, which may include a single-stage or multistage fracturing design. For example, a method as disclosed herein may include drilling model analysis, stress model analysis, basin model analysis, seismic model analysis, and analysis of at least one other model, such as a geographic scale model (eg regional, local or other), a numerical stress model or a thermal model, separately or in combination, wholly or in part. A method disclosed herein may include modeling and analyzing many factors associated with at least one formation or wellbore, such as salt content, production, injection, sanding, geothermal factors and / or other factors, such as at least one factor or parameter described elsewhere here. According to at least one embodiment, at least one existing software application can be used to develop or otherwise analyze at least one of the models described herein, such as, for example, Drillworks Predict®, Geostress®, Presage® or Drillworks 3D®. However, this is not a necessity and if not or collectively, at least one software application can be developed independently to implement the systems and methods of the present disclosure, separately or in combination with one another or with one another. less an existing application. In at least one embodiment, a method as disclosed herein may include entering, processing or otherwise analyzing data associated with at least one formation or wellbore, which may include the actual data collected, the estimated data, the predicted data, the calculated data and / or any other data in accordance with a particular application, such as known data of operations that have taken place or are in progress within at least one formation or at least one wellbore or for one of these. For example, the training data may be or include data or other information extracted from wireline operations, logging operations ("LWD"), heart tests and other tests. or analyzes. In at least one embodiment, a method described herein may include analysis of formation data relating to either lithology (eg, gamma rays), resistivity, pore pressure, sonic data (eg, dipole). traversed oriented), mechanical properties and other rock properties, density, temperature, pressure, overload, wellbore stability, formation images, formation stresses, natural fractures, uniaxial compression or multiaxial, compression considering shale or other anisotropy (eg normal and parallel to stratification), Young's modulus (eg vertical and horizontal), Poisson's number (eg vertical and horizontal) , mineralogy (eg X-ray diffraction ("XRD"), well stability over time, fluid-rock interaction (eg capillary suction time test ("CST") "), The agent integration support, Brinnell hardness, hole size, well depth, shear, tensile forces, crumbling, formation materials, fracture, drilling induced fractures (e.g. tensile fractures), stress regions, global stress maps, in situ stress regimes (eg extension regimes, strikeback regimes, compression regimes), drilling instability, well instability, occurrence of defects (eg normal defects, sink fault, inversion fault), instabilities with and / or without consideration of anisotropy (eg shale anisotropy) and / or hole cleaning, flow rates, fracture size, fluid type, proppant concentration, fluid volume, proppant volume, number of fracturing stages, effective containment pressure , effective average stress, stratification, shale or other material quality of formation, trajectory, efficiency, separately or in combination, in whole or in part. In at least one embodiment, a method as disclosed herein may include creating a seismic interval velocity model of a formation, creating a pore pressure gradient model of a training, creating an overload gradient model of a formation and creating a fracture gradient model of a formation. A method as disclosed herein may include in situ stress analysis, which may include determining an applicable stress regime, determining an applicable type of defect and determining at least one stress effect and defects on at least one wellbore. A method as disclosed herein may include determining how well stability may vary depending on the location and position of the well, which may include determining a most stable direction, from minus a stable direction and relative stabilities in at least one other direction. A method as disclosed herein may include determining a zero strain direction of anisotropy in a formation and how that direction varies if it does so, such as according to at least one constraint in at least one direction of stress. within the training. A method as disclosed herein may include modeling, predicting or otherwise analyzing the complexity of at least one hydraulic or other fracture as a function of in situ or other stresses present in a formation. A system may comprise a set of data representing at least one HF factor, such as a set of data relating to the fracturing geometry to at least one parameter capable of controlling or otherwise affecting the fracture geometry resulting from a Hydraulic fracking. For example, a data set may contain information regarding the type of fracture geometry, stress anisotropy, fragility, completion study and at least one reservoir, and may relate or compare this information. when they concern the tank in number of at least one. In at least one embodiment, a set of data may represent the relative presence or magnitude of reservoir contact, fracturing conductivity, and natural fractures among one or more formations, for example as a function of at least one attribute of the formation (s), e.g. fragility, Young's modulus, Poisson's number and / or at least one other factor mentioned here. In at least one embodiment, a method as disclosed herein may include defining a location, a spacing, a number, a direction, and a sequence of perforations for at least one embodiment. minus one wellbore, the VRS analysis, the modification of at least one of the preceding factors, the new VRS analysis for at least one well and the determination of the differences of VRS (or other characteristics) in the light changes. A method as disclosed herein may include these steps manually, automatically or otherwise, separately or in combination, in whole or in part, and may include performing any one of the steps in any order and in any number of ways. iterations. A method as disclosed herein may include identifying at least one parameter capable of regulating HF geometry in a formation, which may be or include any of the parameters and other factors described herein. A method as disclosed herein may include selecting a fracturing fluid and a proppant system for formation based on at least one HF geometry control parameter within the formation. A method as disclosed herein may include monitoring the parameters and other factors described herein during production operations and modifying at least one aspect of a fracturing design for a formation. According to at least one embodiment, among others, a method as disclosed herein may include modeling or otherwise analyzing the characteristics of a reservoir over a distance or length of a wellbore, which may be any distance according to a particular application. The method may include analyzing the stress anisotropy and the fragility index (or fi-acability) of that portion of the reservoir, comparing the above information and identifying at least one location where to perforate the formation. to favor (or at least potentially foster) the best possible production from this training. The method may include determining a useful fracturing system in the area (s) analyzed. Thus, at least partly optimized production can be achieved and costs limited by combining reservoir petrophysical characteristics and geomechanical scribing analyzes along at least one horizontal well in or through a formation. A method of optimizing production from a well may include the combination of petrophysical and geomechanical analyzes to determine locations, directions and preferable sequences of hydraulic fracturing. Geophysical and petrophysical analyzes of natural fractures and defects can also be used, for example, to design final or even multistage hydraulic fracturing systems. In at least one embodiment, a multi-stage fracturing operation modeling system may be or include a computer model of at least one wellbore, formations, stresses, stress anisotropies, fragility, hydraulic fractures, perforation types, perforation spacings, fracturing fluids, proppants, drilling equipment, pipes, drilling fluids and other variables, attributes described here. According to at least one embodiment, a multistage fracturing operation modeling system may be implemented, in whole or in part, by software, such as at least one software application described above. The software may include, for example, subroutines, programs, objects, components, data structures that perform particular tasks, or implement data types, such as abstract data or other types of data. data. The interface (s) and implementations of the present disclosure may reside on a suitable computer system (which may be any computer or computer system required by a particular application) comprising at least one computer processor, such as Intel Xeon 5500, and a medium computer readable record, which may be accessible by a number of storage media, including semiconductor memory, hard disk, CD-ROM and other media already known or developed in the future . One or more embodiments of the disclosure may also cooperate with at least one other system resource, such as Oracle® Enterprise, and appropriate operating system resources, such as Microsoft® Windows®, Red Hat® or others, separately or in combination. 10049] One or more embodiments of the present disclosure may cooperate with other databases and with other resources available for a multistage fracturing system or network. For example, at least one implementation may cooperate with at least one database, such as a database accessible on the same computer, on a local data bus, or across a network connection. The network connection may be a public network, such as the Internet, a private network, such as a local area network ("LAN") or a certain combination of 10 networks. Those skilled in the art benefiting from this disclosure will appreciate that one or more embodiments of the disclosure may be implemented in a variety of computer system configurations, or computer architectures. It will be appreciated that any number of computer systems and computer networks are acceptable for use in embodiments of the present disclosure. Still other embodiments may be implemented in distributed computing environments such as when the tasks are performed by remotely controlled devices that can be connected by a telecommunication network. In a distributed computing environment, program modules may be located, but not necessarily, both on local and remote computer-based storage medium 20, including memory storage devices or other media.

100501 One or more embodiments of the disclosure may be recorded on computer readable media, such as hard disks, DVDs, CD ROMs, flash drives or other readable semiconductor media, magnetic or optical, separately or in combination, in whole or in part. These computer recording media may carry computer readable instructions, data structures, program modules, and other data representing one or more embodiments of the disclosure, or portions thereof, for loading and for execution by an implementation computer system. While at least one other internal component of the appropriate computer system may not be specifically illustrated or described herein, it will be understood by those of ordinary skill in the art that these components and their interconnection and operation are well known.

According to at least one embodiment of the disclosure, federation of data or other techniques can be used to combine information from at least one database, such as information concerning at least one training. or other features thereof, separately or in combination with information from at least one other source (eg, those described elsewhere herein), in an optimization system of a model or design of hydraulic fracturing system. This is possible according to a computer-implemented process that synchronizes (eg periodically, continuously, or otherwise) the model with, for example, the most current information regarding a physical oilfield formation available at a particular time or at times of interest for the user. There are many sources of information that can be used to obtain information in an optimized fracturing model according to the embodiments of the disclosure. The database (s) of data used by Landmark Graphics OpenWells® Engineering Data Model (EDM), those used by Peloton's Wellview® 15 (MasterView) or other operational databases Well drilling can provide data such as well latitude and longitude in one or more formations. In addition, or alternatively, a disclosure-compliant system can provide information from at least one geographic information system (GIS), public data sources, or other sources, such as databases, databases, and databases. data including information about materials (eg factors, types or properties of materials), component sizes (eg diameters, lengths, etc.), friction factors or a variable described elsewhere right here. Of course, any data or data from a particular source may be considered for a particular application of an embodiment, in whole or in part, separately or in combination, and in at least some embodiments, may be used to obtain other information that may not be immediately available in a particular form or format. For example, if the desired training is not explicitly included in a source database, this information can be determined from other information in at least some cases. FIG. 6 illustrates an exemplary system 600 that can be used to perform the entire well fracturing design and modeling process described herein or a portion thereof. The exemplary system 600 may be a conventional workstation, desktop, or laptop, or it may be a custom computing system 600 developed for a particular application. In a typical arrangement, system 600 includes a bus 602 or other communication path for transferring information among other components within system 600, and a central unit 604 coupled to bus 602 for information processing. The system 600 may also include a main memory 606, such as random access memory (RAM) or other dynamic storage device coupled to the bus 602 for recording computer readable instructions to be executed by the computer. CPU 604. Main memory 606 may also be used to store temporary variables or other intermediate information when instructions are executed by CPU 604. [0053] System 600 may further include a read-only memory. (ROM) 608 or other static recording device coupled to the bus 602 for storing static information and instructions for the CPU 604. A computer readable storage device 610, such as a non-volatile memory disk (eg Flash memory) or magnetic disk, can be coupled to bus 602 for information and instruction recording for CPU 604. The unit Central 604 can also be coupled by bus 602 to a display 612 to display information for a user. At least one input device 614, including alphanumeric and other keyboards, a mouse, a trackball, cursor direction keys, and so on, may be coupled to the bus 602 to communicate information and control selections. to the central unit 604. A communication interface 616 may be provided to allow the horizontal well design system 600 to communicate with a system or with an external network. [0054] According to the exemplary embodiments, at least one hydraulic fracturing modeling application 618 or the computer readable instructions relating thereto may reside on the recording device 610 or be downloaded there for execution. In general, the at least one application 618 is or contains at least one computer program that can be executed by the CPU 604 and / or other components to allow users to perform part of the design process. and hydraulic fracturing modeling described here or as a whole. These applications 618 may be implemented in any appropriate computer programming language or in a software development package known to those of ordinary experience, including various versions of C, C ++, FORTRAN, and the like. 10055] Accordingly, as already indicated, the embodiments disclosed herein can be implemented in a number of ways. In general, in one aspect, the exemplary embodiments include a computer implemented method of designing a hydraulic fracturing operation for a hydrocarbon reservoir. The method comprises defining an anisotropy of a formation material present in the reservoir, defining a heterogeneity of a formation material in the reservoir and creating, in a computer-readable memory, a electronically recorded geomechanical model of at least part of the reservoir based on at least anisotropy and heterogeneity, the geomechanical model giving a prediction of at least one of a pore pressure and in situ constraints within of the tank part. The method also includes defining a borehole track in the geomechanical model through the portion of the reservoir, and identifying an estimated hydraulic fracturing geometry of the portion of the reservoir at a first and a second fracturing location along the wellbore track, the estimated hydraulic fracturing geometry being based on at least one of a geoconstraint and a mechanical property of formation material existing at the level of the first and second fracking locations. The method further comprises creating, in the computer-readable memory, an electronically recorded fracturing geometry model of the estimated hydraulic fracturing geometry at the first and second fracturing locations, estimating a first reservoir volume stimulated from the tank portion and adding in the electronically recorded fracturing geometry model an estimated hydraulic fracturing geometry at a third fracturing location along the well bore pathway between the first and second fracking locations. The method further comprises calculating a manipulated stress anisotropy of the reservoir portion based on the addition of the estimated hydraulic fracturing geometry at the third fracturing location, estimating a second volume of stimulated reservoir of the reservoir part; and calculating a difference between the first boosted reservoir volume and the second boosted reservoir volume. In some embodiments, the method may further comprise any of the following characteristics individually or in a preferred embodiment. at least two of these features in combination, comprising: the iterative variation of at least one variable within the fracturing geometry model, the recalculation of the manipulated anisotropy of stress and the estimation of a third volume stimulated tank of the tank part; selecting the at least one variable in the set consisting of a well interval, a gap between perforations, an order of perforations and a combination thereof; performing a numerical stress analysis of a reservoir gap between the first and second fracking locations; the third fracturing location is disposed in a reservoir gap and located in a first puncture interval from the first fracturing location and a second puncture interval from the second fracturing location, and the method further comprising determining a variation of the stress in at least one direction in the reservoir gap; determining a variation of a process pressure as a function of the stress variation; determining a likelihood that hydraulic fracturing at the third fracturing location could cause fractures of increased complexity in the reservoir gap between the first and second fracture locations; determining the manipulated horizontal stress anisotropy (HSAI *) of the reservoir interval versus the first and second puncture intervals, the HSAI * being determined according to the following equation: '= (SH-K Sl ) ") / (Sh *); determining a plurality of values of I-ISAI * as a function of a plurality of different values for at least one of the first and second perforation intervals; identifying a position of the third Fracturing location along the reservoir gap where a target HSAI * value exists; determination of a vertical manipulated stress anisotropy (VSAI *) of the reservoir gap, the VSAI * being determined according to the the following equation: VSAI 1 (Sv-Sh IA *) / (Sh *); and identifying a position of the third fracturing location along the reservoir interval where a target VSAI * value exists. [0057] In general, in one aspect, the examples of Embodiments include a computer system for designing a hydraulic fracturing operation for a hydrocarbon reservoir. The computer system includes a central unit mounted in the computer system, a data input unit connected to the central unit, the data input unit receiving fracability data relating to the hydrocarbon reservoir, a database connected to the central unit, the database storing the fracability data for the hydrocarbon reservoir, and a storage device connected to the central unit, the storage device storing computer readable instructions in his breast. The computer readable instructions are executable by the CPU to perform the method of designing a hydraulic fracturing operation for a hydrocarbon reservoir as described in substance above. In general, in still another aspect, the exemplary embodiments include a computer readable medium storing computer readable instructions for causing a computer to design a hydraulic fracturing operation for a hydrocarbon reservoir. The computer readable instructions include instructions for causing the computer to perform the method of designing a hydraulic fracturing operation for a hydrocarbon reservoir as described in substance above. The role of the systems and methods of the present disclosure may be continuous throughout the life of an unconventional reservoir or the like, and may be investigated during the exploration phases. , well planning and development, such as during the optimization of a multistage hydraulic fracturing design. The systems and methods disclosed herein can improve production and reduce costs by limiting learning curves associated with at least one formation, such as an emerging resource shale and tight games. Other embodiments utilizing one or more aspect (s) of the systems and methods described above may be designed while remaining within the scope of the present disclosure. For example, the systems and methods disclosed herein may be used alone or to form at least a portion of another modeling, simulation, or other system of analysis. In addition, the various methods and embodiments of the workflow system may be included in combination with each other to produce variants of disclosed methods and embodiments. A discussion of singular elements may include several elements and vice versa. References to at least one article followed by a reference to the article may include at least one of the following. Also, various aspects of the embodiments may be used in conjunction with each other. Except where the context otherwise requires, the verb "to understand" and its conjugated forms such as "includes", "understand" or "including" must be understood to mean the inclusion of at least the element or stage or the group of elements or steps indicated or their equivalents, and not the exclusion of a superior numerical quantity or any other element or step or group of elements or steps or equivalents thereof. this. The order of the following steps may occur according to a number of sequences, unless otherwise specific. The various steps described herein may combine with other steps, intermingle with the steps indicated, and / or divide into multiple steps. Likewise, elements have been functionally described and can be implemented as separate components or can be combined into multi-function components. Those skilled in the art will understand that one or more embodiments of the present disclosure may be implemented as a method, a data processing system or a computer program product. Accordingly, at least one embodiment may take the form of a fully hardware embodiment, a fully software embodiment, or an embodiment combining software and hardware aspects. In addition, at least one embodiment may be a computer program product on a recording medium usable by a computer having a computer readable program code on the medium.

Any suitable computer-readable medium may be used, including, but not limited to, static and dynamic storage devices, hard disks, optical recording devices, and magnetic recording devices. At least one embodiment may be described herein with reference to flow chart illustrations of methods, systems and computer program products in accordance with the disclosure. It will be understood that each block of a flow chart illustration and block combinations in the flowchart illustrations can be implemented by computer program instructions. These computer program instructions may be provided to a general purpose computer processor, a special computer or other programmable data processing apparatus for producing a machine, such that the instructions which may be executed by a processor of a computer or other programmable data processing apparatus may implement the functions specified in the block or blocks of the flowchart, separately or in combination, in whole or in part. [0062] The computer program instructions may be stored in a computer readable memory capable of directing a computer or other programmable data processing apparatus to function in a particular manner, so that the instructions stored in the readable memory by computer cause an article of manufacture including instructions that can implement the function (s) specified in the block or in the blocks of the flowchart. The computer program instructions may be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process. so that the instructions that run on the computer or other programmable devices produce the steps of implementing the functions specified in the block or in the blocks of the flowchart. While the disclosed embodiments have been described with reference to one or more particular embodiments, it will be apparent to those skilled in the art that many changes can be made to them while remaining within the scope of the present disclosure. and that obvious modifications and changes in the described embodiments are possible. Therefore, each of these embodiments and their obvious variations is intended to be included in the scope of the present disclosure and this patent application intends to fully protect all of those modifications and improvements that come within the scope of the present disclosure. (the equivalents being duly taken into account in the assessment of the latter) of the following claims.

Claims (20)

REVENDICATIONS1. A computer-implemented method, characterized in that the method allows the design of a hydraulic fracturing operation for a hydrocarbon reservoir (20), and in that it comprises: defining an anisotropy of a formation material in the tank (20); defining a heterogeneity of a formation material in the reservoir (20); creating, in a computer-readable memory (610) (600), an electronically recorded geomechanical model of at least a portion of the reservoir (20) based on at least anisotropy and heterogeneity, the geomechanical model giving predicting at least one of a pore pressure and in situ stress within the portion of the reservoir (20); defining a well bore (10) in the geomechanical model through the portion of the reservoir (20); identifying an estimated hydraulic fracturing geometry of the portion of the reservoir (20) at a first and a second fracturing location along the well bore path (10), the fracturing geometry hydraulic system being based on at least one of a geoconstraint and a mechanical property of formation material existing at the first and second fracturing locations; creating, in the computer-readable memory (610) (600), an electronically recorded fracturing geometry model of the estimated hydraulic fracturing geometry at the first and second fracturing locations; estimating a first stimulated reservoir volume of the reservoir portion (20); adding to the electronically recorded fracturing geometry model an estimated hydraulic fracturing geometry at a third fracturing location along the well bore pathway (10) between the first and second fracturing locations ; calculating a manipulated stress anisotropy of the reservoir portion (20) based on the addition of the estimated hydraulic fracturing geometry at the third fracture location; Estimating a second stimulated reservoir volume of the reservoir portion (20); and calculating a difference between the first stimulated reservoir volume and the second stimulated reservoir volume. The method of claim 1, further comprising the iterative variation of at least one variable within the fracturing geometry model, the recalculation of the manipulated stress anisotropy, and the estimation of a third reservoir volume. stimulated from the portion of the reservoir (20). The method of claim 2, wherein said at least one variable is selected from the group consisting of a well interval, a gap between perforations, an order of perforations and combinations thereof. 15 The method of any one of claims 1 to 3, further comprising performing a stress analysis of a reservoir gap between the first and second fracturing locations. The method of any one of claims 1 to 4, wherein the third fracturing location is disposed in a reservoir gap and located in a first perforation interval from the first fracturing location and a second perforation interval. from the second perforation location, and the method further comprises determining a stress variation in at least one direction within the reservoir gap. 25 The method of claim 5, further comprising determining a variation in a process pressure as a function of the stress variation. The method of claim 5 or 6, further comprising determining a likelihood that hydraulic fracturing at the third fracturing location will result in fractures of increased complexity in the reservoir gap between the first and second locations. fracturing. 5 10 3035674 34 The method of any one of claims 5 to 7, further comprising determining a manipulated horizontal stress anisotropy (HSAI *) of the reservoir gap as a function of the first and second perforation intervals, the HSAI " - SH -Sit- HSAI * being determined according to the following equation: Sh s, where SH is a maximum horizontal stress and Sh * is a minimally manipulated horizontal stress. The method of claim 8, further comprising determining a plurality of HSAI * based on a plurality of different values for at least one of the first puncture interval and the second puncture interval. The method of claim 8 or 9, further comprising identifying a position of the third fracturing location along the reservoir interval where a target HSAI * value exists. 15 The method according to any one of claims 5 to 10, further comprising determining a manipulated vertical stress anisotropy (VSAI *) of the tank Sv - interval, the VSAI * being determined according to the following equation : VS-241 * = Sh *, where Sv is a vertical overload constraint and Sh * is a minimally manipulated horizontal stress. The method of claim 11, further comprising identifying a position of the third fracturing location along the reservoir gap where a target VSAI * value exists. 25 13. Computer system, characterized in that it allows the design of a hydraulic fracturing operation for a tank (20) of hydrocarbons, and in that the computer system comprises: a central unit (604) mounted in the system computer science ; A data input unit (614) connected to the central unit (604), the data input unit receiving fracability data relating to the hydrocarbon reservoir (20); a database connected to the central unit (604), the database storing the fracability data for the hydrocarbon reservoir (20); and a storage device (610) connected to the central unit (604), the storage device (610) storing computer readable instructions therein, the computer readable instructions being executable by the central unit (604) to: define anisotropy of a formation material in the reservoir (20); Defining a heterogeneity of a formation material in the reservoir (20); creating a geomechanical model of at least a portion of the reservoir (20) based on at least anisotropy and heterogeneity, the geomechanical model providing a prediction of at least one of a pore pressure and stress in located within the portion of the tank (20); and defining a well bore (10) in the geomechanical model through the portion of the reservoir (20). The computer system of claim 13, wherein the computer readable instructions further cause the CPU (604) to identify an estimated hydraulic fracturing geometry of the tank portion (20) at a first and a second fracturing location along the wellbore track (10), the estimated hydraulic fracturing geometry being based on at least one of a geoconstraint and a mechanical property of formation material existing at the level of the first and second fracking locations. 25 The computer system of claim 14, wherein the computer readable instructions further cause the CPU (604) to: create an electronically recorded fracturing geometry model of the estimated first and second hydraulic fracturing geometry 30 fracking sites; estimating a first volume of stimulated reservoir of the portion of the reservoir (20); and adding in the electronically recorded fracturing geometry model an estimated hydraulic fracturing geometry at a third fracturing location along the well bore pathway (10) between the first and second fracturing locations. 5 The computer system of claim 15, wherein the computer readable instructions further cause the CPU (604) to: calculate a manipulated constraint anisotropy of the tank portion (20) based on adding geometry estimated hydraulic fracturing at the third fracture location; estimating a second volume of stimulated reservoir of the portion of the reservoir (20); and calculating a difference between the first stimulated reservoir volume and the second stimulated reservoir volume. 15 Computer-readable medium, characterized in that the medium stores computer-readable instructions for causing a computer (600) to design a hydraulic fracturing operation for a hydrocarbon reservoir (20), the computer-readable instructions comprising instructions which, when executed by a processor, cause the computer (600) to: define an anisotropy of a formation material in the reservoir (20); defining a heterogeneity of a formation material in the reservoir (20); creating a geomechanical model of at least a portion of the reservoir (20) based on at least anisotropy and heterogeneity, the geomechanical model providing a prediction of at least one of a pore pressure and stress in located within the portion of the reservoir (20); and defining a well bore (10) in the geomechanical model through the portion of the reservoir (20). 3035674 37 The computer-readable medium of claim 17, wherein the computer-readable instructions further cause the computer (600) to identify an estimated hydraulic fracturing geometry of the portion of the reservoir (20) at a first and a second fracturing location along the well bore path (10), the estimated hydraulic fracturing geometry being based on at least one of a geoconstraint and a mechanical property of existing formation material at the first and second fracking locations. The computer readable medium of claim 18, wherein the computer readable instructions further cause the computer (600) to: create an electronically recorded fracturing geometry model of the estimated hydraulic fracturing geometry at the first and second fracking locations; estimating a first volume of stimulated reservoir of the portion of the reservoir (20); and adding to the electronically recorded fracturing geometry model an estimated hydraulic fracturing geometry at a third fracturing location along the wellbore track (10) between the first and second fracturing locations. 20 The computer-readable medium of claim 19, wherein the computer-readable instructions further cause the computer (600) to: calculate a manipulated strain anisotropy of the portion of the reservoir (20) based on the addition of the hydraulic fracturing geometry estimated at the third fracturing location; Estimating a second volume of stimulated reservoir of the portion of the reservoir (20); and calculating a difference between the first stimulated reservoir volume and the second stimulated reservoir volume.