CROSS-REFERENCE TO RELATED APPLICATION

This application claims the benefits of priority to United States Provisional Patent Application No. 63/400,644, filed August 24, 2022, titled METHODS AND SYSTEMS FOR. NATURAL R.ESOUR.CE EXTRACTION USING A TUNED FLOW CONDUCTING NETWORK, the contents of which are hereby expressly incorporated into the present application by reference in their entirety.

FIELD

[0001] The present disclosure relates to processes for natural resource extraction, and in particular, to methods and systems for managing fluid circulation through a subsurface fluid conducting network of a solution mining operation.

BACKGROUND

[0002] Solution mining, also known as in-situ leaching or in-situ recovery, is a mineral extraction method where a wellbore is drilled into a subsurface formation to recover minerals such as salts, (e.g. halite, potash), phosphorus, uranium, copper and lithium. Ores or other deposits can be dissolved in-situ or leached and produced, for example, by pumping to the surface.

[0003] Subsurface salt deposits can be found, for example, in a subsurface salt dome, an anticline or a flat-bedded formation. Solution mining of salt domes is typically achieved by the creation of a salt cavern using one or more wells. In contrast, flat-bedded formations may represent thinner deposits and may require multiple horizontal wells to be drilled to access the deposit, at increased operational cost.

[0004] Accordingly, it would be useful to provide improved techniques for solution mining of minerals from flat-bedded subsurface formations. SUMMARY

[0005] In some aspects, the present disclosure describes a method to extract natural resource material from a subterranean formation. The method comprises: via a flow receiving communicator, disposed at the earth's surface and extending into the subterranean formation, injecting a lixiviant into a flow conducting network, established within the subterranean formation, with effect that: leaching of natural resource material, from the subterranean formation, is effectuated, with effect that a recovered leachate flow is discharged from the flow conducting network via a flow discharging communicator, disposed at the earth's surface and extending from the subterranean formation, with effect that the recovered leachate flow is produced at the surface; wherein: the flow conducting network includes a first borehole portion and a second borehole portion; the leaching includes: leaching of a first natural resource material, from a first natural resource material source within the subterranean formation, in response to emplacement of a first lixiviant-derived flow, derived from the injected lixiviant, in communication with the first natural resource material source within the subterranean formation, wherein the emplacement is effectuated while the first lixiviant-derived flow is being conducted through the first borehole portion; and leaching of a second natural resource material, from a second natural resource material source within the subterranean formation, in response to emplacement of a second lixiviant-derived flow, derived from the injected lixiviant, in communication with the second natural resource material source within the subterranean formation, wherein the emplacement is effectuated while the second lixiviant-derived flow is being conducted through the second borehole portion; the first lixiviant-derived flow and the second lixiviant-derived flow are conducted in parallel; sensing the rate of flow of the first lixiviant-derived flow; sensing the rate of flow of the second lixiviant- derived flow; and comparing the sensed rate of flow of the first lixiviant-derived flow and the sensed rate of flow of the second lixiviant-derived flow. [0006] In some embodiments, the methods and systems described herein can be used to extract a natural resource material from a subterranean formation, for example, using a flow conducting network. Advantageously, the methods and systems described herein enable the management of fluid flow through a flow conducting network without the use of external devices or components such as packers or plugs to control the flow dynamics. In this regard, less well intervention may be required to manage flow through the flow conducting network with an associated reduced risk for mechanical component failure. In addition, by using a multilateral flow conducting network configuration, a large portion of a target subsurface formation can be accessed by the flow conducting network from a single surface location, contributing to a smaller surface footprint and associated reduced surface resources.

BRIEF DESCRIPTION OF THE DRAWINGS

[0007] Reference will now be made, by way of example, to the accompanying drawings which show example implementations of the present application, and in which:

[0008] FIG. 1A is a schematic block diagram of a solution mining system suitable for implementation of examples described herein.

[0009] FIG. IB is a schematic block diagram showing a solution mining system suitable for implementation of examples described herein.

[0010] FIG. 10 is an example plan view of a multilateral well configuration for implementing the solution mining system of FIG. IB, in accordance with example implementations described herein.

[0011] FIG. 2 is a block diagram of an example computing system suitable for implementation of examples described herein.

[0012] FIG. 3A is a block diagram of an example flow conducting network tuning system, in accordance with example implementations described herein. [0013] FIG. 3B is a block diagram of another example flow conducting network tuning system, in accordance with example implementations described herein.

[0014] FIG. 4A is an example flow conducting network modification block that adds a specified tuning length to a flow conducting network, in accordance with example implementations described herein.

[0015] FIG. 4B is an example flow conducting network modification block that executes a change in borehole diameter in the flow conducting network, in accordance with example implementations described herein.

[0016] FIG. 4C is an example flow conducting network modification block that adds one or more flow channels to a flow conducting network, in accordance with example implementations described herein.

[0017] FIG. 4D is a is an example flow conducting network modification block that adds a fluid pulsating device into a wellbore of the flow conducting network, in accordance with example implementations described herein.

[0018] FIG. 5 is a flowchart showing operations of a method for extracting a natural resource material from a subterranean formation, in accordance with example implementations described herein.

[0019] Similar reference numerals have been used in different figures to denote similar components.

DESCRIPTION OF EXAMPLE IMPLEMENTATIONS

[0020] As used herein, the terms, "comprises" and "comprising" are to be construed as being inclusive and open ended, and not exclusive. Specifically, when used in the specification and claims, the terms, "comprises" and "comprising" and variations thereof mean the specified features, steps or components are included. These terms are not to be interpreted to exclude the presence of other features, steps or components. [0021] As used herein, the term "exemplary" or "example" means "serving as an example, instance, or illustration," and should not be construed as preferred or advantageous over other configurations disclosed herein.

[0022] As used herein, the terms "about", "approximately", and "substantially" are meant to cover variations that may exist in the upper and lower limits of the ranges of values, such as variations in properties, parameters, and dimensions.

[0023] As used herein, statements that a second item (e.g., a signal, value, scalar, vector, matrix, calculation, or bit sequence) is "based on" a first item can mean that characteristics of the second item are affected or determined at least in part by characteristics of the first item. The first item can be considered an input to an operation or calculation, or a series of operations or calculations that produces the second item as an output that is not independent from the first item.

[0024] The present disclosure describes methods, systems and processor- readable media for extracting a natural resource material from a subterranean formation by conducting lixiviant-derived flow through a flow conducting network. In examples, the methods, systems and processor-readable media can be applied to a flow conducting network that is configured to conduct a first lixiviant-derived flow and a second lixiviant-derived flow in parallel. According to examples, a lixiviant is injected into the flow conducting network, leaching of natural resource material from the subterranean formation is effectuated, the rate of flow of lixiviant-based flow through the flow conduction network is sensed and a recovered leachate flow is produced. In response to sensing that the rate of flow of a first lixiviant-based flow deviates from a second lixiviant-based flow within the flow conducting network, the flow conducting network is modified with effect that the rate of flow of at least one of the first or second lixiviant-derived flow is altered. .

[0025] In examples, the flow conducting network can be considered to be analogous with an electrical circuit, where the first and second lixiviant-derived flow are conducted through the flow conducting network in "parallel". In managing the rate of flow of the first and second lixiviant-derived flow through the flow conducting network, borehole modification actions can be performed to portions of the flow conducting network to ensure that the rate of flow of lixiviant-derived flow through the flow conducting network represents maximal production efficiency of recovered leachate flow.

[0026] Solution mining methods are commonly employed to produce salts or other minerals from subsurface deposits. Subsurface salt deposits may be found, for example, in a subsurface salt dome, an anticline or a flat-bedded formation. While salt domes may represent a thick deposit that can be efficiently produced through a single well by forming a salt cavern, flat-bedded formations may represent thinner deposits and require multiple horizontal wells to be drilled to access the deposit, at increased operational cost. Multilateral wellbores forming fluid-circulation loops represent an efficient approach to target thin, bedded formations, however the management of fluid flow in multilateral wellbores can be complex, often requiring the use of downhole tools such as packers and plugs to control fluid flow dynamics. Use of downhole tools such as packers and plugs further increase costs and incur risk as potential points of mechanical failure.

[0027] In some embodiments, the present disclosure describes examples that address some or all of the above drawbacks of existing solution mining approaches.

[0028] To assist in understanding the present disclosure, the following describes some concepts relevant to solution mining processes using a flow conducting network, along with some relevant terminology that may be related to examples disclosed herein.

[0029] In the present disclosure, "solution mining" can mean: a mineral extraction method where a natural resource material is dissolved in a fluid to form a solution or leached from the subterranean formation, and the leachate is produced, for example, by pumping to the surface, where the natural resource material can be recovered. Example minerals which are commonly extracted by solution mining include salts, such as halite, potash or trona, as well as phosphorus, uranium, copper and lithium. [0030] In the present disclosure, a "multilateral wellbore" can mean: a single access parent wellbore containing two or more wellbore branches or laterals drilled off of the parent wellbore from at least one junction. In some cases, a parent wellbore can be a vertical wellbore or a parent wellbore can be a horizontal or deviated wellbore. Multilateral wellbores can include one or more vertical laterals that deviate from the parent wellbore before running in a parallel direction to the parent wellbore. Multilateral wellbores can also include one or more horizontal or deviated laterals branching in various directions from the parent wellbore.

[0031] In the present disclosure, a "parent well" can mean: an initial well to be drilled into a target subterranean formation, for example, before any other wells are drilled. In examples, parent wells can include parent well pairs, in which one well of the well pair is a flow receiving communicator and the other well of the well pair is a flow discharging communicator.

[0032] In the present disclosure, a "child well" can mean: a well that is drilled after an initial parent well has been drilled into a subterranean formation, and possibly after a parent well has been on production. Child wells can also be called infill wells, and can be designed to target a region of a subterranean formation that cannot be accessed by a parent well. In some examples, a child well can be a multilateral branch of a multilateral well, where the child well is drilled off of the parent well or off of another child well at a multilateral junction. In examples, child wells can include child well pairs, in which one child well of the child well pair is in fluid connection to a flow receiving communicator and the other child well of the child well pair is in fluid connection to the flow discharging communicator.

[0033] In the present disclosure, a "flow conducting network" can mean: a borehole configuration extending into a subterranean formation, through which lixiviant-derived flow can be conducted. The flow conducting network can include a flow receiving communicator disposed at the earth's surface and extending into the subterranean formation, for receiving a lixiviant. The flow conducting network can also include a flow discharging communicator, disposed at the earth's surface and extending from the subterranean formation, for the production of recovered leachate flow at the surface. In some embodiments, for example, the flow conducting network can include a first borehole portion for conducting a first lixiviant-derived flow and a second borehole portion for conducting a second lixiviant-derived flow in parallel with the first lixiviant-derived flow.

[0034] In the present disclosure, a "first borehole portion" or a "second borehole portion" of a flow conducting network can mean: a borehole portion of the flow conducting network that conducts flow in parallel with another borehole portion of the flow conducting network. In examples, a first borehole portion or a second borehole portion can include a borehole configuration where a well pair is connected toe-to-toe to conduct flow in a loop or closed circuit, among other borehole configurations. In examples, a first or second borehole portion has defined properties to influence the rate of flow through the borehole portion. In examples, a first borehole portion can include a parent well pair and a second borehole portion can include a child well pair extending off of an existing first borehole portion at one or more multilateral junctions. In examples, flow can be received into a borehole portion at a multilateral junction and flow can be discharged from a borehole portion at another multilateral junction of the flow conducting network.

[0035] In the present disclosure, a "volumetric flow rate (Q)" or "rate of flow" can mean: the volume of lixiviant-derived flow, for example, conducting along a borehole per a unit of time. Volumetric flow rate can be measured using flowmeters, pressure sensors or radioactive tracers, among others. In some examples, measurements or predictions of the rate of flow can be presented as a flow profile, where a "flow profile" can mean: a log of the in-situ rate of flow at different depths in a well.

[0036] FIG. 1A shows a solution mining system 100a for extracting a natural resource material from a subterranean formation using a flow conducting network 105. The solution mining system 100a is an illustrative example of a system to which the systems, methods, and processor-readable media described herein can be applied, in accordance with examples of the present disclosure. [0037] In some embodiments, for example, the solution mining system 100a represents a solution mining operation where the flow conducting network 105 comprises a first borehole portion. A flow receiving communicator 102 and a flow discharging communicator 104 can be drilled as a parent well pair, for example, a horizontal well pair or a deviated well pair. In some embodiments, for example, the flow receiving communicator 102 and the flow discharging communicator 104 can each comprise a tubing string 132 (e.g. a coiled tubing or a production tubing) extending within a wellbore string from a surface level 106 and to a subsurface depth corresponding to a subterranean formation 108. In some embodiments, for example, the wellbore string can comprise a casing and optionally, a liner, and a casing shoe 116 can be fixed to the end of the casing. In some embodiments, for example, a liner or sections of a liner can have fluid flow openings (e.g. slots in a slotted liner, or another fluid flow communication structure) through which fluid can be exchanged between the wellbore string and the subterranean formation 108 or sections of the liner can be solid. In examples, the liner can be made of metal, plastic or a composite material. In other embodiments, for example, sections of the wellbores can be open-hole. At the surface level 106, a wellhead 112 can be fixed to the flow receiving communicator 102 and a wellhead 114 can be fixed to the flow discharging communicator 104.

[0038] In some embodiments, for example, the flow receiving communicator 102 and the flow discharging communicator 104 can extend vertically from the surface 106 to a target depth corresponding to the subterranean formation 108. In some examples, the flow receiving communicator 102 and the flow discharging communicator 104 can change direction and extend laterally, for example, horizontally or in a deviated direction to access the subterranean formation 108. In some embodiments, for example, the lateral extents of the flow receiving communicator 102 and flow discharging communicator 104 can be substantially parallel. In examples, the subterranean formation 108 can be a bedded formation defined by a top 118 and a bottom 120 of the formation. In some embodiments, for example, the lateral extents of the flow receiving communicator 102 and flow discharging communicator 104 can be positioned between the top 118 and the bottom 120 of the subterranean formation 108 or in other embodiments, one of either the flow receiving communicator 102 or the flow discharging communicator 104 can be positioned outside of the subterranean formation 108 while the other of either the flow receiving communicator 102 or the flow discharging communicator 104 can be positioned within the subterranean formation 108, for example, at an upper or lower extent of the subterranean formation 108.

[0039] In some embodiments, for example, the flow receiving communicator 102 and the flow discharging communicator 104 can each include a vertical well section and a lateral well section, the lateral well section having a heel region and a toe region, and where the flow receiving communicator 102 and the flow discharging communicator 104 can be connected toe-to-toe at a toe region connection point 110 to form a first borehole portion 122 of a flow conducting network 105.

[0040] In some examples, the subterranean formation 108 can include a minable source of a natural resource material, for example, a salt deposit containing potassium (K) salts such as potash (e.g. potassium chloride or KCI) or other natural resource material source. In some examples, the natural resource material can be recovered by a solution mining method, for example, where leaching of a natural resource material within the subterranean formation 108 is effectuated in response to the emplacement of a lixiviant-derived flow, derived from the injected lixiviant, in communication with the natural resource material source to produce a leachate. In some examples, the lixiviant in communication with the natural resource material source can be a brine, for example, a saturated brine or a super saturated brine, for example, comprising sodium chloride (NaCI), or the lixiviant can be another solvent. In some examples, the lixiviant can be injected into the flow receiving communicator 102 and a first lixiviant-derived flow can be conducted through a first borehole portion 122 of the flow conducting network 105, with effect that leaching of natural resource material is effectuated. In some embodiments, for example, the lixiviant can be heated at the surface using a heater 150 prior to being injected into the flow receiving communicator 102 or the lixiviant can be heated by a heat exchanger (not shown) located within the flow receiving communicator 102. Production tubing can transport the leachate containing the natural resource material from the subterranean formation 108 to the surface level 106, where the natural resource material can then be recovered. In some examples, the leachate can be produced by artificial lift, for example, using an electrical submersible pump (ESP) assembly (not shown) disposed at a subsurface intake location near the heel of the flow discharging communicator 104.

[0041] FIG. IB shows a solution mining system 100b for extracting an natural resource material from a subterranean formation 108 using a flow conducting network 105 including a first borehole portion and a second borehole portion. The solution mining system 100b is an illustrative example of a system to which the systems, methods, and processor-readable media described herein can be applied, in accordance with examples of the present disclosure.

[0042] In the example embodiment of solution mining system 100b, the solution mining system 100a is extended to include at least a second borehole portion 124 extending off of the first borehole portion 122 of the flow conducting network 105. In some examples, a second lixiviant-derived flow can be conducted through the second borehole portion 122 of the flow conducting network 105, with effect that leaching of natural resource material is effectuated. In some examples, a first child well 125a can be drilled off of the flow receiving communicator 102 at a first multilateral junction 126a and a second child well 125b can be drilled off of the flow discharging communicator 104 at a multilateral junction 126b to form a child well pair. In some examples, each child well in the child well pair can comprise a lateral section having at least a toe region, where the child well pair can be connected toe-to-toe at a toe region connection point 128 to form the second borehole portion 124 of the flow conducting network 105. In some embodiments, for example, the second borehole portion 124 can be designed to ensure that rate of flow of the second lixiviant-derived flow conducted through the second borehole portion 124 is equal to the rate of flow of the first lixiviant-derived flow conducted through the first borehole portion 122. In this way, the rate of flow of lixiviant- derived flow conducted through each borehole portion of the flow conducting network 105 can be considered to be uniform.

[0043] FIG. 1C is an example plan view of a multilateral well configuration comprising a fluid conducting network 105 for implementing the solution mining system 100b of FIG. IB, in accordance with example implementations described herein. In examples, the plan view depicts a flow conducting network 105 spanning a land section 140 as defined by a land grid 142. In examples, the flow conducting network 105 includes a first borehole portion 122 and one or more additional borehole portions 124 (e.g. 124a, 124b, 124c ... 124n). In examples, a well pad 144 on the surface 106 provides access to the flow conducting network 105 through a wellhead 112 of a flow receiving communicator 102 and a wellhead 114 of a flow discharging communicator 104. In some embodiments, for example, the additional borehole portions 124 can be designed to ensure that the rate of flow of lixiviant- derived flow conducted through each borehole portion of the flow conducting network 105 is uniform.

[0044] FIG. 2 is a block diagram of an example computing system 200 including computing hardware suitable for monitoring the rate of flow of lixiviant- derived flow in a flow conducting network 105, according to example embodiments described herein. In some implementations, computing system 200 can be an electronic computing device, such as a networked server. In other implementations, the computing system 200 can be a distributed computing system including multiple devices (such as a cloud computing platform) or a virtual machine running on one or more devices in mutual communication over a network. Other examples suitable for implementing implementations described in the present disclosure can be used, which can include components different from those discussed below. Although FIG. 2 shows a single instance of each component, there can be multiple instances of each component in the computing system 200.

[0045] The computing system 200 can include one or more processor devices (collectively referred to as processor device 202). The processor device 202 can include one or more processor devices such as a processor, a microprocessor, a digital signal processor, an application-specific integrated circuit (ASIC), a field- programmable gate array (FPGA), a dedicated logic circuitry, a dedicated artificial intelligence processor unit, or combinations thereof.

[0046] The computing system 200 can include one or more network interfaces (collectively referred to as network interface 206) for wired or wireless communication over a network. The network interface 206 can include wired links (e.g., Ethernet cable) and/or wireless links (e.g., one or more antennas). The computing system 200 can communicate with one or more user devices (such as user workstation computers) via the network interface 206. The computing system 200 can also communicate with various sensors or other data sources to obtain data used in monitoring the rate of flow of lixiviant-derived flow in a flow conducting network 105, such as sensors 208. In some embodiments, the sensors 208 can include sensors located within the flow conducting network 105, for example, sensors to sense the rate of flow of lixiviant-derived flow in one or more borehole portions of the flow conducting network 105.

[0047] The computing system 200 can include one or more non-transitory memories (referred to collectively as a memory 204), which can include a volatile or non-volatile memory (e.g., a flash memory, a random access memory (RAM), and/or a read-only memory (ROM)). The memory 204 can also include one or more mass storage units, such as a solid state drive, a hard disk drive, a magnetic disk drive and/or an optical disk drive.

[0048] The memory 204 can store instructions for execution by the processor device 202 to carry out examples described in the present disclosure. The instructions can include instructions 310-1 for implementing and operating a flow dynamics model 310 described below with reference to FIG 3. The memory 204 can include other software instructions, such as for implementing an operating system and other applications/functions. In some examples, the computing system 200 can additionally or alternatively execute instructions from an external memory (e.g., an external drive in wired or wireless communication with the computing system 200) or can be provided executable instructions by a transitory or non-transitory computer-readable medium. Examples of non-transitory computer readable media include a RAM, a ROM, an erasable programmable ROM (EPROM), an electrically erasable programmable ROM (EEPROM), a flash memory, a CD-ROM, or other portable memory storage. The memory 204 can also store information or data used in executing the flow dynamics model 310, for example, lixiviant-derived flow measurements 302 and optionally, borehole measurements 304.

[0049] The computing system 200 can also include a bus 212 providing communication among components of the computing system 200, including those components discussed above. The bus 212 can be any suitable bus architecture including, for example, a memory bus, a peripheral bus or a video bus, or the bus 212 can be another communication link such as a network interface 206.

[0050] FIG. 3A is a block diagram of an example flow conducting network design system 300 of the present disclosure. In some embodiments, for example, the flow conducting network design system 300 can receive as input, simulated borehole portion geometry 302 for borehole portions of a prospective flow conducting network 105 and can output a tuned flow conducting network design 340. In examples, the simulated borehole portions 302 can be simulated wellbore paths generated from a well simulator. In examples, a flow dynamics model 310 can receive the simulated borehole portion geometry 302 and can predict a deviation in the rate of flow 320 between at least two borehole portions of the flow conducting network 105. In examples, the flow dynamics model 310 can simulate the lixiviant-derived flow dynamics, for example, using the Navier-Stokes equations based on the simulated borehole portion geometry 302 while accounting for physical, geological or operational constraints on the borehole geometry. The flow dynamics model 310 can be a software that is implemented in the computing system 200 of FIG. 2, in which the processor device 202 is configured to execute instructions 310-1 of the flow dynamics model 310 stored in the memory 204.

[0051] In some embodiments, for example, the flow dynamics model 310 can model the fluid flow through a fluid circulation-loop network 105 for example, where each borehole portion of the flow conducting network network 105 is configured in "parallel" and rate of flow of lixiviant-derived flow through each borehole portion is uniform. In some embodiments, for example, a deviation in sensed rate of flow of lixiviant-derived flow between borehole portions of the flow conducting network 105 can be due to erosion in a borehole portion of the flow conducting network 105, or another factor that affects the flow behavior through a wellbore. .

[0052] In response to a predicted deviation in the rate of flow 320 of lixiviant- derived flow across one or more borehole portions of the flow conducting network 105, a flow conducting network modification 330 can be evaluated in order to modify at least one of a rate of flow of a first lixiviant-based flow in a first borehole portion of the flow conducting network 105 or a rate of flow of a second lixiviantbased flow in a second borehole portion of the flow conducting network 105. In some embodiments, for example, a flow conducting network modification 330 can include altering a flow conducting behavior of the flow conducting network 105 or altering a geometry of the flow conducting network 105. In examples, altering a geometry of the flow conducting network 105 can include altering a shape of the first borehole portion 122 or the second borehole portion 124 of the flow conducting network 105, altering a diameter of the first borehole portion 122 or the second borehole portion 124 of the flow conducting network 105, establishing an additional flow conducting channel in the flow conducting network 105 or establishing an additional flow conducting pathway in the flow conducting network 105, among others. Advantageously, maintaining a uniform flow behavior through each borehole portion of a flow conducting network 105 can help to ensure uniform extraction of the natural resource material throughout the subterranean formation 108. Example flow conducting network modification 330 blocks are further described in FIG.s 4A-4D.

[0053] In examples, the flow conducting network modification 330 can be input to the flow dynamics model 310 to evaluate the effect of the flow conducting modification 330 on the predicted flow dynamics for each borehole portion of the flow conducting network (e.g. predicted rate of flow of the first lixiviant-derived flow, predicted rate of flow of the second lixiviant-derived flow, the predicted deviation in rate of flow 320, etc.). Flow conducting network modifications 330 can be iteratively provided to the flow dynamics model 310 and evaluated by the flow dynamics model 310 until a tuned flow conducting network design 340 is obtained that includes a borehole portion geometry for the flow conducting network 105 that equalizes the rate of flow across each borehole portion.

[0054] FIG. 3B is a block diagram of an example flow conducting network tuning system 350 of the present disclosure. In some embodiments, after a flow conducting network 105 is designed and drilled, a lixiviant can be injected into a flow receiving communicator 102 and conduction of lixiviant-derived flow through the flow conducting network 105 can be monitored using, for example, the flow conducting network tuning system 350.

[0055] In some embodiments, the flow conducting network tuning system 350 can receive as an input, one or more lixiviant-derived flow measurements 306 representing a rate of flow or a flow profile of lixiviant-derived flow in the flow conducting network 105. In examples, a sensed rate of flow of a first lixiviant- derived flow and a second lixiviant-derived flow can be compared 360 and a sensed deviation in the rate of flow 370 between the first lixiviant-derived flow and the second lixiviant-derived flow can be input to the flow dynamics model 310 of the flow conducting network design system 300 as described with respect to FIG. 3A. The flow dynamics model 310 can also receive as input, information gathered during the drilling of the flow conducting network 105 representative of the drilled borehole portion geometry 304 for each borehole portion of the flow conducting network 105 and optionally can receive one or more borehole measurements 308 representing a current size of a borehole portion of the flow conducting network 105. In this regard, the flow dynamics model 310 can use the lixiviant-derived flow measurements 306 and optionally can also use the one or more borehole measurements 308 to update the model to account for changes in one or more wellbore properties that can affect the fluid flow behavior across the flow conducting network 105. For example, the flow dynamics model 310 can be updated to reflect errors in logged drilling surveys, variations in flow due to differing pump rates and pressures across the borehole portions, variations in caliper gauge measurements indicating wellbore erosion etc. The flow dynamics model 310 can be a software that is implemented in the computing system 200 of FIG. 2, in which the processor device 202 is configured to execute instructions 310- I of the flow dynamics model 310 stored in the memory 204.

[0056] In some embodiments, for example, the lixiviant-derived flow measurements 306 can be measured by sensors 208, for example, one or more pressure sensors installed at or in proximity to the entry point and the exit point of one or more borehole portions, one or more flow sensors, for example, impellerbased flow sensors or Coriolis-based flow sensors installed in one or more borehole portions, or other sensors. In other embodiments, for example, radioactive isotopes can be injected into the flow conducting network 105 and can be measured in the produced leachate to evaluate lixiviant-derived flow in one or more borehole portions. Optionally, one or more borehole measurements 308 can include measuring a wellbore profile using a caliper gauge tool or another measurement tool to monitor the erosion and geomechanical properties of one or more borehole portions in the flow conducting network 105.

[0057] Optionally, based on the sensed deviation in the rate of flow 370, the geometry of the flow conducting network may not be altered, and instead the rate of flow of the lixiviant into the flow receiving communicator can be reduced. In examples, it may be more cost effective to reduce the total flow rate of lixiviant- derived flow through the flow conducting network 105 for a period of time in order to increase the saturation of the natural resource material in the recovered leachate flow, than to alter the geometry of the flow conducting network 105. In examples, a cost analysis can be performed to evaluate the cost of producing the recovered leachate flow at the surface at the reduced rate of flow of the lixiviant into the flow receiving communicator, compared to the cost of altering the geometry of the flow conducting network. In examples, the cost analysis can determine a period of time after which it can be more cost effective to alter the geometry of the flow conducting network, with effect that the rate of flow of at least one of the first lixiviant-derived flow or the second lixiviant-derived flow is altered.

[0058] Example embodiments of flow conducting network modification blocks 330 for tuning a flow conducting network 105 are now provided with respect to FIG.s 4A-4D.

[0059] FIG. 4A is an example flow conducting network modification block 330 of adding a tuning length 402 to a borehole portion of the flow conducting network 105, in accordance with example implementations described herein. In the example embodiment, a tuning length 402 representing a multilateral well segment extending off of a first or second borehole portion of the flow conducting network 105 (for example, child well 125a or child well 125b) can be drilled to provide an additional flow path 404 for lixiant-derived flow through the borehole portion. In examples, adding a tuning length 402 may have the effect of altering the rate of flow of lixiviant-derived flow in the borehole portion. In examples, the tuning length 402 can be added to the borehole portion after the borehole portion has already been drilled. In some embodiments, for example, the tuning length 402 can be drilled with a well diameter that is different from the well diameter of the borehole portion, or alternately the well diameter of the tuning length 402 can be equal to the well diameter of the borehole portion. In some embodiments, the tuning length 404 can be drilled at any location along the borehole portion.

[0060] FIG. 4B is an example flow conducting network modification block 330 of executing a change in borehole diameter during drilling of a borehole portion of the flow conducting network 105, in accordance with example implementations described herein. In the example embodiment, a change in borehole diameter can be executed during drilling of a child well pair, for example, when drilling child well 125a or child well 125b, or a change in borehole diameter can be executed when the child well pair is connected toe-to-toe at a toe region connection point 128 to form the first borehole portion 122 or the second borehole portion 124. In examples, executing a change in borehole diameter may have the effect of altering the rate of flow of lixiviant-derived flow in the borehole portion. In some embodiments, for example, the change in borehole diameter can represent an abrupt change in borehole diameter 408 or can represent a gradual change in borehole diameter 410, among others. In examples, the change in borehole diameter can occur at any point along the borehole portion.

[0061] FIG. 4C is an example flow conducting network modification block 330 of adding one or more flow channels 412 to a borehole portion, for example, a secondary fluid circulation-loop 124, in accordance with example implementations described herein. In the example embodiment, one or more flow channels 412 can be added to connect the wells of a well pair forming a first or second borehole portion of the flow conducting network 105, for example, child wells 125a and 125b. In some embodiments, for example, the one or more flow channels 412 can be drilled using an ultra-short radius directional drilling tool. In other embodiments, for example, treatment fluid can be injected through the flow conducting network 105 such that hydraulic fracturing of the subterranean formation 108 is effectuated, with effect that the additional flow conducting pathway becomes emplaced within the flow conducting network. In examples, hydraulic fracturing may have the effect of generating significant connectivity in the borehole portion while maintaining wellbore integrity. In examples, adding one or more flow channels 412 may have the effect of altering the rate of flow of lixiviant-derived flow in the borehole portion. In some embodiments, the one or more flow channels 412 can be added at any location along the borehole portion.

[0062] FIG. 4D is an example flow conducting network modification block 330 wherein the modifying includes supplying energy to the lixiviant-derived fluid material being conducted through the flow conducting network 105, in accordance with example implementations described herein. In examples, supplying energy to the lixiviant-derived fluid material may have the effect that modification is effectuated to at least one of: (i) rate of flow of lixiviant-derived fluid material being conducted through first borehole portion 122, or (ii) the rate of flow of lixiviant- derived fluid material being conducted through the second borehole portion 124. In examples, supplying energy to the lixiviant-derived fluid material can include installing a fluid pulsating tool 414 in the first borehole portion 122 or the second borehole portion 124 of the flow conducting network 105, and while the lixiviant- derived fluid material is being conducted through the flow conducting network 105, operating the fluid pulsating tool 414. In the example embodiment, a pulsating device 414 can generate a pulsating jet stream of fluid at the outlet 416 of the pulsating device 414. In examples, inserting a fluid pulsating device 414 into a wellbore of the first borehole portion 122 or the second borehole portion 124 can, for example, alter the rate of flow of lixiviant-derived flow in the borehole portion. In some embodiments, for example, the pulsating device 414 can create two step changes in wellbore diameter. In examples, fluid can enter the pulsating device 414 at an inlet 418 with a first narrowing 420, and flow through to an interior cavity 422 with a wider diameter 424, forming vortices 426 in the interior cavity 422. In examples, the vortices 426 can induce oscillatory motion of the fluid upon exiting the device through the outlet 416. In examples, inserting a fluid pulsating device 414 into a wellbore of the flow conducting network 105 represents a reactive approach to altering flow properties compared to resistive approaches described in previous embodiments. In other embodiments, for example, flow conducting network modification block 330 generating a similar flow behavior in a wellbore of the flow conducting network 105 can be created by shaping the wellbore to create step changes in diameter using cutting or jetting methods. In examples, the insertion of the pulsating device 414 can occur at any point along the borehole portion.

[0063] Example implementations of methods for extracting a natural resource material will now be described, with reference to the flow conducting network tuning system 350 executed by the example computing system 200 in co-operation with the solution mining system 100b.

[0064] FIG. 5 is a flowchart showing operations of a method 500 for solution mining an natural resource material, in accordance with examples of the present disclosure. The method 500 can be performed in the context of the components of the multilateral solution mining system 100b shown in FIG. IB in some embodiments.

[0065] Method 500 begins at step 502 in which a lixiviant is injected into flow conducting network 105 established within a subterranean formation 108 via a flow receiving communicator 102 of the flow conducting network 105, the flow receiving communicator 102 being disposed at the earth's surface 106 and extending into the subterranean formation 108.

[0066] At step 504, a natural resource material is leached from the subterranean formation 108, with effect that the recovered leachate flow is discharged from the flow conducting network 105 via a flow discharging communicator 104 of the flow conducting network 105, and recovered leachate flow is produced at the surface 106..

[0067] At step 506, the leaching of step 504 includes leaching a first natural resource material in response to emplacement of a first lixiviant-derived flow in communication with the first natural resource material source while being conducted through a first borehole portion 122 of the flow conducting network 105..

[0068] At step 508, the leaching of step 504 further includes leaching a second natural resource material in response to emplacement of a second lixiviant- derived flow in communication with the second natural resource material source while being conducted through a second borehole portion 124 of the flow conducting network 105. In examples, the first borehole portion 122 and the second borehole portion 124 are conducted in parallel.

[0069] At steps 510 and 512, a rate of flow of the first lixiviant-derived flow and a rate of flow of the second lixiviant-derived flow are sensed by sensors 208 within the flow conducting network 105. In examples, sensors 208 can include one or more pressure sensors installed at or in proximity to the entry point and the exit point of one or more borehole portions of the flow conducting network 105, one or more flow sensors, for example, impeller-based flow sensors or Coriolis-based flow sensors installed in one or more borehole portions, or other sensors. In other embodiments, for example, radioactive isotopes can be injected into the flow conducting network 105 and can be measured in the produced leachate to evaluate lixiviant-derived flow in one or more borehole portions.

[0070] At step 514, the sensed rate of flow of the first lixiviant-derived flow and the second lixiviant-derived flow can be compared.

[0071] Optionally, at step 516, based on the comparing of step 514, determining whether the sensed rate of flow of the first lixiviant-derived flow deviates from the sensed rate of flow of the second lixiviant-derived flow by more than a pre-determined amount.

[0072] Optionally, at step 518, in response to the determination of the deviation of step 516, the flow conducting network 105 can be modified with effect that modification is effectuated to at least one of: (i) the rate of flow of the first lixiviant-derived flow, or (ii) the rate of flow of the second lixiviant-derived flow.

General

[0073] Although the present disclosure describes functions performed by certain components and physical entities, it should be understood that, in a distributed system, some or all of the processes can be distributed among multiple components and entities, and multiple instances of the processes can be carried out over the distributed system.

[0074] Although the present disclosure describes methods and processes with steps in a certain order, one or more steps of the methods and processes can be omitted or altered as appropriate. One or more steps can take place in an order other than that in which they are described, as appropriate.

[0075] Although the present disclosure is described, at least in part, in terms of methods, a person of ordinary skill in the art will understand that the present disclosure is also directed to the various components for performing at least some of the aspects and features of the described methods, either by way of hardware components, software or any combination of the two. Accordingly, the technical solution of the present disclosure can be embodied in the form of a software product. A suitable software product can be stored in a pre-recorded storage device or other similar non-volatile or non-transitory computer readable medium, including DVDs, CD-ROMs, USB flash disk, a removable hard disk, or other storage media, for example. The software product includes instructions tangibly stored thereon that enable a processing device (e.g., a personal computer, a server, or a network device) to execute examples of the methods disclosed herein. In general, the software improves the operation of the hardware in one or more ways.

[0076] The present disclosure can be embodied in other specific forms without departing from the subject matter of the claims. The described example implementations are to be considered in all respects as being only illustrative and not restrictive. Selected features from one or more of the above-described implementations can be combined to create alternative implementations not explicitly described, features suitable for such combinations being understood within the scope of this disclosure.

[0077] All values and sub-ranges within disclosed ranges are also disclosed. Also, although the systems, devices and processes disclosed and shown herein can include a specific number of elements/components, the systems, devices and assemblies could be modified to include additional or fewer of such elements/components. For example, although any of the elements/components disclosed can be referenced as being singular, the implementations disclosed herein could be modified to include a plurality of such elements/components. The subject matter described herein intends to cover and embrace all suitable changes in technology.