Use of wireline logging to evaluate rock properties and fractures in geothermal wells

Abstract

Methods, systems, and computer readable storage mediums for managing completion of a well for geothermal energy extraction is disclosed. The method may include obtaining a plurality of measurements of a geological formation in which a wellbore of the well is positioned. The method may also include, for each measurement of the plurality of measurements, obtaining a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation. The method may further include defining at least one zone along the wellbore based on the fluid flow analysis results. The method may also include ranking the at least one zone based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone. The method may additionally include obtaining a formation model for the geological formation using the at least one ranked zone a thermal properties of the geological formation.

Description

USE OF WIRELINE LOGGING TO EVALUATE ROCK PROPERTIES AND FRACTURES IN GEOTHERMAL WELLSCROSS-REFERENCE TO RELATED APPLICATION

[0001] This application claims the benefit of U.S. Provisional Application No. 63 / 612,606 filed December 20, 2023.BACKGROUND

[0002] Geological formations may host a range of resources. For example, geological formations may include trapped liquids and / or gasses that may include hydrocarbons of various types. These hydrocarbons may be used for a variety of purposes.

[0003] In additional to physical resources such as gasses or fluids, the geological formations may also include geothermal reservoirs. A geothermal reservoir may be part of a geological formation which may be heated due to various geological processes. The heat from a geothermal reservoir may be used for a variety of purposes including, for example, geothermal heating and energy production.SUMMARY

[0004] A summary of certain embodiments disclosed herein is set forth below. It should be understood that these aspects are presented merely to provide the reader with a brief summary of these certain embodiments and that these aspects are not intended to limit the scope of this disclosure. Indeed, this disclosure may encompass a variety of aspects that may not be set forth below.

[0005] In an aspect, a method for managing completion of a well for geothermal energy extraction is disclosed. The method may include obtaining a plurality of measurements of a geological formation in which a wellbore of the well is positioned; for each measurement ofthe plurality of measurements, obtaining a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation; defining at least one zone along the wellbore based on the fluid flow analysis results; ranking the at least one zone based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone; and obtaining a formation model for the geological formation using the at least one ranked zone and thermal properties of the geological formation.

[0006] The ranking system may define a numerical score for the at least one zone based on the fluid flow analysis results. A first portion of the fluid flow analysis results may indicate whether at least one portion of the geological formation in the at least one zone is likely to support fluid flow. A second portion of the fluid flow analysis results may indicate whether stress in the at least one portion of the geological formation is favorable for opening fractures in the at least one portion of the geological formation or is favorable for closing factures in the at least one portion of the geological formation.

[0007] The numerical score may include a cardinality the first portion of the fluid flow analysis results that indicate that the at least one zone is likely to support fluid flow. The numerical score may also include a summation of the cardinality and a value for the second portion of the fluid flow analysis results that depends on whether the stress in the at least one portion of the geological formation is favorable for opening fractures in the at least one portion of the geological formation. The value may increase the numerical score when the summation of the cardinality is greater than zero, and may not increase the numerical score when the summation of the cardinality is not greater than zero.

[0008] The formation model may associate thermal properties of portions of the geological formation with corresponding likelihoods of the portions of the geological formation supporting fluid flow. The formation model may not indicate magnitudes of fluid permeabilities of the portions of the geological formation.

[0009] The formation model may be obtained by generating a graphical user interface. The graphical user interface may display, with respect to position along the well: each of the plurality of measurements; indicators for positions of the at least one ranked one zone; and indicators for different ranks of the at least one ranked zone.

[0010] The graphic user interface may further display, with respect to the position along the well: thermal properties of the geological formation. The thermal properties may include at least one selected from a group of thermal properties consisting of: thermal conductivity; thermal capacity; and thermal diffusivity.

[0011] The fluid flow analysis result for each measurement of the plurality of measurements may indicates portions of the geological formation that are likely to support fluid flow.

[0012] At least one zone along the wellbore may be defined based on the fluid flow analysis results by identifying a portion of the geological formation indicated by a fluid flow analysis result of the fluid flow analysis results as likely supporting fluid flow; identifying whether any of the fluid flow analysis results other than the fluid flow analysis results indicates that the portion of the geological formation is likely to support fluid flow; in an instance of the identifying wherein a second fluid flow analysis result of the fluid flow analysis results indicates that the portion of the geological formation is likely to support fluid flow: defining a zone of the at least one zone to comprise the portion of the geological formation and a second portion of the geological formation indicated by the second fluid flow analysis result.

[0013] Each of the fluid flow analysis results may indicate whether the portion of the geological formation is likely to support fluid flow, and each of the plurality of measurements may characterize properties of the geological formation via different types of measurements.

[0014] The method may also include obtaining a well completion plan using, at least, the formation model; completing the well using a well completion plan to obtain a completed well; and obtaining an energy product using geothermal energy from the completed well.

[0015] In an aspect, a non-transitory machine-readable medium having instructions stored therein, which when executed by a processor, cause the processor to perform operations for managing completion of a well for geothermal energy extraction is disclosed. The operations may cause the method, as discussed above, to be performed.

[0016] In an aspect, a data processing system is provided. The data processing system may include a processor; and a memory coupled to the processor to store instructions, which when executed by the processor, cause the processor to perform operations for managing completion of a well for geothermal energy extraction. The operations may cause the method, as discussed above, to be performed.

[0017] Various refinements of the features noted above may be undertaken in relation to various aspects of the present disclosure. Further features may also be incorporated in these various aspects as well. These refinements and additional features may exist individually or in any combination. For instance, various features discussed below in relation to one or more of the illustrated embodiments may be incorporated into any of the above-described aspects of the present disclosure alone or in any combination. The brief summary presented above is intended only to familiarize the reader with certain aspects and contexts of embodiments of the present disclosure without limitation to the claimed subject matter.BRIEF DESCRIPTION OF THE DRAWINGS

[0018] Embodiments disclosed herein are illustrated by way of example and not limitation in the figures of the accompanying drawings in which like references indicate similar elements.

[0019] FIG. 1A shows a diagram illustrating a first system in accordance with an embodiment.

[0020] FIG. IB shows a block shows a diagram illustrating a second system in accordance with an embodiment.

[0021] FIGs. 2A-2D show data flow diagrams in accordance with an embodiment.

[0022] FIG. 2E shows a diagram illustrating information used in ranking of zones in accordance with an embodiment.

[0023] FIGs. 2F-2G show data flow diagrams in accordance with an embodiment.

[0024] FIG. 2H shows a diagram illustrating information in a formation model in accordance with an embodiment.

[0025] FIG. 21 shows a diagram illustrating an example interface populated with information in a formation model in accordance with an embodiment.

[0026] FIG. 3 shows a flow diagram illustrating a method in accordance with an embodiment.

[0027] FIG. 4 shows a block diagram illustrating a data processing system in accordance with an embodiment.DETAILED DESCRIPTION

[0028] Various embodiments will be described with reference to details discussed below, and the accompanying drawings will illustrate the various embodiments. The following description and drawings are illustrative and are not to be construed as limiting. Numerous specific details are described to provide a thorough understanding of various embodiments. However, in certain instances, well-known or conventional details are not described in order to provide a concise discussion of embodiments disclosed herein.

[0029] Reference in the specification to “one embodiment” or “an embodiment” means that a particular feature, structure, or characteristic described in conjunction with the embodiment can be included in at least one embodiment. The appearances of the phrases “inone embodiment” and “an embodiment” in various places in the specification do not necessarily all refer to the same embodiment.

[0030] Exploitation of geothermal resources enables electricity and other valuable products to be generated in an economical and environmentally friendly manner. To generate electricity using geothermal resources, a top side power facility may be deployed.

[0031] Turning to FIG. 1 A, a diagram of a top side power facility deployed to geological formation 100 in accordance with an embodiment is shown. The top side power facility may generate electricity by extracting heat from geological formation 100.

[0032] For example, geological formation 100 may include any number of layers 101 (e.g., sedimentary layers, hot rock layers, etc.). Ongoing geological processes near and / or in geological formation 100 may generate geothermal reservoir 102. Geothermal reservoir 102 may be a portion of geological formation 100 that tends to remain at elevated temperature due to the ongoing geological processes.

[0033] To use the heat to generate the electricity, the top side power facility may include heat exchanger 110, generator 112, and cooling system 114. The top side power facility may include additional, different, or / or fewer components without departing from embodiments disclosed herein.

[0034] Heat exchanger 110 may use heat extracted from geothermal reservoir 102 to warm a fluid used to drive generator 112. Cooling system 114 may cool the warm fluid to establish a fluid loop (e.g., the cooled fluid may be returned to heat exchanger 110 to be heated again).

[0035] To obtain the heat used by heat exchanger 110 to warm the fluid used to drive generator 112, a second fluid may be injected into geothermal reservoir 102 and extracted from geothermal reservoir via production well 120. The second fluid may be warmed by geothermal reservoir after being injected and prior to be extracted.

[0036] Thus, the top side power facility and associated wells may establish two fluid loops, one that runs through geothermal reservoir 102 and another that runs between heat exchanger 110, generator 112, and cooling system 114.

[0037] The amount of electricity that the top side power facility may produce may depend on (i) the rate of heating of the second fluid after injection into and prior to extraction from geothermal reservoir 102, (ii) the flow rate of the second fluid through geothermal reservoir 102 which may be hampered by the structure and permeability of the geothermal reservoir 102, and / or (iii) other factors that may also be impacted by how the wells (e.g., 120, 122) are completed. For example, higher rates of heating and larger flow rates of the second fluid may provide for higher rates of electricity production (e g., an example of an energy product, any product or service provided using heat extracted from a thermal reservoir may be an energy product) by the top side power facility. These characteristics of the system may be impacted by the well completions.

[0038] The rate of heating by geothermal reservoir 102 and flow rate of the second fluid through geothermal reservoir 102 may depend on geological rock properties of the formation such as, for example, the thermal properties of the rock that makes up geothermal reservoir 102 and presence of fractures 104 or other geological structures (e.g., the “fracture properties”) in the rock that makes up geothermal reservoir 102 that allow for fluid flow interconnecting injection well 122 and production well 120. Thus, the manner in which the wells are completed (e.g., where the wells interact with geothermal reservoir 102) may directly impact the rate and temperature of heated fluids produced using the wells.

[0039] In general, embodiments disclosed herein relate to methods and systems for completing wells, providing information to aid in the modeling of geothermal reservoirs and to aid in the planning for the placement of possible future wells. To complete the wells and provide additional information on the geothermal reservoir, after wellbores are drilled, the wellbores may be characterized with respect to (i) a likelihood of facilitating fluid flowthrough geothermal reservoir 102, and (ii) thermal properties of the rock (and / or other materials) forming geothermal reservoir 102.

[0040] During characterization with respect to likelihood of facilitating fluid flow, multiple tools may be used. The tools may operate on various physical principles (e.g., sonic, resistance, spectroscopic), and thus may each provide data usable to infer the local geologic rock properties of geothermal reservoir 102 with different degrees of accuracy depending on a variety factors (e.g., the data obtained from each measurement may be usable to infer the local properties of the geothermal reservoir but that rely on a corresponding set of assumptions which may or may not be true).

[0041] To increase the likelihood of completing the well and exploiting the geothermal reservoir in a manner with desirable levels of fluid flow, the data obtained from each of the measurements may be used to define and rank different zones (e.g., ranges of depth) of the wells with respect to the likelihood of being able to provide for fluid flow through geothermal reservoir 102. These ranked zones may be used in combination with thermal properties of the rock (corresponding to each of the ranked zones) of geothermal reservoir 102 to define a completion plan for the wells and / or an exploitation plan for the geothermal reservoir. The completion plan may be established to facilitate fluid flow between the well and geological formation 100 at locations along the wellbore where (i) there is a higher likelihood of the presence of sufficient fractures to facilitate fluid flow through geological formation 100 and geological formation 100 and (ii) geological formation 100 comprises rock with thermal properties that are conducive to heating of fluids.

[0042] Once the completion plan is obtained, the completion plan may be used to guide completion of the well. The resulting well, by virtue of its design being based on the completion plan, may be able more likely to produce desirable quantities of heated fluids usable in various processes such as electricity generation.

[0043] While illustrated in FIG. 1A as including multiple fluid loops, the topology of the top size power station and corresponding wells may be different without departing from embodiments disclosed herein.

[0044] To obtain completion plans, a modeling system in accordance with an embodiment may be used.

[0045] Turning to FIG. IB, a block diagram of a modeling system in accordance with an embodiment is shown. The modeling system may be used to establish completion plans for wells.

[0046] To provide the above noted functionality, the modeling system of FIG. IB may include planning system 130, analysis system 140, and communication system 150. Each of these components is discussed below.

[0047] Planning system 130 may facilitate completion planning for wells. To do so, planning system 130 may gather and provide information regarding a not-yet-completed well to analysis system 140. The information may have been obtained using a variety of downhole tools such as a micro-imager (e.g., measures resistivity along the wellbore), sonic tools (e.g., acoustic or other sounds based measurements), spectroscopic tools (e.g., measurements based on nuclear properties), and / or other types of downhole tools.

[0048] Based on the provided data, analysis system 140 may return the thermal properties of the rock forming the geological formation in which the wellbore is positioned as well as the ranked zones. Planning system 130 may use this information to define a completion plan, and / or manage completion of a well based on the completion plan.

[0049] For example, planning system 130 may use the ranked zones and rock properties to define a topology of the completed well. The topology may be defined in an automated manner (e.g., automatic selection of where the well will interact with the geologic formation), semi-automated (e.g., suggest where the well will interact with the geologic formation, allow a subject matter expert to confirm / reject / modify the suggestion), and / or manual manner (e.g.,allow the subject matter expert to review and use the information to define the completion plan.

[0050] To provide its functionality, planning system 130 may include any number of endpoint devices 132-134. The endpoint devices may include various types of computing devices used by personnel working on completion of the wells.

[0051] Analysis system 140 may analyze the data provided by planning system 130 to identify ranked zones and rock properties. Once obtained, the ranked zones and rock properties may be used to obtain various graphical user interfaces (and / or other types of interfaces) usable by automated systems and / or subject matter experts to identify more promising locations along a wellbore with respect to heated fluid production. The graphical user interfaces and / or underlying data may be provided to planning system 130. Refer to FIGs. 2A-2H for additional details regarding ranked zones and information provided by analysis system 140 to planning system 130.

[0052] When providing their functionality, any of (and / or components thereof) planning system 130 and analysis system 140 may perform all, or a portion, of the actions and methods illustrated in FIGs. 2A-3.

[0053] Any of (and / or components thereof) planning system 130 and analysis system 140 may be implemented using a computing device (also referred to as a data processing system) such as a host or a server, a personal computer (e.g., desktops, laptops, and tablets), a “thin” client, a personal digital assistant (PDA), a Web enabled appliance, a mobile phone (e.g., Smartphone), an embedded system, local controllers, an edge node, and / or any other type of data processing device or system. For additional details regarding computing devices, refer to FIG. 4.

[0054] Any of the components illustrated in FIG. IB may be operably connected to each other (and / or components not illustrated) with communication system 150. In an embodiment, communication system 150 includes one or more networks that facilitatecommunication between any number of components. The networks may include wired networks and / or wireless networks (e.g., and / or the Internet). The networks may operate in accordance with any number and types of communication protocols (e.g., such as the internet protocol).

[0055] While illustrated in FIG. IB as including a limited number of specific components, a system in accordance with an embodiment may include fewer, additional, and / or different components than those illustrated therein.

[0056] To further clarify embodiments disclosed herein, data flow diagrams in accordance with an embodiment are shown in FIGs. 2A-2D and 2F-2G. In these diagrams, flows of data and processing of data are illustrated using different sets of shapes. A first set of shapes (e.g., 200, 206, etc.) is used to represent data structures, a second set of shapes (e.g., 202, 222, 224, etc.) is used to represent processes performed using and / or that generate data, and a third set of shapes (e.g., 204, 226, etc.) is used to represent large scale data structures such as databases. Additionally, as part of the flows of data, various data processing operations may be performed. FIGs. 2E, 2H, and 21 show diagrams illustrating examples of and / or results of the data processing operations in accordance with an embodiment.

[0057] Turning to FIG. 2A, a first data flow diagram in accordance with an embodiment is shown. The first data flow diagram may illustrate data used in and data processing performed in preparing measurements of a geological formation for analysis.

[0058] To prepare the measurements for analysis, conditioning process 202 may be performed. During conditioning process 202, measurement data 200 may be analyzed to (i) remove artifacts (and / or otherwise place it in a form for subsequent analysis) and / or (ii) establish criteria 208. The resulting conditioned measurement data 206 may be in a form compatible with various analysis algorithms.

[0059] During conditioning process 202, information from conditioning repository 204 maybe utilized. For example, conditioning repository 204 may include information regardingrequired forms of data compatible with analysis algorithms, anomaly detection information usable to remove portions of measurement data 200 that is likely to be inaccurate (e.g., due to a measurement error or violation of an assumption regarding the measurement processes used to obtain measurement data 200), and / or other information usable to place measurement data 200 in a form that is more likely to be able to be successfully analyzed.

[0060] Criteria 208 may include thresholds and / or other types of criteria usable to customize subsequently performed analysis processes based on measurement data 200. For example, any of the analysis algorithms used to analyze conditioned measurement data 206 may do so by identifying certain signals, patterns, and / or other characteristics of conditioned structural measurement data 206 as indications of the presence of certain structural features in a geological formation along a wellbore characterized by measurement data 200. Criteria 208 may be used to customize a magnitude of the signals, patterns, etc. in conditioned measurement data 206 for an analysis algorithm to determine that a corresponding fracture property is present in the geological formation. For example, criteria 208 may be used to define when conditioned measurement data 206 indicates that the geological formation is fractured in a manner that is likely to support fluid flow. Consequently, criteria 208 may be used to customize subsequently performed analysis to the measurements that were performed on the well to obtain measurement data 200.

[0061] Criteria 208 may be obtained in an automated or manual fashion. If obtained in a automated manner, a cumulative distribution function may be used to identify a signal level, pattern density, and / or other characteristics of conditioned measurement data 206 to define the criteria. For example, the cumulative distribution function may be used to analyze the measurements (e.g., sorting) to identify a top percentile (e.g., top 90%, top 95%, top 98%) of the measurement along the wellbore. Thus, when subsequently used, criteria 208 may be used to define a signal level or other criteria sufficient to indicate present of a particular geological feature such as presence of fractures that are likely to support fluid flow, presence of criticallystressed fractures, etc. If obtained in a manual manner, a user or other person may provide user input indicating values for various criteria. Criteria 208 may include, for example, any number of thresholds corresponding to any number of different measurements included in measurement data 200.

[0062] Measurement data 200 may include multiple measurements by multiple tools. Each measurement may be a continuous or discrete characterization of the geological formation along the wellbore. For example, a measurement may be made by moving a tool along the wellbore (e.g., from the surface down through the layers of the geological formation). During the movement, the tool may utilize various stimuli (e.g., electric, sonic, nuclear) to excite a response from the geological formation. The response to the stimulation by the tool may be measured. Accordingly, any of the measurements may characterize the geological formation along all, or a portion, the wellbore.

[0063] The measurements may indicate whether (i) fractures are present in the geological formation along the wellbore that are likely to support fluid flow, and (ii) whether forces in the geological formation are likely to open or close the fractures in the geological formation along the wellbore. As will be discussed below, these pieces of information regarding the geological formation may be used to guide completion of the well.

[0064] With respect to identifying fractures, for example, a micro-imaging tool may stimulate the geological formation using electrical current to count the number of fractures in the geological formation and estimate sizes of apertures in the geological formation as a function of position along the wellbore. In another example, sonic tools (e.g., to generate dipole sonic logs) may stimulate the geological formation using sound waves to measure the shear wave anisotropy and attenuation of the geological formation. In a further example, sonic tools (e.g., to generate monopole sonic logs) may stimulate the geological formation using sound waves to measure Stoneley wave transmissivity and reflectivity of the geological formation.

[0065] With respect to identifying forces in the geological formation that are likely to open or close factures, for example, micro-imaging tool collected data may be subsequently processing to estimate whether stresses in the geological formation are likely to place any identified fractures under critical stress. Fractures under critical stress may be more likely to stay open. Because geothermal reservoirs may be geologically active, information regarding the current fracture properties of the geological formation may provide an incomplete picture regarding how well different portions of the geological formation are likely to be usable for heated fluid production. By characterizing and using information regarding stresses and / or other characteristics of the geological formation that indicate whether existing fractures are likely to remain open or to close, various portions of the geological formation may be selected that are likely to be useful for heated fluid production.

[0066] Turning to FIG. 2B, a second data flow diagram in accordance with an embodiment is shown. The second data flow diagram may illustrate data used in and data processing performed in analyzing conditioned measurement data 206 to obtain fluid flow analysis results 230 .

[0067] To analyze conditioned measurement data 206, test logs 210 for different measurements performed on the geological formation may be divided for subsequent analysis. Any number (e.g., 212 214) of test logs may be obtained. The obtained test logs may, as discussed with respect to FIG. 2A, be conditioned to remove artifacts and otherwise prepare the test log for analysis using a corresponding analysis process.

[0068] A portion (e.g., multiple) of the test logs may be usable to obtain analysis results for a similar quantity (e.g., presence of fractures likely to support fluid flow). For example, multiple test logs may include information regarding a same portion of the geological formation that may be used to independently infer whether the portion of the geological formation is or is not likely to support fluid flow (e.g., sufficient for heated fluid production). In another example, multiple test logs may include information regarding a same portion ofthe geological formation that may be used to independently infer whether the portion of the geological formation is under stress that is likely to open or close factures, if present.

[0069] Once test logs 210 are obtained, analysis process 220 may be performed. During analysis processes 220, corresponding analysis processes (e.g., 222-224) may be performed to analyze a corresponding test log. The analysis processes may be based on analysis algorithms included in analysis tools repository 226.

[0070] Thresholds (and / or other information) from criteria 208 may be used to customize the algorithms from analysis tools repository 226 on which each corresponding analysis process (e.g., 222, 224) is based. For example, criteria 208 may be used to modify detection threshold levels of each corresponding analysis process. Accordingly, the corresponding analysis processes may be, in part, calibrated to the measurements made on the geological formation (e.g., rather than using static detection thresholds).

[0071] Through performance of analysis processes 220, fluid flow analysis results 230 may be obtained. Any number of fluid flow results (e.g., 232, 234) may be obtained. While illustrated in FIG. 2B as including a same number of fluid flow analysis results as are corresponding processes, it will be appreciated that the number may differ (e.g., an analysis process may generate multiple fluid flow results).

[0072] Each fluid flow analysis results 230 may indicate whether (i) various portions of the geological formation are likely or unlikely to support fluid flow usable for heated fluid production, (ii) the portions of the geological formation are likely or unlikely to support fluid flow in the future (e.g., due to stresses), and / or (iii) other information regarding the various portions of the geological formation usable to identify portions of the geological formation that may be suited for heated fluid production for various uses.

[0073] For example, fluid flow analysis results 232 may indicate, as a function of position along the wellbore, whether the geological formation proximate to the wellbore is likely to support fluid flow (e.g., by having fractures or other structures that allow for fluid flow).

[0074] Analysis tools repository 226 may include any number and type of algorithms usable to infer properties of the geological formation based on measurements. For example, analysis tools repository 226 may include algorithms usable to infer the properties of the geological formation based on any of (i) fracture count, (ii) fracture aperture size, (iii) shear anisotropy, (iv) shear attention, (v) Stoneley transmissivity, (vi) Stoneley reflectivity, (vii) critically stressed fractures, and / or other types of measurements. Any of the algorithms may be modifiable using thresholds or other information from criteria 208.

[0075] At least one of the algorithms may be usable to identify critically stressed fractures. The algorithm may identify whether fractures planes in the geological formation are oriented between 20-40 degrees relative to the direction of maximum horizontal stress in the geological formation. The result of the algorithm may indicate whether existing stress in the geological formation is likely to keep fractures (if present) open (e.g., if between 20-40 degrees) or close fractures (e.g., if not between 20-40 degrees).

[0076] Any number of the algorithms may infer whether fractures for fluid flow are present. However, the algorithms may not infer a level of fluid permeability of the geological formation (or fluid permeabilities for different portions of the geological formation). Thus, the results of these algorithms may be binary in that the results indicate whether fluid flow is likely to be present or not.

[0077] Turning to FIG. 2C, a third data flow diagram in accordance with an embodiment is shown. The third data flow diagram may illustrate data used in and data processing performed in analyzing fluid flow analysis results 230 to obtain zones 242.

[0078] To obtain zones 242, zone creation process 240 may be performed. During zone creation process 240, fluid flow analysis results 230 may be analyzed to identify portions of the geological formation that are likely to support fluid flow. For example, each of fluid flow analysis results 230 may be analyzed with respect to position along the wellbore. If any of the fluid flow analysis results indicate presence of fractures or other structures likely to supportfluid flow (e.g., sufficient for a use), then the position may be marked as a zone. Refer toFIG. 2E for additional details regarding identification of zones 242 based on fluid flow analysis results 230.

[0079] When evaluating whether a position along a wellbore is likely to support fluid flow, a margin may be added to each of the fluid flow results. For example, if a fluid flow result indicates that a depth range of 1000-1050 feet is likely to support fluid flow, the range may be extended on one or both ends by a fixed or proportional amount. If the margin is a fixed 10 feet, then the depth range may be extended to 990-1060 feet. Thus, the depth ranges along the wellbore noted as flagged by each fluid flow analysis result may be padded with a margin. The margin may be, for example, one meter, a percentage based on a range of a flagged area (e.g., 10%, etc.), and / or may be defined using other methods. A subject matter expert or automated process may define the margin.

[0080] Zones 242 may include information defining various locations along the wellbore as being candidates for injection and / or extraction of fluids from a proximate geological formation. For example, zones 242 may indicate depth ranges along the wellbore that are candidates for injection and / or extractions of fluids.

[0081] Turning to FIG. 2D, a fourth data flow diagram in accordance with an embodiment is shown. The fourth data flow diagram may illustrate data used in and data processing performed in ranking zones 242 to obtain ranked zones 254.

[0082] Ranked zones 254 may include quantifications regarding the propensity of different zones 242 to support fluid flow usable for energy production or other uses. To obtain ranked zones 254, ranking process 250 may be performed.

[0083] During ranking process 250, each of zones 242 may be ranked based on fluid flow analysis results 230 and ranking system 252. To rank a zone, fluid flow analysis results 230 may be reviewed to identify any that indicate that the zone is likely to support fluid flow. For those fluid flow analysis results that indicate that the zone is likely to support fluid flow, pointvalues may be assigned based on ranking system 252. The point values may be used to obtain a quantification for the zone.

[0084] Ranking system 252 may specify values based on the fluid flow analysis result 230. For example, ranking system 252 may indicate that each fluid flow analysis result 230 that indicates that the zone is likely to support fluid flow currently (e.g., may be referred to as a “qualifier”) is to be assigned a value of 1. Ranking system 252 may also indicate that each fluid flow analysis result 230 that indicates that the zone is likely to support fluid flow in the future for various reasons such as being due to alignment of fracture planes and horizontal stress (e.g., may be referred to as a “booster”) is to be assigned a value of 1, so long as at least one other fluid flow analysis result indicates that fractures that support fluid flow is present. In other words, ranking system 252 may precondition awarding of points for future propensity to maintain fluid flow based on the currently ability of the zone to support fluid flow.

[0085] Ranking system 252 may also specify that point values are only assigned for fluid flow analysis results 230 that indicate that same portions of the zone are likely to support fluid flow. For example, a zone of zones 242 may include a region of wellbore where (i) two fluid flow analysis result indicates that a first portion of the region are likely to support fluid flow and (ii) two fluid flow results (with at least one different from the first two) indicate that a second portion of the region are likely to support fluid flow. Thus, up to three fluid flow results may indicate that the zone supports fluid flow currently. However, rather than assigning a value of 3 to the zone for each of these different results, only a value of 2 may be assigned because no portion of the zone is indicated by all 3 fluid flow analysis results as supporting fluid flow. Thus, points may only be assigned based on a set of fluid flow analysis results that all indicate that a same portion of the zone supports fluid flow. Refer to FIG. 2E for additional details regarding calculation of values usable to rank different zones.

[0086] Turning to FIG. 2E, a diagram of an example of zones and fluid flow analysis results 230 in accordance with an embodiment is shown. In FIG. 2E, five fluid flow analysisresults are shown in forms of columns A-E. In each of columns A-D, the shaded regions indicate that that the corresponding portions of the wellbore are proximate to portions of a geological formation that supports fluid flow. In column E, the shaded region indicates that the corresponding portions of the wellbore are likely to support fluid flow in the future (e.g., due to horizontal stress / fracture plane alignment).

[0087] In the diagram, depth into the wellbore is indicated as increasing from the top to the bottom of the page. Thus, for example, the fluid flow analysis results illustrated in column A indicates that two regions along the wellbore are proximate to portions of the geological formation that support fluid flow, while the fluid flow analysis results illustrate in column C includes a single region along the wellbore that is proximate to a portion of the geological formation that supports fluid flow.

[0088] To define zones along the wellbore, the fluid flow analysis results may be reviewed by starting at a top of the wellbore and scanning down until any of the fluid flow analysis results illustrated in columns A-D indicate that the geological formation supports fluid flow. In this example, the first fluid flow analysis results illustrated as column A is the first to indicate that the geological formation supports fluid flow. The start of the region indicated by column A may be marked as a start to a first zone. Once marked, the scan may be continued to identify an end to the first zone. The end may be identified by scanning further down on the page until none of the fluid flow analysis results indicate that the geological formation supports fluid flow. In this example, this occurs after the fluid flow analysis result illustrated in column B indicates that the geological formation no longer supports fluid flow, which may be marked as the end of the first zone. In other words, each zone may be an aggregate of regions where any number of fluid flow analysis results indicate co-extensive regions of the wellbore as being are proximate to portions of the geological formation that support fluid flow.

[0089] Fluid flow analysis results that indicate future propensity for continued fluid flow may not be considered when defining zones. In other, in this example, the fluid flow result illustrated in column E may not be taken into account when defining zones.

[0090] In this example, three zones are defined based on the fluid flow results. Once defined, each of the zones may be ranked using the ranking system. In this example, the first zone may be assigned a value of two because the first two fluid flow results illustrated in columns A and B indicate coextensive regions where the geological formation supports fluid flow (e.g., two qualifiers each with values of one).

[0091] The second zone may also be assigned a value of two because the fluid flow result illustrated in column C indicates presence of fractures or other structures that are likely to support fluid flow, and the fluid flow analysis result illustrated in column E indicates that fluid flow will likely continue in the future and is co-extensive with the positive result illustrated in column C (e.g., one qualifier with a value of 1, and a booster with a value of 1 that meets its prerequisite of presence of fractures or other structures as indicated by column C).

[0092] The third zone may be assigned a value of three because the fluid flow results illustrated in columns A and D indicate coextensive regions where the geological formation supports fluid flow, and the fluid flow analysis result illustrated in column E indicates that fluid flow in these coextensive regions of columns A and D will likely continue in the future (e.g., two qualifiers with values of 1, and a booster with a value of 1 that meets its prerequisite of presence of fractures or other structures as indicated by column C). The third zone, in this example, is not assigned a value of four because all of the qualifiers depicted in columns A, B, and D are not coextensive, at best only two are co-extensive.

[0093] Thus, in this example, first zone is assigned a value of two, second zone is also assigned a value of two, and third zone is assigned a value of three. Accordingly, third zone is ranked the highest while the first and second zones being ranked lower and equally to oneanother, under this example ranking system. It will be appreciated that a ranking system in may assign different point values for different fluid flow analysis results than described with respect to this example without departing from embodiment disclosed herein.

[0094] Turning to FIG. 2F, a fifth data flow diagram in accordance with an embodiment is shown. The fifth data flow diagram may illustrate data used in and data processing performed in obtaining formation model 266 usable to guide a completion of a well.

[0095] To obtain formation model 266, modeling process 262 may be performed. During modeling process, ranked zones 254, thermal properties data 260, and conditioned measurement data 206 may be ingested and used to generate formation model 266.

[0096] Thermal properties data 260 may include information regarding thermal properties of the rocks and / or other constituent materials of the geological formation along the wellbore. The thermal properties may include thermal conductivity, thermal capacity, thermal diffusivity, and / or other properties. The thermal properties may be obtained based on mineral and fluid volumes obtained / characterized during drilling of the wellbore, temperature, and pressure. For example, a geometric mean of the thermal properties of materials obtained during drilling of the wellbore may be used to obtain thermal properties data 260. The thermal properties of the constituent materials may be obtained via spectroscopy, nuclear tools, and / or other types of workflows.

[0097] To obtain formation model 266, a modeling template (e.g., 264) may be populated using ranked zones 254, thermal properties data 260, and conditioned measurement data 206. Modeling template 264 may define an arrangement of portions of the aforementioned data with respect to one another. The arrangement may establish associates between different portions of the well with respect to (i) the thermal properties of the geological formation proximate to the portions of the well, (ii) rankings for zones, and (iii) the conditioned measurement data for the portions of the well. Refer to FIG. 2H for additional details regarding obtaining of formation model 266.

[0098] The resulting formation model 266 may be usable to identify portions of the well proximity to portions of the geological formation that are likely to support fluid flow and have compositions conducive to heating of fluids. For example, the zone rankings may indicate areas of the well where the geological formation is likely support fluid flow and the associated thermal properties of the geological formation within the area that have high thermal conductivity, high thermal capacity, and / or other thermal properties indicating that larger amounts of heat may be extracted from the area.

[0099] Turning to FIG. 2G, a sixth data flow diagram in accordance with an embodiment is shown. The fifth data flow diagram may illustrate data used in and data processing performed in obtaining a well completion plan (e g., 274) usable to complete a well.

[0100] To obtain well completion plan 274, plan generation process 270 may be performed. During plan generation process 270, formation model 266 may be analyzed to identify portions of the geological formation that both support fluid flow and are composed of materials that facilitate extraction of thermal energy (e g., heating of fluids). Formation model 266 may be analyzed, for example, by using the top ranked zones as an initial set of potential locations for injection / extraction of fluids with respect to the geological formation. The initial set may then be revised based on the rock properties to obtain a final set of potential locations. Some potential locations of the final set of potential locations may then be selected based on a variety of factors (e.g., related to drilling, completions, regulatory, etc.).

[0101] Once obtained, the selected potential locations may then be used to generate well completion plan. Well completion plan 274 may include any number of actions to be performed to complete the well.

[0102] Once obtained, well completion plan 274 may be used to complete a well. For example, all or a portion of the actions specified by well completion plan 274 may be performed to complete the well.

[0103] Once completed, the completed well may be used, for example to produce energy by supplying heated fluids to a top side power station. It will be appreciated that the well may be used for other purposes without departing from embodiments disclosed herein.

[0104] Turning to FIG. 2H, a diagram of an example of the information content of formation model 266 in accordance with an embodiment is shown. For example, the diagram may represent a graphical user interface (or other type of graphical representation) of the content of a formation model.

[0105] In FIG. 2H, representations of the content of a formation model are shown graphically. For example, the diagram may include various display areas (e.g., 280, 282A- 282N, 284, 286). These display areas may show graphical representations of different portions of the information content of a formation model. In this figure, a limited number of areas are illustrated but it will be appreciated that a graphical representation of formation model 266 may include additional, fewer, and / or different areas without departing from embodiments disclosed herein.

[0106] The diagram may include area 280 in which information regarding the thermal properties of the geological formation along the wellbore of a well are shown. For example, area 280 may include graphical representations (e.g., color, infill patterns, line weights, etc.) that represent a magnitude of the thermal conductivity, thermal capacity, and thermal diffusivity of the geological formation. Area 280 may include, from a top to the bottom of the page, thermal information as a function of depth into the well. Thus, a completion engineer, another person, an automated process, and / or another entity may utilize the thermal properties to discriminate different areas of the geological formation along the wellbore that are better suited and / or less well suited for geothermal energy production or other uses.

[0107] The diagram may also include areas 282A-282 in which information regarding some conditioned measurement data 206 is positioned. For example, these areas may includegraphical representations (e.g., plots) of measurements upon which zone rankings are based (e.g., measurements used as qualifiers in ranking of different zones).

[0108] The diagram may further include area 284 in which information regarding some other conditioned measurement data 206 is positioned. For example, these areas may include graphical representations (e.g., plots) of measurements upon which zone rankings are also based (e.g., measurements used as boosters in ranking of different zones).

[0109] The diagram may additionally include area 286 in which information regarding zones and rankings of the zones is positioned. Area 286 may include zone indicators (e.g., 288) that indicate (i) the areas of the wellbore corresponding to each zone and (ii) the ranking of each zone. For example, the zone indicators be implemented using bars having heights, infill pattern, coloring, line weight, and / or other characteristics corresponding to the ranking of each zone.

[0110] Additionally, a numerical value representing the value assigned to each zone may be positioned next to each zone. For example, as seen in FIG. 2H, four zone indicators (dark infill pattern rectangles) may be present. A value used as a basis for ranking the zone may be positioned to the right of (or at other locations with respect to) each zone indicator.

[0111] The height and position of each zone indicator may correspond to the position and size of the zone along the wellbore. For example, the depth into the well may increase from top to the bottom of the page. The first zone indicator (e.g., 288) may be positioned and have a height that corresponding to the range of the depths of the first zone.

[0112] Thus, as shown in FIG. 2H, four ranked zones are shown. The shallowest ranked zone, in the example, is shown using the first zone indicator 288, and has a value of 3. The second ranked zone has a value of 2, the third ranked zone has a value of 1, and the fourth ranked zone has a value of 4. Thus, in terms of likelihood to allow for fluid flow, deepest ranked zone with a value of 4 is ranked as the best, the shallowest ranked zone with a value of 3 is ranked as next best, etc.

[0113] However, the highest ranked zone may not be the most likely to facilitate geothermal energy production. To facilitate identification of which ranked zone is the most likely to facilitate geothermal energy production, the diagram may also include are number of indicators (e.g., 290) that associate thermal rock properties and / or conditioned measurement data with corresponding zones. For example, indicator 290 may highlight or otherwise indicate the portions of areas 280, 282A-282N, and 284 that are associated with the shallowest ranked zone. Using the highlighting, the rock properties and / or conditioned measurement data associated with the ranked zone may be identified. Thus, the combination of these pieces of information may be used to ascertain the relative merits of attempting to use each ranked zone for geothermal energy production.

[0114] For example, the thermal properties may indicate whether the constituent materials of a portion of a geological formation in a ranked zone are likely to facilitate or hinder thermal energy production. Accordingly, the combination of ranking and thermal properties (and / or other properties of a geological formation) may be used to establish a completion plan.

[0115] To further illustrate how information from a formation model may be utilized, FIG. 21 shows an example diagram of an interface populated with exemplary data from a formation model in accordance with embodiments disclosed herein. As seen in FIG. 21, the populated interface may allow for rapid identification and use of both zone rankings and thermal properties by virtue of the associations established.

[0116] For example, four zones with different rankings are shown, and associated with corresponding thermal properties. Thus, this information may be used to select how to complete a well.

[0117] Any of the data flows shown in FIGs. 2A-2D and 2F-2G may be performed.Any of the processes illustrated using the second set of shapes may be performed, in part or whole, by digital processors (e.g., central processors, processor cores, etc.) that executecorresponding instructions (e.g., computer code / software). Execution of the instructions may cause the digital processors to initiate performance of the processes. Any portions of the processes may be performed by the digital processors and / or other devices. For example, executing the instructions may cause the digital processors to perform actions that directly contribute to performance of the processes, and / or indirectly contribute to performance of the processes by causing (e.g., initiating) other hardware components to perform actions that directly contribute to the performance of the processes.

[0118] Any of the processes illustrated using the second set of shapes may be performed, in part or whole, by special purpose hardware components such as digital signal processors, application specific integrated circuits, programmable gate arrays, graphics processing units, data processing units, and / or other types of hardware components. These special purpose hardware components may include circuitry and / or semiconductor devices adapted to perform the processes. For example, any of the special purpose hardware components may be implemented using complementary metal-oxide semiconductor based devices (e.g., computer chips).

[0119] Any of the data structures illustrated using the first and third set of shapes may be implemented using any type and number of data structures. Additionally, while described as including particular information, it will be appreciated that any of the data structures may include additional, less, and / or different information from that described above. The informational content of any of the data structures may be divided across any number of data structures, may be integrated with other types of information, and / or may be stored in any location.

[0120] As discussed above, the components of FIG. IB may perform various methods to facilitate completion of wells. FIG. 3 illustrate a method that may be performed by the components of the system of FIG. IB. In the diagram discussed below and shown in FIG. 3,any of the operations may be repeated, performed in different orders, and / or performed in parallel with or in a partially overlapping in time manner with other operations.

[0121] Turning to FIG. 3, a flow diagram illustrating a method for managing completion of a well in accordance with an embodiment is shown. The method may be performed, for example, by any of planning system 130, analysis system 140, and / or other components of the system shown in FIGs. 1B-2H.

[0122] At operation 300, a plurality of measurements of a geological formation in which a wellbore of a well is positioned are obtained. The plurality of measurements may be obtained by (i) reading the plurality of measurements from storage, (ii) receiving the plurality of measurements from another device, (iii) generating the plurality of measurement using measurement tools, and / or via other methods.

[0123] At operation 302, for each measurement of the plurality of measurements, obtain a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation. The fluid flow analysis results may be obtained by ingesting a corresponding measurement of the plurality of measurements into an analysis algorithm. The analysis algorithm may provide the fluid flow analysis result. The fluid flow analysis result for each measurement of the plurality of measurements may indicate portions of the geological formation that are likely to support fluid flow.

[0124] At operation 304, at least one zone along the wellbore is defined based on the fluid flow analysis results. The at least one zone may be defined by identifying contiguous portions of the wellbore indicated by any of the fluid flow analysis results as being proximate to portions of the geological formation that support fluid flow. Each identified contiguous portion of the wellbore may be defined as a zone.

[0125] In an embodiment, the at least one is defined by identifying a portion of the geological formation indicated by a fluid flow analysis result of the fluid flow analysis results as likely supporting fluid flow; identifying whether any of the fluid flow analysis results otherthan the fluid flow analysis results indicates that the portion of the geological formation is likely to support fluid flow; and, in an instance of the identifying wherein a second fluid flow analysis result of the fluid flow analysis results indicates that the portion of the geological formation is likely to support fluid flow: defining a zone of the at least one zone to include the portion of the geological formation and a second portion of the geological formation indicated by the second fluid flow analysis result.

[0126] At operation 306, the at least one zone is ranked based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone. The at least one zone may be ranked by, for each zone of the at least one zone, (i) calculating a value based on the ranking system, and (ii) rank ordering the zones based on the calculated values.

[0127] The ranking system may define a numerical score for the at least one zone based on the fluid flow analysis results. A first portion of the fluid flow analysis results may indicate whether at least one portion of the geological formation in the at least one zone is likely to support fluid flow. A second portion of the fluid flow analysis results may indicate whether stress in the at least one portion of the geological formation is favorable for opening fractures in the at least one portion of the geological formation or is favorable for closing factures in the at least one portion of the geological formation.

[0128] The numerical score may include a cardinality the first portion of the fluid flow analysis results that indicate that the at least one zone is likely to support fluid flow. The numerical score may also include a summation of the cardinality and a value for the second portion of the fluid flow analysis results that depends on whether the stress in the at least one portion of the geological formation is favorable for opening fractures in the at least one portion of the geological formation. The value may increase the numerical score when the summation of the cardinality is greater than zero, and does not increase the numerical score when the summation of the cardinality is not greater than zero.

[0129] At operation 308, a formation model for the geological formation may be obtained using the at least one ranked zone and thermal properties of the geological formation. The formation model may be obtained by populating a template formation model using the at least one ranked zone and thermal properties of the geological formation.

[0130] The formation model may associate thermal properties of portions of the geological formation with corresponding likelihoods of the portions of the geological formation supporting fluid flow. However, the formation model may not indicate magnitudes of fluid permeabilities of the portions of the geological formation.

[0131] In an embodiment, the formation model is obtained by generating a graphical user interface. The graphical user interface may display, with respect to position along the well: each of the plurality of measurements; indicators for positions of the at least ranked one zone; and indicators for different ranks of the at least one ranked zone. The graphic user interface may also display, with respect to the position along the well: thermal properties of the geological formation, the thermal properties include at least one selected from a group of thermal properties consisting of: thermal conductivity; thermal capacity; and thermal diffusivity.

[0132] At operation 310, a well completion plan is obtained using, at least, the formation model. The well completion plan may be obtained by (i) reading the well completion plan from storage, (ii) receiving the well completion plan from another device, (iii) generating the well completion plan, and / or via other methods.

[0133] The well completion plan may be obtained by providing the formation model to a planning system. An operator of the planning system may use the formation model to complete the well completion plan. For example, a subject matter expert, another person, or an automated system may use the formation model to identify portions of the well for geothermal energy exploitation. The identified portions may be used to define workflows (e.g., actions) to complete the well such that the portions of the well are used for geothermalenergy exploitation. For example, the portions of the well may be used for injection / extraction of fluids that carry heat from a geothermal reservoir in the geological formation out of the geological formation.

[0134] At operation 312, the well may be completed using the well completion plan to obtain a completed well. The well may be completed by performing any of the actions / workflows specified by the well completion plan. For example, various actions may be performed to install completion components in the well. The location and type of the completion components may be based on the formation model.

[0135] At operation 314, an energy product is obtained using geothermal energy from the completed well. The energy product may be obtained by pumping fluid into and / or extracting fluid from the geological formation using the well. The fluid may be used to move heat as part of a process of obtaining the energy product, such as exploitation of heat by a top side power facility.

[0136] The method may end following operation 314.

[0137] Thus, using the method illustrated in FIG. 3, embodiments disclosed herein may improve the likelihood of successfully exploiting geothermal resources. The likelihood of success may be improved by use of a ranking system to identify and rank different zones for geothermal energy exploitation purposes.

[0138] Because areas with geothermal energy resources are geologically active, (i) the current fracture properties (e.g., likelihood of supporting fluid flow) of the geological formation may not be sufficiently predictive regarding whether a geological formation will support fluid flow in the future, and (ii) assumptions made when interpreting measurements of the geological formation to determine a current fracture property may not be true. To improve the likelihood of producing completed wells that are likely to be usable to exploit geothermal resources, the ranking system may mitigate interpretation of measurements by using (i) a variety of different measurements with different assumptions so that an incorrectassumption regarding a single measurement has a reduced impact on the interpretation of the measurements for ranking purposes, and (ii) take into account forces in the geological formation that are likely to open or close existing fractures. Thus, the ranking system may identify zones that are proximate to portions of the geological formation that currently support fluid flow (e.g., due to presence of fractures) and are likely to continue to support fluid flow into the future (e.g., forces in the geological formation are likely to keep the fractures open).

[0139] Further, to identify zones that are not only likely to not only able to support fluid flow but that are also likely to allow for geothermal exploitation, the formation models based on the ranked zones may directly associate the thermal properties of the formation with the ranked zones. Thus, zones of a well that both support fluid flow and extraction of heat may be identified and used as a basis for well completion planning. Accordingly, the completed wells based on the well completion plans may be more likely to facilitate geothermal energy exploitation.

[0140] Thus, embodiments disclosed herein may address the technical challenge of identification of portions of a geological formation that are likely to be usable to exploit geothermal resources. The disclosed embodiments may do so using a ranking system that takes into account the current fracture properties and forces in place that may modify the current fracture properties of a geological formation over time, and associate the ranked zones with thermal properties of rocks. The disclosed embodiments may do so using a quantitative model that avoids errors, bias, and / or features present in measurement data interpretation. Accordingly, the resulting well completion plans may be more likely to facilitate completion of geothermal resource exploitable wells.

[0141] Any of the components illustrated in FIGs. 1B-2H may be implemented with one or more computing devices. Turning to FIG. 4, a block diagram illustrating an example of a data processing system (e.g., a computing device) in accordance with an embodiment is shown. For example, system 400 may represent any of data processing systems describedabove performing any of the processes or methods described above. System 400 can include many different components. These components can be implemented as integrated circuits (ICs), portions thereof, discrete electronic devices, or other modules adapted to a circuit board such as a motherboard or add-in card of the computer system, or as components otherwise incorporated within a chassis of the computer system. Note also that system 400 is intended to show a high level view of many components of the computer system. However, it is to be understood that additional components may be present in certain implementations and furthermore, different arrangement of the components shown may occur in other implementations. System 400 may represent a desktop, a laptop, a tablet, a server, a mobile phone, a media player, a personal digital assistant (PDA), a personal communicator, a gaming device, a network router or hub, a wireless access point (AP) or repeater, a set-top box, or a combination thereof Further, while only a single machine or system is illustrated, the term “machine” or “system” shall also be taken to include any collection of machines or systems that individually or jointly execute a set (or multiple sets) of instructions to perform any one or more of the methodologies discussed herein.

[0142] In an embodiment, system 400 includes processor 401, memory 403, and devices 405-407 via a bus or an interconnect 410. Processor 401 may represent a single processor or multiple processors with a single processor core or multiple processor cores included therein. Processor 401 may represent one or more general -purpose processors such as a microprocessor, a central processing unit (CPU), or the like. More particularly, processor 401 may be a complex instruction set computing (CISC) microprocessor, reduced instruction set computing (RISC) microprocessor, very long instruction word (VLIW) microprocessor, or processor implementing other instruction sets, or processors implementing a combination of instruction sets. Processor 401 may also be one or more special-purpose processors such as an application specific integrated circuit (ASIC), a cellular or baseband processor, a field programmable gate array (FPGA), a digital signal processor (DSP), a network processor, agraphics processor, a network processor, a communications processor, a cryptographic processor, a co-processor, an embedded processor, or any other type of logic capable of processing instructions.

[0143] Processor 401, which may be a low power multi-core processor socket such as an ultra-low voltage processor, may act as a main processing unit and central hub for communication with the various components of the system. Such processor can be implemented as a system on chip (SoC). Processor 401 is configured to execute instructions for performing the operations discussed herein. System 400 may further include a graphics interface that communicates with optional graphics subsystem 404, which may include a display controller, a graphics processor, and / or a display device.

[0144] Processor 401 may communicate with memory 403, which in an embodiment can be implemented via multiple memory devices to provide for a given amount of system memory. Memory 403 may include one or more volatile storage (or memory) devices such as random access memory (RAM), dynamic RAM (DRAM), synchronous DRAM (SDRAM), static RAM (SRAM), or other types of storage devices. Memory 403 may store information including sequences of instructions that are executed by processor 401, or any other device. For example, executable code and / or data of a variety of operating systems, device drivers, firmware (e.g., input output basic system or BIOS), and / or applications can be loaded in memory 403 and executed by processor 401. An operating system can be any kind of operating systems, such as, for example, Windows® operating system from Microsoft®, Mac OS® / iOS® from Apple, Android® from Google®, Linux®, Unix®, or other real-time or embedded operating systems such as VxWorks.

[0145] System 400 may further include IO devices such as devices (e.g., 405, 406, 407, 408) including network interface device(s) 405, optional input device(s) 406, and other optional IO device(s) 407. Network interface device(s) 405 may include a wireless transceiver and / or a network interface card (NIC). The wireless transceiver may be a WiFi transceiver, aninfrared transceiver, a Bluetooth transceiver, a WiMax transceiver, a wireless cellular telephony transceiver, a satellite transceiver (e.g., a global positioning system (GPS) transceiver), or other radio frequency (RF) transceivers, or a combination thereof. The NIC may be an Ethernet card.

[0146] Input device(s) 406 may include a mouse, a touch pad, a touch sensitive screen (which may be integrated with a display device of optional graphics subsystem 404), a pointer device such as a stylus, and / or a keyboard (e.g., physical keyboard or a virtual keyboard displayed as part of a touch sensitive screen). For example, input device(s) 406 may include a touch screen controller coupled to a touch screen. The touch screen and touch screen controller can, for example, detect contact and movement or break thereof using any of a plurality of touch sensitivity technologies, including but not limited to capacitive, resistive, infrared, and surface acoustic wave technologies, as well as other proximity sensor arrays or other elements for determining one or more points of contact with the touch screen.

[0147] IO devices 407 may include an audio device. An audio device may include a speaker and / or a microphone to facilitate voice-enabled functions, such as voice recognition, voice replication, digital recording, and / or telephony functions. Other IO devices 407 may further include universal serial bus (USB) port(s), parallel port(s), serial port(s), a printer, a network interface, a bus bridge (e.g., a PCI-PCI bridge), sensor(s) (e.g., a motion sensor such as an accelerometer, gyroscope, a magnetometer, a light sensor, compass, a proximity sensor, etc.), or a combination thereof. IO device(s) 407 may further include an imaging processing subsystem (e.g., a camera), which may include an optical sensor, such as a charged coupled device (CCD) or a complementary metal-oxide semiconductor (CMOS) optical sensor, utilized to facilitate camera functions, such as recording photographs and video clips. Certain sensors may be coupled to interconnect 410 via a sensor hub (not shown), while other devices such as a keyboard or thermal sensor may be controlled by an embedded controller (not shown), dependent upon the specific configuration or design of system 400.

[0148] To provide for persistent storage of information such as data, applications, one or more operating systems and so forth, a mass storage (not shown) may also couple to processor 401. In an embodiments, to enable a thinner and lighter system design as well as to improve system responsiveness, this mass storage may be implemented via a solid state device (SSD). In an embodiments, the mass storage may primarily be implemented using a hard disk drive (HDD) with a smaller amount of SSD storage to act as a SSD cache to enable non-volatile storage of context state and other such information during power down events so that a fast power up can occur on re-initiation of system activities. Also a flash device may be coupled to processor 401, e.g., via a serial peripheral interface (SPI). This flash device may provide for non-volatile storage of system software, including a basic input / output software (BIOS) as well as other firmware of the system.

[0149] Storage device 408 may include computer-readable storage medium 409 (also known as a machine-readable storage medium or a computer-readable medium) on which is stored one or more sets of instructions or software (e g., processing module, unit, and / or processing module / unit / logic 428) embodying any one or more of the methodologies or functions described herein. Processing module / unit / logic 428 may represent any of the components described above. Processing module / unit / logic 428 may also reside, completely or at least partially, within memory 403 and / or within processor 401 during execution thereof by system 400, memory 403 and processor 401 also constituting machine-accessible storage media. Processing module / unit / logic 428 may further be transmitted or received over a network via network interface device(s) 405.

[0150] Computer-readable storage medium 409 may also be used to store some software functionalities described above persistently. While computer-readable storage medium 409 is shown in an embodiment to be a single medium, the term “computer-readable storage medium” should be taken to include a single medium or multiple media (e.g., a centralized or distributed database, and / or associated caches and servers) that store the one ormore sets of instructions. The terms “computer-readable storage medium” shall also be taken to include any medium that is capable of storing or encoding a set of instructions for execution by the machine and that cause the machine to perform any one or more of the methodologies of embodiments disclosed herein. The term “computer-readable storage medium” shall accordingly be taken to include, but not be limited to, solid-state memories, and optical and magnetic media, or any other non-transitory machine-readable medium.

[0151] Processing module / unit / logic 428, components and other features described herein can be implemented as discrete hardware components or integrated in the functionality of hardware components such as ASICS, FPGAs, DSPs or similar devices. In addition, processing module / unit / logic 428 can be implemented as firmware or functional circuitry within hardware devices. Further, processing module / unit / logic 428 can be implemented in any combination hardware devices and software components.

[0152] Note that while system 400 is illustrated with various components of a data processing system, it is not intended to represent any particular architecture or manner of interconnecting the components; as such details are not germane to embodiments disclosed herein. It will also be appreciated that network computers, handheld computers, mobile phones, servers, and / or other data processing systems which have fewer components or perhaps more components may also be used with embodiments disclosed herein.

[0153] Some portions of the preceding detailed descriptions have been presented in terms of algorithms and symbolic representations of operations on data bits within a computer memory. These algorithmic descriptions and representations are the ways used by those skilled in the data processing arts to most effectively convey the substance of their work to others skilled in the art. An algorithm is here, and generally, conceived to be a self-consistent sequence of operations leading to a desired result. The operations are those requiring physical manipulations of physical quantities.

[0154] It should be borne in mind, however, that all of these and similar terms are to be associated with the appropriate physical quantities and are merely convenient labels applied to these quantities. Unless specifically stated otherwise as apparent from the above discussion, it is appreciated that throughout the description, discussions utilizing terms such as those set forth in the claims below, refer to the action and processes of a computer system, or similar electronic computing device, that manipulates and transforms data represented as physical (electronic) quantities within the computer system’s registers and memories into other data similarly represented as physical quantities within the computer system memories or registers or other such information storage, transmission or display devices.

[0155] Embodiments disclosed herein also relate to an apparatus for performing the operations herein. Such a computer program is stored in a non-transitory computer readable medium. A non-transitory machine-readable medium includes any mechanism for storing information in a form readable by a machine (e.g., a computer). For example, a machine- readable (e.g., computer-readable) medium includes a machine (e.g., a computer) readable storage medium (e.g., read only memory (“ROM”), random access memory (“RAM”), magnetic disk storage media, optical storage media, flash memory devices).

[0156] The processes or methods depicted in the preceding figures may be performed by processing logic that comprises hardware (e.g. circuitry, dedicated logic, etc.), software (e.g., embodied on a non-transitory computer readable medium), or a combination of both. Although the processes or methods are described above in terms of some sequential operations, it should be appreciated that some of the operations described may be performed in a different order. Moreover, some operations may be performed in parallel rather than sequentially.

[0157] Embodiments disclosed herein are not described with reference to any particular programming language. It will be appreciated that a variety of programming languages may be used to implement the teachings of embodiments disclosed herein.

[0158] In the foregoing specification, embodiments have been described with reference to specific exemplary embodiments thereof. It will be evident that various modifications may be made thereto without departing from the broader spirit and scope of the embodiments disclosed herein as set forth in the following claims. The specification and drawings are, accordingly, to be regarded in an illustrative sense rather than a restrictive sense.

Claims

CLAIMSWhat is claimed is:

1. A method for managing completion of a well for geothermal energy extraction, the method comprising: obtaining a plurality of measurements of a geological formation in which a wellbore of the well is positioned; for each measurement of the plurality of measurements, obtaining a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation; defining at least one zone along the wellbore based on the fluid flow analysis results; ranking the at least one zone based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone; and obtaining a formation model for the geological formation using the at least one ranked zone and thermal properties of the geological formation.

2. The method of claim 1 , wherein the ranking system defines a numerical score for the at least one zone based on the fluid flow analysis results.

3. The method of claim 2, wherein a first portion of the fluid flow analysis results indicate whether at least one portion of the geological formation in the at least one zone is likely to support fluid flow.

4. The method of claim 3, wherein a second portion of the fluid flow analysis results indicate whether stress in the at least one portion of the geological formation is favorable for opening fractures in the at least one portion of the geological formation or is favorable for closing factures in the at least one portion of the geological formation.

5. The method of claim 4, wherein the numerical score comprises a cardinality the first portion of the fluid flow analysis results that indicate that the at least one zone is likely to support fluid flow.

6. The method of claim 5, wherein the numerical score further comprises a summation of the cardinality and a value for the second portion of the fluid flow analysis results that depends on whether the stress in the at least one portion of the geological formation is favorable for opening fractures in the at least one portion of the geological formation.

7. The method of claim 6, wherein the value increases the numerical score when the summation of the cardinality is greater than zero, and does not increase the numerical score when the summation of the cardinality is not greater than zero.

8. The method of claim 1, wherein the formation model associates thermal properties of portions of the geological formation with corresponding likelihoods of the portions of the geological formation supporting fluid flow.

9. The method of claim 8, wherein the formation model does not indicate magnitudes of fluid permeabilities of the portions of the geological formation.

10. The method of claim 1, obtaining the formation model comprises: generating a graphical user interface that displays, with respect to position along the well: each of the plurality of measurements; indicators for positions of the at least one ranked one zone; and indicators for different ranks of the at least one ranked zone.

11. The method of claim 10, wherein the graphic user interface further displays, with respect to the position along the well: thermal properties of the geological formation, the thermal properties comprising at least one selected from a group of thermal properties consisting of: thermal conductivity; thermal capacity; andthermal diffusivity.

12. The method of claim 1, wherein the fluid flow analysis result for each measurement of the plurality of measurements indicates portions of the geological formation that are likely to support fluid flow.

13. The method of claim 1, wherein defining at least one zone along the wellbore based on the fluid flow analysis results comprises: identifying a portion of the geological formation indicated by a fluid flow analysis result of the fluid flow analysis results as likely supporting fluid flow; identifying whether any of the fluid flow analysis results other than the fluid flow analysis results indicates that the portion of the geological formation is likely to support fluid flow; in an instance of the identifying wherein a second fluid flow analysis result of the fluid flow analysis results indicates that the portion of the geological formation is likely to support fluid flow: defining a zone of the at least one zone to comprise the portion of the geological formation and a second portion of the geological formation indicated by the second fluid flow analysis result.

14. The method of claim 13, wherein each of the fluid flow analysis results indicate whether the portion of the geological formation is likely to support fluid flow, and each of the plurality of measurements characterize properties of the geological formation via different types of measurements.

15. The method of claim 1, further comprising: obtaining a well completion plan using, at least, the formation model; completing the well using a well completion plan to obtain a completed well; and obtaining an energy product using geothermal energy from the completed well.

16. A non-transitory machine-readable medium having instructions stored therein, which when executed by a processor, cause the processor to perform operations for managing completion of a well for geothermal energy extraction, the operations comprising:obtaining a plurality of measurements of a geological formation in which a wellbore of the well is positioned; for each measurement of the plurality of measurements, obtaining a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation; defining at least one zone along the wellbore based on the fluid flow analysis results; ranking the at least one zone based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone; and obtaining a formation model for the geological formation using the at least one ranked zone and thermal properties of the geological formation.

17. The non-transitory machine-readable medium of claim 16, wherein the ranking system defines a numerical score for the at least one zone based on the fluid flow analysis results.

18. The non-transitory machine-readable medium of claim 17, wherein a first portion of the fluid flow analysis results indicate whether at least one portion of the geological formation in the at least one zone is likely to support fluid flow.

19. A data processing system, comprising: a processor; and a memory coupled to the processor to store instructions, which when executed by the processor, cause the processor to perform operations for managing completion of a well for geothermal energy extraction, the operations comprising: obtaining a plurality of measurements of a geological formation in which a wellbore of the well is positioned; for each measurement of the plurality of measurements, obtaining a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation; defining at least one zone along the wellbore based on the fluid flow analysis results; ranking the at least one zone based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone; andobtaining a formation model for the geological formation using the at least one ranked zone and thermal properties of the geological formation.

20. The data processing system of claim 19, wherein the ranking system defines a numerical score for the at least one zone based on the fluid flow analysis results.

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