CA3130384C

CA3130384C - System, method, and medium for optimizing system design for extraction of hydrocarbon material

Info

Publication number: CA3130384C
Application number: CA3130384A
Authority: CA
Inventors: Hossein Aghabarati
Original assignee: Suncor Energy Inc
Current assignee: Suncor Energy Inc
Priority date: 2021-09-10
Filing date: 2021-09-10
Publication date: 2024-04-02
Anticipated expiration: 2041-09-10
Also published as: CA3130384A1

Abstract

There are provided systems, methods, and processor-readable media for optimizing system design for extraction of hydrocarbon material and constructing said systems. Reservoir data, indicating one or more characteristics of a subterranean formation, is gathered while drilling a wellbore for a well of the system. The reservoir data is used to generate a geological model, which is used to generate a system design. The system design is then used to construct the remaining parts of the system, such as an updated drill path for the current wellbore, and/or well placements or completions for the current well and/or one or more additional wells of the system. An economic value can be computed based on the system design, and the system can be abandoned if the economic value fails to satisfy a test or threshold.

Description

SYSTEM, METHOD, AND MEDIUM FOR OPTIMIZING SYSTEM DESIGN FOR
EXTRACTION OF HYDROCARBON MATERIAL
FIELD
[0001] The present disclosure relates to optimizing hydrocarbon extraction, and in particular to systems, methods, and processor-readable media for optimizing the design of hydrocarbon material production systems.
BACKGROUND

[0002] Extraction of hydrocarbon material from a subterranean formation (such as a reservoir of liquid hydrocarbon material, a formation of hydrocarbon-rich ore, or a deposit of hydrocarbon-rich gas) often involves drilling one or more wellbores into the formation, installing a completion into each wellbore to form a completed well, and using the one or more wells to produce the hydrocarbon -- material. Some techniques use pairs of wells to produce the hydrocarbon material:
an injection well can be used to inject a stimulation fluid (liquid and/or gas) into the formation, and a production well can be used to extract the hydrocarbon material from the formation, which is stimulated by the injection of the stimulation fluid. In some embodiments, a single production well or more than two wells may be used.

[0003] A single hydrocarbon production system can therefore include multiple wells drilled into a single subterranean formation. A system designed to extract hydrocarbon material from a single formation can include one or more production wells, and optionally one or more injection wells. Furthermore, a system designed to extract hydrocarbon material from a single formation can proceed by first drilling production and/or injection wells during a first phase, and later drill additional infill wells located between pairs of existing wells to further increase the production of the hydrocarbon material.

[0004] Typically, such a system is designed in advance based on an initial geological model or other information pertaining to the subterranean formation. The -- design of the system can specify design information such as a well placement for Date Recue/Date Received 2023-11-17 each well (i.e. a drill path for the wellbore of each well), and/or a completion for each well. However, geological models prepared prior to constructing and operating the system (i.e., drilling the wellbores, completing the drilled wells, and operating the completed wells) are based on initial interpretations and might be inaccurate, and the system design premised on those models might not operate as expected.

[0005] Accordingly, it would be useful to provide techniques for optimizing system design for hydrocarbon material extraction in real time.
SUMMARY

[0006] The present disclosure describes systems, methods, and processor-readable media for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation. A wellbore is drilled along a drill path. While the drilling is being effected along the drill path, reservoir data is obtained from the subterranean formation. The reservoir data is representative of one or more characteristics of the subterranean formation. The reservoir data is processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. The generation of the system design is based on at least a reservoir fluid production measure. The generated system design includes definition of a placement of the well. The drill path is altered based on the generated system design. In some implementations, an economic value can be computed based on the generated system design, and the current drilling operation is suspended if the economic value fails to satisfy a .. test or threshold. In some implementations, the wellbore being drilled is one well of a well pair (i.e. an injection well and complementary production well), the generated system design includes definition of a placement of the wellbore of a one of the injection well and the production well, and the method further includes drilling a second wellbore for the other one of the injection well and the production well. In some implementations, the wellbore being drilled is an infill well, and the Date Recue/Date Received 2021-09-10 wellbore of the infill well is drilled after producing hydrocarbon material from the reservoir of the subterranean formation during a first time interval with an early stage hydrocarbon production system. In some implementations, one or more further models, such as machine learning models or simulations, can be used to generate the system design based on the reservoir data-defined geological model.

[0007] As used herein, statements that a second item (e.g., a value, calculation, or determination) 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.

[0008] As used herein, the term "characteristic" as applied to a subterranean formation can refer to any geological, physical, structural, spatial, or environmental property of a subterranean formation of hydrocarbon material or its geological environment, including the layers of earth above and around it.

[0009] In some aspects, the present disclosure describes a method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation. The method comprises a number of steps. The wellbore is drilled along a drill path. While the drilling is being effected along the drill path, reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. The reservoir data is processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. The generation of the system design is based on at least a reservoir fluid production measure. The generated system design includes definition of a placement of the well. The drill path is altered based on the generated system design.

[0010] Thus, the drill path of a wellbore can be revised in real time during the drilling operation based on reservoir data obtained during the drilling operation.
Date Recue/Date Received 2021-09-10 This can prevent costly delays or the need to construct additional wells in light of new or unexpected geological data uncovered during drilling or operation, and can improve the performance and/or decrease the cost and time required to construct the system.

[0011] In some aspects, the present disclosure describes a method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation. The method comprises a number of steps. The wellbore is drilled.
While the drilling is being effected, reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. The reservoir data is processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. An economic value is calculated based on the generated system design. It is determined whether the economic value satisfies an economic metric.

[0012] Thus, the economic viability of the updated system can be assessed in light of the new reservoir data obtained during drilling, and a decision can be made to continue or abandon the well currently being drilled. This can prevent resources from being spent on a well that is not optimally placed relative to the subterranean formation, and can improve the performance and/or decrease the cost and time required to construct the system.

[0013] In some aspects, the present disclosure describes a method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well. The method comprises a number of steps. A
wellbore of a one of the injection well and the production well is drilled along a first drill path. While the drilling of a wellbore, of a one of the injection well and the production well, is being effected, a first set of reservoir data representative of one .. or more characteristics of the subterranean formation is obtained from the Date Recue/Date Received 2021-09-10 subterranean formation. The reservoir data is processed to define a geological model of the subterranean formation, such that a first reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. The generated system design includes definition of a placement of the wellbore of a one of the injection well and the production well. Where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the injection well, the definition of placement of the well is a definition of placement of the injection well, such that the generated system design includes the definition of a placement of the injection well. Where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the production well, the definition of placement of the well is a definition of placement of the production well, such that the generated system design includes the definition of a placement of the production well. Based on the generated system design, the first .. drill path, along which the drilling of the wellbore, of a one of the injection well and the production well, is being effected, is altered. Where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the injection well, the altering of the first drill path is an altering of the first drill path of the wellbore of the injection well. Where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the production well, the altering of the first drill path is an altering of the first drill path of the wellbore of the production well. After completing of the drilling of the wellbore of a one of the injection well and the production well, a wellbore of the other one of the injection well and the production well is drilled along a second drill path.

[0014] Thus, the drilling of a first well of an injector-producer well pair can result in LWD data that can be used to update the design of the second well of the well pair. This can improve the cooperation of the two wells of the well pair, and can improve the performance and/or decrease the cost and time required to construct the system.
Date Recue/Date Received 2021-09-10

[0015] In some aspects, the present disclosure describes a method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well. The method comprises a number of steps. A
wellbore of a one of the injection well and the production well is drilled.
While the drilling of a wellbore, of a one of the injection well and the production well, is being effected, a first set of reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation.
After completing the drilling of a wellbore of a one of the injection well and the production well, a wellbore of the other one of the injection well and the production well is drilled along a drill path. While the drilling of a wellbore, of the other one of the injection well and the production well, is being effected, a second set of reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. The first and second sets of reservoir data are processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained.
Based on the reservoir date-defined geological model, a system design for the hydrocarbon production system is generated. The generated system design includes definition of a placement of the wellbore of the other one of the injection well and the production well. Where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the injection well, the definition of placement of the well is a definition of placement of the injection well, such that the generated system design includes the definition of a placement of the injection well. Where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the production well, the definition of placement of the well is a definition of placement of the production well, such that the generated system design includes the definition of a placement of the production well. Based on the generated system design, the drill path, along which the drilling of the wellbore, of the other one of the injection well and the production well, is being effected, is altered. Where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling Date Recue/Date Received 2021-09-10 of a wellbore of the injection well, the altering of the first drill path is an altering of the drill path of the wellbore of the injection well. Where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the production well, the altering of the first drill path is an altering of the drill path of the wellbore of the production well.

[0016] Thus, further improvements can be realized in updating the complementary designs of both wells of the well pair, thereby potentially further improving cooperation between the wells of the well pair.

[0017] In some aspects, the present disclosure describes a method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well. The method comprises a number of steps. A
wellbore of a one of the injection well and the production well is drilled.
While the drilling of a wellbore, of a one of the injection well and the production well, is being effected, a first set of reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. A
wellbore of the other one of the injection well and the production well is drilled.
While the drilling of a wellbore, of the other one of the injection well and the production well, is being effected, a second set of reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. The first and second sets of reservoir data are processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. The generated system design includes definition of a completion design.
After the drilling of the wellbore of the other one of the injection well and the production well, a completion is installed relative to the wellbore of the injection well. A completion relative to the wellbore of the production well is installed. Where the generated system design includes definition of a completion design of the injection well, the completion installed relative the wellbore of the injection well is Date Recue/Date Received 2021-09-10 based on the completion design defined by the generated system design. Where the generated system design includes definition of a completion design of the production well, the completion installed relative to the wellbore of the production well is based on the completion design defined by the generated system design.

[0018] In some aspects, the present disclosure describes a method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well. The method comprises a number of steps. A
wellbore of one of the injection well and the production well is drilled.
While the drilling of a wellbore, of a one of the injection well and the production well, is being effected, a first set of reservoir data, representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation.
After completing of the drilling of a wellbore of one of the injection well and the production well, a wellbore of the other one of the injection well and the production .. well is drilled. While the drilling of a wellbore of the other one of the injection well and the production well is being effected, a second set of reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. The first and second sets of reservoir data are processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. An economic value based on the generated system design is computed. It is determined whether the economic value satisfies an economic metric.

[0019] In some aspects, the present disclosure describes a method for producing hydrocarbon material from a reservoir of a subterranean formation during a first time interval, with effect that residual hydrocarbon material remains within the reservoir after the first time interval, and constructing an infill well for producing the residual hydrocarbon. The method comprises a number of steps.
Hydrocarbon material is produced from the reservoir of the subterranean formation Date Recue/Date Received 2021-09-10 during the first time interval with an early stage hydrocarbon production system.
After the first time interval, a wellbore of the infill well is drilled along a drill path.
While the drilling of the wellbore of the infill well is being effected along the drill path, reservoir data representative of one or more characteristics of the subterranean formation is obtained from the subterranean formation. The reservoir data is processed to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained. Based on the reservoir data-defined geological model, a system design for the hydrocarbon production system is generated. The generated system design includes definition of a placement of the well. The drill path is altered based on the generated design.

[0020] Thus, an infill well of the system is designed based on at least in part on production of hydrocarbon material from the early stage system. This can improve the performance and/or decrease the cost and time required to construct the system.
BRIEF DESCRIPTION OF THE DRAWINGS

[0021] Reference will now be made, by way of example, to the accompanying drawings which show example implementations of the present application, and in which:

[0022] FIG. 1 is a schematic illustration of a first implementation of a system for extraction of hydrocarbon material from a subterranean formation, including a well;

[0023] FIG. 1A is a schematic illustration of a second implementation of a system for extraction of hydrocarbon material from a subterranean formation, including an injection well, a production well;

[0024] FIG. 1B is a schematic illustration of a third implementation of a system for extraction of hydrocarbon material from a subterranean formation, including an injection well a production well of an early stage hydrocarbon production system, and an infill well;
Date Recue/Date Received 2021-09-10

[0025] FIG. 1C is a schematic illustration of a fourth implementation of a system for extraction of hydrocarbon material from a subterranean formation, including two early stage hydrocarbon production systems, each having an injection well and production well, and an infill well;

[0026] FIG. 2 is a block diagram of an example computing system suitable for implementing examples described herein;

[0027] FIG. 3 is a block diagram of an example system design module, in accordance with example implementations described herein;

[0028] FIG. 4 is a flowchart showing operations of a first example method for constructing a system for producing hydrocarbon materials from a subterranean formation, in accordance with example implementations described herein;

[0029] FIG. 5 is a flowchart showing operations of a second example method for constructing a system for producing hydrocarbon materials from a subterranean formation, in accordance with example implementations described herein;

[0030] FIG. 6 is a flowchart showing operations of a third example method for constructing a system for producing hydrocarbon materials from a subterranean formation, in accordance with example implementations described herein; and

[0031] FIG. 6A is a flowchart showing an example of a second stage of the third example method of FIG. 6, in accordance with example implementations described herein;

[0032] FIG. 6B is a flowchart showing operations of a fourth example method for constructing a system for producing hydrocarbon materials from a subterranean formation, in accordance with example implementations described herein.

[0033] FIG. 7 is a flowchart showing operations of a fifth example method for constructing a system for producing hydrocarbon materials from a subterranean formation, in accordance with example implementations described herein.

[0034] Similar reference numerals can have been used in different figures to denote similar components.
Date Recue/Date Received 2021-09-10 DESCRIPTION OF EXAMPLE IMPLEMENTATIONS

[0035] The present disclosure describes systems, methods, and processor-readable media for constructing a system for producing hydrocarbon materials from a reservoir of a subterranean formation via a well extending into the subterranean formation. In some embodiments, for example, the hydrocarbon reservoir is an oil sands reservoir. In some embodiments, for example, the hydrocarbon reservoir is a heavy oil reservoir.

[0036] To construct the well, a wellbore is drilled into the subterranean formation in accordance with a drill path. While the drilling is being effected, reservoir data, representative of one or more characteristics of the subterranean formation, is obtained from the subterranean formation. The collection of this data includes collection of logging while drilling (LWD) data with a LWD tool, and also includes collection of measurement while drilling (MWD) data with a MWD tool.
The reservoir data is processed to define a geological model of the subterranean formation. In some embodiments, for example, the defining of a geological model is the updating of a pre-existing geological model. Based on the defined geological model, a system design for the hydrocarbon production system is generated. In some embodiments, for example, the generation of the system design is based upon at least a reservoir fluid production measure. Exemplary reservoir fluid production measures include one or more of: a rate of reservoir fluid production, a rate of hydrocarbon material production, a produced reservoir fluid composition, a steam-to-oil ratio of the production process, or any other measure of volume, quality, or efficiency of produced hydrocarbon material. The system design is used to dictate construction of the system for producing hydrocarbon material. In some embodiments, for example, the system design includes definition of placement of the well, such that drill path can be altered based on the defined well placement of the system design. In some embodiments, for example, the system design includes definition of completion design of the well, such that the completion installed within the drilled wellbore is based on the defined completion design of the system design.
Date Recue/Date Received 2021-09-10 In some embodiments, for example, the definition of completion design includes configuration and/or placement of one or more of flow control devices, liners, slotted liners, screens (or other sand control devices), blank sections, packers (or other fluidic isolation devices) and an artificial lift apparatus. In some of these embodiments, for example, the constructed well is an infill well. In some embodiments, for example, the data obtained during the drilling is used to compute an economic value based upon the updated hydrocarbon production system model, and the system can be abandoned if the economic value fails to satisfy an economic metric. Abandonment would occur prior to installing of a completion.

[0037] In some embodiments, the geological model can be updated based on a real time numerical reservoir model or analytical modeling. In some cases the geological model may be updated based on data analytics and/or live updates based on the historical production data of similar hydrocarbon extraction systems.

[0038] FIGS. 1, 1A, and 1B are schematic illustrations of exemplary embodiments of a system for performing in-situ hydrocarbon materials extraction from a reservoir 102 of the subterranean formation 101 using a hydrocarbon extraction technology.

[0039] Hydrocarbon material is a material that consists of a least one hydrocarbon compound. In some implementations, for example, the hydrocarbon material being produced includes, or is substantially, a liquid hydrocarbon material.
In some implementations, for example, the hydrocarbon material includes bitumen.
In some of these implementations, for example, the bitumen is a liquid hydrocarbon material with an API gravity less than, or equal to, ten (10), and with an in situ viscosity of greater than 10,000 centipoise. In some implementations, for example, the hydrocarbon material includes heavy oil.

[0040] In some implementations, for example, the hydrocarbon reservoir is an oil sands reservoir. In some implementations, for example, the hydrocarbon reservoir is a heavy oil reservoir.
Date Recue/Date Received 2021-09-10

[0041] In some implementations, for example, the hydrocarbon extraction technology is a production-stimulating fluid injection technology. The production-stimulating technology includes injecting of a production-stimulating fluid into the subterranean formation 102 for stimulating production of hydrocarbon material.

[0042] In some implementations, for example, the production-stimulating fluid is a fluid configured for co-operating with the hydrocarbon material within the subterranean formation 102 for stimulating the production of the hydrocarbon material via at least thermal stimulation (e.g. steam).

[0043] In some implementations, for example, the production-stimulating fluid is a fluid configured for co-operating with the hydrocarbon material within the subterranean formation 102 for stimulating the production of the hydrocarbon material via at least modulation of the flow characteristics of the hydrocarbon material, such as, for example, via viscosity reduction (e.g. steam, solvent).

[0044] In some implementations, for example, the production-stimulating fluid is a fluid configured for co-operating with the hydrocarbon material within the subterranean formation 102 for stimulating the production of the hydrocarbon material via at least chemical conversion of the hydrocarbon material (e.g.
fluid including bacteria).

[0045] In some implementations, for example, the production-stimulating fluid is a fluid configured for co-operating with the subterranean formation 102 for stimulating the production of the hydrocarbon material via at least modulation of the permeability of the subterranean formation (e.g. hydraulic fracturing fluid)

[0046] In some implementations, for example, the production-stimulating fluid is a fluid configured for co-operating with the subterranean formation 102 for stimulating the production of the hydrocarbon material via any combination of the mechanisms described above.

[0047] In some implementations, for example, the production-stimulating fluid injection technology is a displacement technology which produces hydrocarbon material from the reservoir by displacement of the hydrocarbon material in Date Recue/Date Received 2021-09-10 response to the injection of the production-stimulating fluid. Exemplary displacement technologies include steam assisted gravity drainage ("SAGD") technologies, expanding solvent - steam assisted gravity drainage ("ES-SAGD") technologies, waterflooding technologies, and other solvent based recovery methods using wellbore implementations.

[0048] Other suitable hydrocarbon extraction technologies can effectuate production of hydrocarbon material by transferring energy to the hydrocarbon material by means other than by injection of a production-stimulating fluid, such as, for example, by artificial lift, by electrical heating, or both.

[0049] In some implementations, for example, the hydrocarbon extraction technology includes any combination of the above-described technologies.

[0050] FIG. 1 illustrates system 100, where a single well 104 is provided for producing hydrocarbon material from the reservoir 102 of the subterranean formation 101. Exemplary hydrocarbon extraction technologies which could be implemented within the system 100 include hydraulic fracturing technologies and "huff and puff" technologies, and also include artificial lift technologies and electrical heating technologies.

[0051] FIG. 1A illustrates system 120, within which is implementable a hydrocarbon extraction technology that is a displacement process technology.
In this respect, the system 120 includes two wells 104, 106. Well 104 functions as an injection well, for injection of a production-initiating fluid for stimulating hydrocarbon material extraction from a subterranean formation 102, and well functions as a production well for producing the extracted hydrocarbon material to the surface 110.

[0052] FIG. 1B illustrates system 120B, which is a modification of system 120, in that an infill well 108 is constructed for producing residual hydrocarbon material which remains in the reservoir 102 after suspending hydrocarbon material production using the system 120 (in this respect, system 120 functions as an early stage hydrocarbon material production system). Hydrocarbon material is produced Date Recue/Date Received 2021-09-10 for a time interval using the system 120, until it becomes uneconomical to produce residual hydrocarbon material remaining within the reservoir 102. For example, in those embodiments where the system 120 is based upon a production-stimulating fluid injection technology, such as SAGD, it can become uneconomical to produce residual hydrocarbon material remaining within the reservoir 102 where the residual hydrocarbon material is located an excessive distance from the production well 106 such that sufficient hydrocarbon material is not extractable by displacement in response to injection of a stimulating fluid via the injection well 104. In such case, the infill well 108 is constructed in closer proximity to the residual hydrocarbon material so as to enable its production via the infill well 108, in response to injection of production-initiating fluid via one or both of wells 104 and 106.

[0053] FIG. 1C illustrates system 120C3, which includes an infill well 108 disposed between two early stage hydrocarbon material production systems 120C1 and 120C2. Each one of systems 120C1 and 120C2, independently, is a SAGD
system. System 120C1 includes a respective well pair (an injection well 104A
and a production well 106A), and system 120C2 includes a respective well pair (an injection well 104C and a production well 106D). Production stimulating fluid is injectable via one or more of the wells 104A, 106A, 104B, 106B, and producible via the infill well 108.

[0054] With respect to well 104 of the system 100, each one of the wells 104, 106 of the systems 120 and 120B, and the well 108 of the system 120B and the system 120C3, each one of these wells is constructed in stages. First, an initial well placement is specified for the well, based on a pre-existing model of the system 100. Based on this initial well placement, an initial drill path is determined, for planning the drilling of the wellbore of the well.

[0055] The reservoir data obtained during the drilling can include seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical Date Recue/Date Received 2021-09-10 well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and/or gas properties. The drilling operation is performed by a drilling apparatus 211.

[0056] The drilling apparatus can include a logging while drilling (LWD) tool 208 and/or a measurement while drilling (MWD) tool 209. MWD refers to directional-drilling measurements, e.g., for decision support for the smooth operation of the drilling, whereas LWD refers to measurements concerning the subterranean formation 102 made while drilling. When the drilling apparatus 211 is drilling the wellbore, the LWD tool 208 collects LWD data based on surface and/or downhole sensors, such as seismic sensors, temperature sensors, electrical resistivity sensors, pressure sensors, chemical sensors and/or other sensors or monitoring devices configured to gather data from the wellbore and/or the drilling apparatus.

[0057] In addition to the LWD data, additional reservoir data can be collected, such as MWD data with the MWD tool 209, laboratory data, and/or other reservoir data representative of one or more characteristics of the subterranean formation 102. The reservoir data can includes data representative of one or more characteristics of the subterranean formation 102, such as seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, gas saturation, water saturation, salinity, data indicating the presence of mud, and/or additional data obtained while drilling pertaining to the subterranean formation and/or its environment, as described above.

[0058] After the drilling operation is completed, a completion can be customized and installed into the drilled wellbore. The design of the completion can be dictated by the generated system design. The installation of the completion into the drilled wellbore can be referred to as "completing" the well. Exemplary components of a completion include flow control devices (FCDs), slotted liners, Date Recue/Date Received 2021-09-10 screens (or other sand control devices), blank sections, packers (or other fluidic isolation devices) and an artificial lift apparatus.

[0059] FCDs include Inflow Control Devices (ICDs), Inflow Control Valves (ICVs), and Autonomous Inflow Control Devices (AICDs).

[0060] "Artificial lift apparatus" refers to any apparatus or process used to lower the producing bottomhole pressure (BHP) on the formation to obtain a higher production rate from the production well. An artificial lift apparatus can include, for example, a sucker-rod (beam) pumping apparatus, an electrical submersible pumping (ESP) apparatus, a gas lift or intermittent gas lift apparatus, a reciprocating or jet hydraulic pumping system, a plunger lift apparatus, a progressive cavity pump (PCP), an electrical submersible progressive cavity pump (ESPCP), a continuous belt transportation apparatus, or a combination thereof.
An artificial lift apparatus can be emplaced relative to the drilled wellbore such that hydrocarbon material from the reservoir is displaceable by the artificial lift apparatus to the surface. In some embodiments, for example, the artificial lift apparatus is emplaced within the drilled wellbore.

[0061] A system design for each one of systems 100, 120, and 120A, independently, defines design specifications for construction of the respective hydrocarbon production system for producing hydrocarbon material from the reservoir 102 of the subterranean formation 101. In this respect, design specifications, which are defined by the system design, include definition of well placement of the one or more wells, and definition of completion design of the one or more wells. The system design can also includes specification of operational constraints, which can include specification of injection fluids, and their rate of injection, as well as specification of production fluids, and their rate of production.

[0062] The operations of example methods for constructing a system for producing hydrocarbon material are described with reference to an example computing system executing an example system design module, defined by processor-readable instructions stored on a non-transitory computer readable Date Recue/Date Received 2021-09-10 medium, to optimize the system design and construct the system according to the optimized system design.

[0063] FIG. 2 is a block diagram of an example computing system 200 including computing hardware suitable for generating a system design for the hydrocarbon production system, based on the defined geological model. 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.

[0064] 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.

[0065] The computing system 200 can include one or more network interfaces (collectively referred to as network interface 210) for wired or wireless communication over a network. The network interface 210 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 206 (such as user workstation computers) and/or one or more LWD tools 208 and/or MWD
tools 209 (and/or other reservoir data collection devices) via the network interface 210. The computing system 200 can also communicate with a drilling apparatus 211 via the network interface 210 to control the drilling operation of the drilling apparatus 211. In some examples, the user devices 206, LWD tools 208, MWD
tools Date Recue/Date Received 2021-09-10 209, and/or drilling apparatus 211 can communicate with the computing system 200 through other means, such as an input/output interface of the computing system 200 (not shown) or through an intermediate device in communication with the computing system 200.

[0066] The computing system 200 can include one or more non-transitory memories (referred to collectively as a memory 214), 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 214 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.

[0067] The memory 214 can store instructions for execution by the processor device 202 to carry out examples described in the present disclosure. The instructions can include instructions for implementing and operating the system design module 300 described below with reference to FIG. 3. The memory 214 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.

[0068] The memory 214 can store data and models used by the system design module 300. Reservoir data 222, such as LWD data generated by and received from the LWD tools 208, can be stored in the memory. Models used by the system design module 300 (as described below with reference to FIG. 3) can be considered to be stored in the memory 214 as part of the system design module 300. An initial geological model 224 can be stored in the memory 214 prior to beginning the drilling operation. A pre-existing system design 230 can be stored in Date Recue/Date Received 2021-09-10 the memory 214, including, e.g., a first well design 232 for a first well of the system (including, e.g., well placement 234 and/or completion design 236for the first well, as described above) and a second well design 242 for a second well of the system (including, e.g., well placement 244 and/or completion design 246for the second well). During execution by the processor 202, the system design module 300 can generate an updated geological model 224 and/or an generated system design 250 and store this updated information in the memory 214. The generated system design 250 include, e.g., an updated first well design 252 for the first well (including, e.g., well placement 254 and/or completion design 256f0r the first well) .. and an updated second well design 242 for the second well (including, e.g., well placement 264 and/or completion design 266f0r the second well).

[0069] The computing system 200 can also include a bus 216 providing communication among components of the computing system 200, including those components discussed above. The bus 216 can be any suitable bus architecture .. including, for example, a memory bus, a peripheral bus or a video bus, or the bus 216 can be another communication link such as a network interface 210.

[0070] FIG. 3 illustrates an example system design module 300. The system design module 300 is executed by a computing system 200 to perform the methods and operations described herein. The system design module 300 includes a number of sub-modules 302, 304, 306, 308, 310 as described below. It will be appreciated that some implementations can omit one or more of the described submodules and/or can combine the functions of two or more of the described submodules into a single submodule.

[0071] In some implementations, the system design module 300 operates to .. optimize the design of a system 100 and implement the updated system design by constructing the system 100 according to the updated system design. A pre-existing system design 230, generated based on an initial geological model 224, can indicate a well placement for a first well. Reservoir data 222 can be collected during a first stage of a drilling operation to drill the wellbore for the first well, .. using a drill path for the first drilling stage determined based on the well placement Date Recue/Date Received 2021-09-10 for the first well. The reservoir data 222 can be used by a geological model update submodule 302 to generate a reservoir data-defined geological model 226 based on the initial geological model 224. A hydrocarbon production prediction submodule 304 can be used to generate prediction data 314 representative of a predicted reservoir fluid production measure, i.e. a measure of an amount of hydrocarbon material predicted to be produced by the system 100 based on the pre-existing system design 230 and the reservoir data-defined geological model 226. In some embodiments, the prediction data 314 is representative of a different measure of performance of the system 100. An economic value submodule 306 can compute an economic value 316 of the pre-existing system design 230 based on the prediction data 314. Using the prediction data 314 and/or economic value 316 as inputs, a system redesign submodule 308 can operate to generate a proposed system design 340, based on the pre-existing system design 230, intended to optimize the prediction data 314 and/or economic value 316.

[0072] In some implementations, the system redesign submodule 308 operates iteratively in cooperation with the hydrocarbon production prediction submodule 304 and/or the economic value submodule 306 to continue generating new proposed system designs 340 until an optimal proposed system design 340 is identified. Each proposed system design 340 is provided to the hydrocarbon production prediction submodule 304 and/or the economic value submodule 306 to generate new prediction data 314 and/or a new economic value 316, respectively.
The system redesign submodule 308 can continue generating new proposed system designs 340 using the new prediction data 314 and/or new economic value 316 as feedback until a proposed system design 340 is generated that optimizes the prediction data 314 and/or the economic value 316. The system redesign submodule 308 then outputs the optimized proposed system design 340 as the generated system design 250. In other implementations, the system redesign submodule 308 is configured to generate the generated system design 250 in a single iteration.
Date Recue/Date Received 2021-09-10

[0073] A system implementation submodule 310 can implement the generated system design 250, i.e., control the construction of at least a portion of the system 100 according to the generated system design 250. For example, a drilling implementation sub-submodule 322 of the system implementation submodule 310 can control the drilling operation of each well indicated by the generated system design 250. In some implementations, the drilling implementation sub-submodule 322 can be used to control the drilling operation of the first well after the first drilling stage has been completed. The generated system design 250 can indicate an altered or updated drill path for the first well.
The drilling implementation sub-submodule 322 can then perform a second drilling stage of the drilling of the wellbore for the first well, according to the altered or updated drill path for the first well. In some implementations, drilling operations performed by the drilling implementation sub-submodule 322 can result in further reservoir data 222 being obtained; the new reservoir data 222 can be provided to the geological model update submodule 302 to generate a further generated system design 250, which can result in changes to the operations of the system implementation submodule 310.

[0074] In some implementations, the system implementation submodule can include a system discontinuance sub-submodule 326 that receives the economic value 316 for the generated system design 250 and makes a decision regarding continuation or discontinuance of implementation of the system 100.
Discontinuance of the system 100 can indicate suspension of drilling of one or more wellbores, such that the system 100 is abandoned.

[0075] In some implementations, the pre-existing system design 230 can be generated by the redesign submodule 308 based on the initial geological model 224, using the multiple-iteration or single-iteration process described above.
In other implementations, the pre-existing system design 230 can be generated by other means, such as by a human designer. The initial geological model 224 can be generated based on survey data or other data collected prior to beginning construction of the system 100.
Date Recue/Date Received 2021-09-10

[0076] The initial geological model 224 and reservoir data-defined geological model 226 can be spatial models of the subterranean environment in the region being explored by the system 100, i.e. the subterranean formation 102 and its geological environment, and in particular the geology of the regions between the upper openings of the wells of the system 100 and the subterranean formation 102.
In some implementations, the initial geological model 224 and/or reservoir data-defined geological model 226 can include full-field reservoir simulation models specifying parameters such as the structure, layering, properties, and regions of the subterranean formation 102 and/or its geological environment. The initial geological model 224 and/or reservoir data-defined geological model 226 can include stratigraphy information and/or a seismic inversion model.

[0077] The geological model update submodule 302 generates the reservoir data-defined geological model 226 by processing the reservoir data 222. In some implementations, due to the stochastic nature of the geology, the geological model update submodule 302 does not receive an initial geological model 224;
instead, the reservoir data-defined geological model 226 is generated using the reservoir data 222 without reference to a pre-existing initial geological model 224. In other implementations, the initial geological model 224 is adjusted or updated based on the reservoir data 222. In some implementations, further data other than reservoir data 222 can be obtained and used as inputs to the geological model update submodule 302, such as deviation surveys or laboratory data such as special core analysis (SCAL).

[0078] The geological model update submodule 302 can use the reservoir data 222 to update the regions of the initial geological model 224 close to the wellbore being drilled when the reservoir data 222 is collected. In some examples, other spatial regions of the initial geological model 224 can be updated as well based on the reservoir data 222. In some implementations, various parameters of the initial geological model 224 can be updated directly to generate the reservoir data-defined geological model 226, using updated values for various parameters of the model derived directly or indirectly from the reservoir data 222. In some Date Recue/Date Received 2021-09-10 implementations, the geological model update submodule 302 can include logic for estimating or modeling geological parameters of the model based on the reservoir data 22 and/or the initial values of the model parameters. In some implementations, the logic can include the use of trained machine learning models or probabilistic models to estimate parameter values for the reservoir data-defined geological model 226 based on the reservoir data 222. For example, an artificial neural network, such as a convolutional neural network, can be trained to generate geological parameters of the reservoir data-defined geological model 226 using as inputs the previous geological parameter values of the initial geological model 224 and the reservoir data 222, either as-is or after being preprocessed. The neural network can be trained using a data set of reservoir data labelled with ground-truth geological parameters values for the corresponding geological environment, such as measurement of the geological parameter values measured in a laboratory using core samples.

[0079] The hydrocarbon production prediction submodule 304 can also make use of one or more models, such as trained machine learning models, probabilistic models, and/or numerical or analytical simulations, to generate the prediction data 314. The prediction data 314 is representative of one or more measures of hydrocarbon material production by the system 100, such as produced fluid flow rate, hydrocarbon concentration measure, steam-to-oil ratio, oil production rate, steam injection demand, water production, non condensable gas production, information regarding lean zone/rich zone interactions, solvent hold up ratio, solvent oil ratio, and/or a likelihood and/or predicted severity of steam breakthrough, liner failure, solvent break through, operation issues with hot wells and low sub cool, etc. The prediction data 314 can be used directly or indirectly to predict an overall measure of hydrocarbon material production, potentially including both quantity and quality of the produced hydrocarbon material, by the various production wells of the system 100. The prediction data 314 can also include one or more measures of expected resources needed to extract the hydrocarbon material, such as power, steam, solvent, replacement materials or equipment, labour, etc.
Date Recue/Date Received 2021-09-10

[0080] Thus, in some implementations, the hydrocarbon production prediction submodule 304 can include a trained machine learning model, such as an artificial neural network, trained to predict a measure of hydrocarbon material production by a system 100 using a training dataset. The training dataset can include labelled data samples: each data sample can be a set of system design parameters (e.g.
number and type of wells, each well including well placement parameters and/or completion design parameters) and a set of geological parameters (e.g.
parameters of geological models). Each data sample can be labelled with a ground truth label indicating the ground truth measure of hydrocarbon material production by a system having the set of system design parameters operating in a geological environment having the set of geological parameters.

[0081] In other implementations, the hydrocarbon production prediction submodule 304 generates and updates a model of a hydrocarbon production system (e.g. a system 100) for simulating hydrocarbon production from the reservoir of the subterranean formation 102. The hydrocarbon production prediction submodule 304 simulates production from a reservoir based on the geological model (e.g., an existing geological model such as the initial geological model 224 or a previously updated geological model, or the reservoir data-defined geological model 226), using a system 100 defined by the system design (e.g., an existing system design such as the pre-existing system design 230 or a previously updated system design, a proposed system design 340, or the generated system design 250). By simulating hydrocarbon production from a simulated reservoir using a simulated hydrocarbon production system, the hydrocarbon production prediction submodule 304 can predict quantities and qualities of hydrocarbon materials likely to be produced from the real reservoir using a real hydrocarbon production system constructed according to the system design. These predictions can be encoded into the prediction data 314.

[0082] The redesign submodule 308 is configured to generate the proposed system design 340 based on the parameters of the reservoir data-defined geological model 226, the prediction data 314, and optionally the economic value Date Recue/Date Received 2021-09-10 316. In some implementations, the redesign module 308 can include one or more models, such as trained machine learning modules, probabilistic models, and/or simulations, which can be used to update the pre-existing system design 230 to generate the proposed system design 340. For example, in a first example implementation, the redesign submodule 308 can use a trained machine learning model, such as a generative adversarial network (GAN), to generate the proposed system design 340. A generator model of the GAN can receive as inputs the parameters of the reservoir data-defined geological model 226, the prediction data 314, and optionally the economic value 316. The generator model transforms these inputs, using layers of learnable parameters or weights, to generate system design parameters, such as well placement and completion design for a proposed first well design 342, a proposed second well design 344, and so on for each well of the proposed system design 340, as well as parameters indicating the number of wells of the proposed system design 340, etc. A discriminator model of the GAN is used to train the generator model using semi-supervised learning by computing an objective function which is back-propagated through the generator model to train the values of its learnable parameters. The discriminator model can be trained using system design parameters, geological parameters, and corresponding prediction data 314 and/or economic value 316, to compute an objective function that seeks to optimize the prediction data 314 and/or economic value 316 of the system design parameters generated by the generative model. Such a GAN-based implementation, if sufficiently trained, can avoid the need for the multiple-iteration process of refining proposed system designs 340 until an optimal system design is identified. In a second example implementation, a generative model can be trained directly using feedback in the form of the prediction data 314 and/or economic value 316 of its generated system design parameters.

[0083] The redesign submodule 308 can identify an optimal system design among its proposed system designs 340, either by generating a single proposed system design 340 in a single iteration as described above, or by iterating the process of generating a proposed system design 340 and evaluating the proposed system design 340 using the hydrocarbon production prediction submodule 304 Date Recue/Date Received 2021-09-10 and/or the economic value submodule 306 until an optimization condition is satisfied. For example, the optimization condition can be satisfied when a predetermined number of proposed system designs 340 have been generated;
when the prediction data 314 and/or economic value 316 show a measure of improvement over the pre-existing system design 230 over a predetermined improvement threshold; or when the prediction data 314 and/or economic value 316 begin to converge relative to previously generated proposed system design 340. In some implementations, the redesign submodule 308 can perform a gradient descent, using the prediction data 314 and/or economic value 316 as an objective function, to adjust system design parameters toward an optimal set of values.
After the optimization condition is satisfied, the redesign submodule 308 identifies the optimal system design as the proposed system designs 340 having the best prediction data 314 and/or economic value 316. The identified optimal system design is output as the generated system design 250.

[0084] The system discontinuance sub-submodule 326 can base its decisions regarding continuation or discontinuance of implementation of the system 100 on an economic metric, such as a threshold or test for economic viability or profitability, using the economic value 316 as input. In some implementations, the economic value 316 is generated by the economic value submodule 306 to include .. several types of information. For example, the economic value 316 can include an expected financial expenditure required to construct and/or operate the system based on the generated system design 250. The expected financial expenditure can be compared to an expected return, such as an expected revenue generated by operating the system 100, which can also be included in the economic value 316.
.. The expected revenue can be computed by the economic value submodule 306 based on the prediction data 314, which can include a prediction of one or more measures of hydrocarbon material production by the system 100 based on the generated system design 250 and the reservoir data-defined geological model 226.
By comparing the expected financial expenditure to the expected return, a cost-benefit analysis or return on investment (ROI) analysis can be performed by the economic value submodule 306, thereby generating a cost-benefit or ROI value as Date Recue/Date Received 2021-09-10 part of the economic value 316. The economic value 316 can also include an environmental impact value for determining one or more environmental impacts of operating the system 100, such as an amount of solvent or hydrocarbon material dispersed into the ground. The environmental impact value can be used to determine whether operation of the system 100 will comply with legal regulations or organizational policies governing environmental practices, and/or can be included in the cost-benefit analysis along with the expected financial expenditure, the expected return, and/or other metrics. The system discontinuance sub-submodule 326 can perform the cost-benefit or ROI analysis in some implementations in order to determine whether the economic value 316 satisfies the economic metric. In other implementations, the economic value 316 can include only a single value, such as a cost-benefit or ROI value, and the system discontinuance sub-submodule 326 can simply apply the economic metric to the cost-benefit or ROI value to determine whether the economic value satisfies the economic metric.

[0085] In some implementations, the economic value submodule 306 also includes one or more models, such as trained machine learning modules, probabilistic models, and/or simulations, used to generate the economic value based on the system design parameters and the prediction data 314.

[0086] Each of the submodules 302, 304, 306, 308, 310 can include one or more models, as described above. In some implementations, a submodule can use two or more models, such as two trained machine learning models or a deterministic simulation and a probabilistic model. In some implementations, two or more models can be configured in series, i.e. the output of a first model is provided as the input to the second model. In some implementations, the two models are used in parallel, with the output of a first model acting as a check or modifier on the output of the second model - for example, the output of a deterministic simulation can be used to check or validate the predictions of a trained machine learning model. In some implementations, the output of a first model can be used to train a machine learning model, as in the example of a GAN described above, in which a trained discriminator model is used to train a generator model.
Date Recue/Date Received 2021-09-10

[0087] In some implementations, the initial geological model 224 and/or the reservoir data-defined geological model 226 can be integrated into the logic of a software program. The hydrocarbon production prediction submodule 304 can use a simulation model incorporating the logic or parameters of the initial or updated .. geological model 224, 226 to perform a numerical or analytical prediction using a proposed system design 340 to generate the prediction data 314. The economic value submodule 306 can use an economic model that includes forecasted prices for various types and qualities of hydrocarbon materials, as well as environmental impact measures as described above, to generate the economic value 316 based on the prediction data 314 and the proposed system design 340. The system redesign submodule 308 can then generate an optimization workflow in real time to generate system design parameters indicating information such as: number and types of wells, well designs (e.g., well placement, completion design, installation of sand control), and optimum operating conditions (per well and/or system-wide) such as injection parameters for injection wells, etc. The system discontinuance sub-submodule 326 of the system implementation submodule 310 can make decisions regarding finalizing the drilling operation or abandoning the drilling of the current well based on the economic value 316, and optionally based on the prediction data 314 and/or proposed system design 340 as well.

[0088] By using automated logic such as computational models to generate the reservoir data-defined geological model 226 based on the reservoir data 222, the reservoir data-defined geological model 226 can be generated in real time, i.e.
in a matter of seconds or minutes. This stands in contrast to existing techniques, in which a reservoir model can require weeks of time to be updated by human designers. By automating the model updating process, the system implementation can be updated in real time as well, allowing for the system to be optimized when construction (e.g. drilling) has already begun.

[0089] In some implementations, one or more of the functions of two or more of the submodules 302, 304, 306, 308, 310 can be combined into a single submodule, split into multiple additional submodules, and/or redistributed among Date Recue/Date Received 2021-09-10 the other submodules. For example, the system redesign subnnodule 308 can receive the reservoir data 222 directly in some implementations, and can use techniques such as machine learning to automatically generate the generated system design 250 based on the reservoir data 222, either alone or in combination with the initial geological model 224.

[0090] In some implementations, different functions of the system design module 300 can be performed on different devices other than the computing system 200. For example, computationally intensive functions such as training machine learning models, executing trained machine learning models, and/or generating simulations of other models can be performed on a cloud computing platform in communication with a local computing system 200. By leveraging cloud computing resources and machine learning, the need for numerical simulation can be eliminated or optimized in some implementations, and the optimization and implementation of system design can be performed in real time without waiting for manual intervention by a human designer.

[0091] Example implementations of methods for constructing a system for producing hydrocarbon materials from a subterranean formation will now be described, with reference to the example system design module 300 executed by the example computing system 200.
First Example Method

[0092] FIG. 4 is flowchart showing operations of a first example method 400 for constructing a system 100 for producing hydrocarbon materials from a subterranean formation 102.

[0093] At 402, the pre-existing system design 230 is obtained. As described above, the pre-existing system design 230 can be designed by a human designer, or the pre-existing system design 230 can be generated by the system redesign submodule 308 based on the initial geological model 224. The pre-existing system design 230 can be stored in the memory 214 after being received. The pre-existing Date Recue/Date Received 2021-09-10 system design 230 includes at least an initial well placement and for at least a first well of the system.

[0094] At 403, the initial geological model 224 is received. As described above, the initial geological model 224 can be generated based on survey data prior to beginning construction of the system 100. The initial geological model 224 can be stored in the memory 214 after being received.

[0095] At 404, an initial drill path is determined for a wellbore based on the initial well placement of the first well of the system. The initial drill path can be determined by the drilling implementation sub-submodule 322 of the implementation submodule 310, based on the pre-existing system design 230. In some examples, the initial drill path can be explicitly included in the pre-existing system design 230.

[0096] At 406, a first drilling stage of drilling of the wellbore into the subterranean formation is performed based on the initial drill path. The drilling implementation sub-submodule 322 can be used to control a drilling apparatus to perform the first drilling stage.

[0097] At 408, reservoir data 222 is collected during the first drilling stage.
The reservoir data 222 is representative of one or more characteristics of the subterranean formation 102, as described above. The reservoir data 222 can include LWD data obtained by the LWD tool 208 of the drilling apparatus 211, sent to the computing system 200 via the network interface 210, and stored in the memory 214.

[0098] At 410, the reservoir data 222 is processed by the geological model update submodule 302 to generate an reservoir data-defined geological model 226.
The reservoir data-defined geological model 226 models at least a portion of the subterranean formation 102; in some examples, as described above, the reservoir data-defined geological model 226 can update only regions of the initial geological model 224 that are near to the drill path of the wellbore being drilled. In some examples, as described above, step 404 can be omitted, and the reservoir data-Date Recue/Date Received 2021-09-10 defined geological model 226 can be generated using the reservoir data 222 without basing the reservoir data-defined geological model 226 on an initial geological model 224. The reservoir data-defined geological model 226 can be stored in the memory 214.

[0099] At 412, hydrocarbon production (i.e. a reservoir fluid production measure) from the subterranean formation 102 is predicted by the hydrocarbon production prediction submodule 304, based on the reservoir data-defined geological model 226 and the pre-existing system design 230, thereby generating the prediction data 314.

[0100] At 414, the prediction data 314 and reservoir data-defined geological model 226 are processed by the system redesign submodule 308 to generate an generated system design 250 based on the pre-existing system design 230. In the presently described example, the generated system design 250 includes at least an updated well placement for at least the first well (i.e., an updated model-defined placement of the well or a change in placement of the model-defined well). It will be understood that step 414 can, in some implementations, include one or more iterations of the redesign process described above with reference to FIG. 3, wherein one or more proposed system designs 340 are generated and evaluated until an optimal proposed system design 340 is identified and used as the generated system design 250. It will also be understood that, in some implementations, the economic value submodule 306 can be used to generate the economic value 306, which can be used as a further input to the system redesign submodule 308 at step 414 in generating the generated system design 250.

[0101] In some embodiments, steps 412 and 414 are omitted, and the prediction data 314 is only used as an objective function to train a machine learning model of the redesign submodule 308 during a training stage prior to deployment of the redesign submodule 308 for real-time system redesign. In such embodiments, the machine learning model of the redesign submodule 308 deployed for real-time system redesign has been trained to generate the generated system design 250 based on the reservoir data-defined geological model 226.
Date Recue/Date Received 2021-09-10

[0102] At 416, an altered drill path is determined, based on the updated well placement for the first well, as indicated by the generated system design 250 generated at step 414. The altered drill path can be determined by the drilling implementation sub-submodule 322 of the implementation submodule 310, based .. on the generated system design 250. In some examples, the initial drill path can be explicitly included in the generated system design 250.

[0103] At 418, a second drilling stage of drilling of the wellbore into the subterranean formation 102 is performed, based on the altered drill path. The drilling implementation sub-submodule 322 can be used to control a drilling apparatus to perform the second drilling stage, thereby altering the drill path of the well currently being drilled.

[0104] In some embodiments, of the example method 400 of FIG. 4, for example, the drill path of a wellbore can be revised in real time during the drilling operation based on reservoir data obtained during the drilling operation. This can .. prevent costly delays or the need to construct additional wells in light of new or unexpected geological data uncovered during drilling or operation, and can improve the performance and/or decrease the cost and time required to construct the system 100.
Second Example Method

[0105] FIG. 5 is flowchart showing operations of a second example method 500 for constructing a system 100 for producing hydrocarbon materials from a subterranean formation 102. Steps 402 through 414 are identical to those of method 400 shown in FIG. 4, except as noted otherwise below.

[0106] The generated system design 250 generated at step 414, in the present example of FIG. 5, includes a completion design for at least one well of the system (e.g., updated first well completion design 256 or updated second well completion design 266); or a well placement for at least one well of the system (e.g., updated first well placement 254 or updated second well placement 264).
Date Recue/Date Received 2021-09-10

[0107] At 516, the economic value 316 is computed by the economic value submodule 306 based on the generated system design 250. It will be understood that, in FIG. 3, the input to the economic value submodule 306 from the proposed system design 340 can in this example represent the input from the optimal proposed system design 340 selected as the generated system design 250. It will also be appreciated that the prediction data 314 generated based on the generated system design 250 can constitute a further input to the economic value submodule 306 used to generate the economic value 306.

[0108] At 518, the system discontinuance sub-submodule 326 determines whether the economic value 316 satisfies the economic metric, as described above.

[0109] If the economic value 316 satisfies the economic metric, the method 500 proceeds to step 520, wherein the implementation submodule 310 can be used to complete drilling of the first well by continuing the drilling of the wellbore (e.g.
continuing the drilling operation for a second stage and/or subsequent stages using the drilling implementation sub-submodule 322).

[0110] If the economic value 316 does not satisfy the economic metric, the method 500 proceeds to step 522, wherein the drilling operation is suspended using the drilling implementation sub-submodule 322. In some examples, the system is abandoned following step 522. A system 100 is considered to be abandoned if the system 100 is not used to produce hydrocarbon material within a predetermined period, such as one year, of suspension of drilling.

[0111] In some examples, the generated system design 250 generated at step 414 includes an updated first well placement 254, resulting in an updated drill path for the wellbore currently being drilled. If the economic value 316 satisfies the economic metric, and the method proceeds to step 520, completing the drilling of the first well at step 520 can involve performing a second drilling stage of the drilling operation based on the updated drill path, as in step 418 of method 400.

[0112] Thus, in the example method 500 of FIG. 5, the economic viability of the updated system can be assessed in light of the new reservoir data obtained Date Recue/Date Received 2021-09-10 during drilling, and a decision can be made to continue or abandon the system 100.
This can prevent resources from being spent on a well that is not optimally placed relative to the subterranean formation 102, and can improve the performance and/or decrease the cost and time required to construct the system 100.
Third Example Method

[0113] FIG. 6 is flowchart showing operations of a third example method 600 for constructing a system 100 for producing hydrocarbon material from a subterranean formation 102. In this example method 600, the system 100 produces the hydrocarbon materials from the subterranean formation by injecting stimulation fluid via an injection well 104 and producing the hydrocarbon material, that is stimulated by the injected stimulation fluid, at a production well 106. Steps 402 through 414 are identical to those of method 400 shown in FIG. 4, except as noted otherwise below.

[0114] The pre-existing system design 230 includes at least a first well of the system (specified by first well design 232) having an initial first well placement 234, and a second well of the system (specified by second well design 242). The first well is the production well 106; the second well is the injection well 104.
Thus, method 600 is described in the context of a stimulation fluid injection hydrocarbon extraction technology, such as SAGD, ES-SAGD, or waterflooding technologies.

[0115] The generated system design 250 generated at step 414, in the present example of FIG. 6, includes an updated well design for the injection well 104 and an updated well design for the production well 106. Each updated well design includes at least a well placement (e.g., updated first well placement 234 or updated second well placement 244) or a completion design (e.g., updated first well completion design 236 or updated second well completion design 246).

[0116] Step 414 is followed by at least one of subsequent steps 416, 618, 620, and/or 622.

[0117] Step 416 is identical to step 416 of method 400, and can optionally be followed by step 418 of method 400.
Date Recue/Date Received 2021-09-10

[0118] At 618, an updated completion design (i.e., updated first well completion design 236) is determined for the first well.

[0119] At 620, an updated well placement design (i.e., updated second well placement 244) is determined for the second well.

[0120] At 622, an updated completion design (i.e., updated second well completion design 246) is determined for the second well.

[0121] Thus, in the example method 600 of FIG. 6, the drilling of a first well of an injector-producer well pair can result in reservoir data that can be used to update the design of the second well of the well pair. This can improve the cooperation of the two wells of the well pair, and can improve the performance and/or decrease the cost and time required to construct the system 100.

[0122] FIG. 6A shows an example second stage 630 following method 600.
The first example second stage 630 follows the last step of method 600 (i.e., step 416, 618, 620, or 622).

[0123] At 636, a first drilling stage of drilling of a second wellbore is performed for the second well into the subterranean formation 102 based on the generated system design 250. The drilling implementation sub-submodule 322 can be used to control a drilling apparatus to perform the first drilling stage of the second wellbore by controlling a drilling apparatus.

[0124] At 638, additional reservoir data, representative of one or more characteristics of the subterranean formation, is received. The further reservoir data is collected (e.g., by a reservoir device 208) during the first drilling stage of drilling the second wellbore.

[0125] At 640, the additional reservoir data is processed by the geological model update submodule 302 to generate an updated geological model (i.e., a further updated geological model) of at least a portion of the subterranean formation based on the geological model (i.e., based on the reservoir data-defined geological model 226 generated at step 410).
Date Recue/Date Received 2021-09-10

[0126] At 642, hydrocarbon production from the subterranean formation is predicted by the hydrocarbon production prediction submodule 304, based on the further updated geological model and the generated system design 250, thereby generating additional prediction data.

[0127] At 644, the additional prediction data is processed by the system redesign submodule 308 to generate a second updated system design based on the generated system design 250. The second updated system design includes a well design for the injection well 104 and a well design for the production well 106. Each well design includes at least a well placement or a completion design.

[0128] After step 644, the second stage 630 performs at least one of the following additional steps 646, 648, and/or 650 based on the second updated system design.

[0129] At 646, an updated drill path is determined for drilling of the second well based on the second updated system design, for example using the drilling implementation sub-submodule 322.

[0130] At 648, an updated completion design of the second well is determined based on the second updated system design.

[0131] At 650, an updated completion design of the first well is determined based on the second updated system design.

[0132] Thus, in the first example second stage 630, further improvements can be realized in updating the complementary designs of both wells of the well pair, thereby potentially further improving cooperation between the wells of the well pair.
Fourth Example Method

[0133] FIG. 6B is flowchart showing operations of a fourth example method 660 for constructing a system 100 for producing hydrocarbon materials from a subterranean formation 102. Steps 402, 403, 408, 410, 412, and 414 are identical to those of method 400 shown in FIG. 4, except as noted otherwise below.
Date Recue/Date Received 2021-09-10

[0134] Steps 516 and 518 of the second example second stage 660 are identical to steps 516 and 518 of method 500 unless otherwise indicated below.
The economic value submodule 306 and the system discontinuance sub-submodule 326 can be used to make and implement a decision regarding continuing or abandoning the second well, as in method 500.

[0135] At 664, at least a portion of the wellbore for the first well is drilled along a first drill path. Step 664 can be implemented as step 406 of method 400, in which a first drilling stage of drilling the wellbore of the first well is effected.

[0136] At 665, a second drill path is determined for the wellbore of the second well. The second dill path can be determined based on a well placement for the second well indicated in the pre-existing system design 230.

[0137] At 666, after drilling at least a portion of the first well, a wellbore is drilled for the second well along the second drill path. This drilling step can constitute a first drilling stage for the wellbore of the second well, as in step 406 of method 400 but with respect to the second well of the system 100. The drilling implementation sub-submodule 322 can be used to control the drilling operation at a second well placement location (e.g., a further updated second well placement of the second updated system design), following a drill path based on the second well placement location.

[0138] At 670, in response to determining that the economic value 316 satisfies the economic metric, the drilling of the second well can be completed (e.g.
by continuing the 2nd wellbore drilling operation 666 for a second stage and/or subsequent stages using the drilling implementation sub-submodule 322).

[0139] Thus, in the second example second stage 660, economic analysis can be used to determine whether to continue or abandon either or both the first well and the second well of an injector-producer well pair after the first well has been drilled and while the second well is being drilled, and if construction of the wells is continued, both wells can be constructed based on a further updated system Date Recue/Date Received 2021-09-10 design, thereby potentially improving the performance and/or decreasing the cost and time required to construct the system 100.
Fifth Example Method

[0140] FIG. 7 is flowchart showing operations of a fifth example method 700 for constructing a system 100 for producing hydrocarbon materials from a subterranean formation 102 during a first time interval, with effect that residual hydrocarbon material remains within the reservoir after the first time interval, and constructing an infill well for producing the residual hydrocarbon. Steps 403, 408, 410, and 412, are identical to those of method 400 shown in FIG. 4, except as noted otherwise below.

[0141] The method 700 begins with a early stage hydrocarbon production system 100, including one or more wells, already constructed and operational.

[0142] At 701, hydrocarbon material is produced from the reservoir of the subterranean formation 102 during the first time interval with the early stage hydrocarbon production system 100.

[0143] At 702, a pre-existing system design 230 is obtained. The pre-existing system design 230 includes an initial design for a first infill well to be constructed.
Infill wells are described above, and can be placed in between existing wells of a system 100. Step 702 otherwise corresponds to step 402 of method 400.

[0144] At 403, the initial geological model 224 is received, as described with reference to method 400.

[0145] At 704, an initial drill path is determined for a wellbore based on the initial well placement of the infill well of the system. Step 704 otherwise corresponds to step 404 of method 400.

[0146] At 706, a first drilling stage of drilling of the wellbore into the subterranean formation is performed based on the initial drill path for the infill well.
Step 706 otherwise corresponds to step 406 of method 400.
Date Recue/Date Received 2021-09-10

[0147] At 408, reservoir data 222 is collected during the first drilling stage, as described with reference to method 400.

[0148] At 410, the reservoir data 222 is processed by the geological model update submodule 302 to generate an reservoir data-defined geological model 226, as described with reference to method 400.

[0149] At 412, hydrocarbon production from the subterranean formation is predicted by the hydrocarbon production prediction submodule 304, as described with reference to method 400.

[0150] At 714, the prediction data 314 is processed by the system redesign submodule 308 to generate an generated system design 250 based on the pre-existing system design 230. In the presently described example, the generated system design 250 includes at least an updated well placement for at least the infill well or an updated completion design for the infill well. Step 714 otherwise corresponds to step 414 of method 400.

[0151] Thus, in the example method 700 of FIG. 7, an infill well of the system 100 is designed based on reservoir collected during drilling. This can improve the performance and/or decrease the cost and time required to construct the system 100.
General

[0152] 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.

[0153] 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.
Date Recue/Date Received 2021-09-10

[0154] 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.

[0155] 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.

[0156] 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.
Date Recue/Date Received 2021-09-10

Claims

- 42 -

1. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
drilling the wellbore along a drill path;
while the drilling is being effected along the drill path, obtaining, from the subterranean formation, reservoir data representative of one or more characteristics of the subterranean formation;
processing the reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the reservoir data-defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure; and the generated system design includes definition of a placement of the well;
and altering the drill path based on the generated system design.

2. The method as claimed in claim 1;
wherein:
the altering of the drill path is effected while the drilling is being effected.

3. The method as claimed in claim 1 or 2;
wherein:
the altering of the drill path, based on the updated model-defined placement of the model-defined well, includes changing a direction of the drilling of the wellbore by at least ten degrees.

4. The method as claimed in any one of claims 1 to 3;
wherein:
the generated system design includes definition of a completion design;
further comprising:
after the drilling, installing a completion, relative to the wellbore, based on the completion design.

5. The method as claimed in claim 4;
wherein:
the installing of a completion, relative to the wellbore, is an installation within the wellbore.

6. The method as claimed in claim 4 or 5;
wherein:
the completion includes one or more of a flow control device, a liner, a slotted liner, a sand control device, a blank section, a packer, and an artificial lift apparatus.

7. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
drilling the wellbore along a drill path;
while the drilling is being effected along the drill path, obtaining, from the subterranean formation, reservoir data representative of one or more characteristics of the subterranean formation;
processing the reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generated system design includes definition of a completion design;
and after the drilling of the wellbore, installing a completion, relative to the wellbore, based on the completion design.

8. The method as claimed in claim 7;
wherein the installing of a completion, relative to the wellbore, is an installation within the wellbore.

9. The method as claimed in claim 7 or 8;
wherein:
the completion includes one or more of a flow control device, a liner, a slotted liner, a sand control device, a blank section, a packer, and an artificial lift apparatus.

10. The method as claimed in any one of claims 7 to 9;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure

11. The method as claimed in any one of claims 1 to 10;
wherein:
the obtaining of the reservoir data includes obtaining logging while drilling (LWD) data with a LWD tool.

12. The method as claimed in any one of claims 1 to 11;
wherein:
the obtaining of the reservoir data includes obtaining measurement while drilling (MWD) data with a MWD tool.

13. The method as claimed in any one of claims 1 to 12;
wherein:
the reservoir data includes at least one of the following:
seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and gas properties.

14. The method as claimed in any one of claims 1 to 13;
wherein both of:
the processing of the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling is being effected along the drill path.

15. The method as claimed in any one of claims 1 to 14;
wherein:
the reservoir fluid production measure is predicted by a simulation of hydrocarbon production from the reservoir based on the reservoir data-defined geological model and the generated system design.

16. The method as claimed in claim 15;
wherein:
generating the system design comprises using a trained generator model to generate the system design based on the reservoir data-defined geological model.

17. The method as claimed in claim 16;
wherein:
the trained generator model generates the system design based on the reservoir data-defined geological model and a pre-existing system design.

18. The method as claimed in claim 16 or 17;
wherein:
the trained generator model is trained using a training reservoir fluid production measure predicted by the simulation of hydrocarbon production.

19. The method as claimed in any one of claims 16 to 18;
wherein:
the generator model is a trained generator model of a trained generative adversarial network (GAN).

20. A system for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
a processor device; and a memory storing instructions that, when executed by the processor device, cause the system to perform a method as claimed in any one of claims 1 to 19.

21. A non-transitory computer-readable medium storing instructions thereon to be executed by a processor device, the instructions, when executed, causing the processor device to perform a method as claimed in any one of claims 1 to 20.

22. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
drilling the wellbore;
while the drilling is being effected, obtaining, from the subterranean formation, reservoir data representative of one or more characteristics of the subterranean formation;
processing the reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the reservoir data-defined geological model, generating a system design for the hydrocarbon production system;
computing an economic value based on the generated system design; and determining whether the economic value satisfies an economic metric.

23. The method as claimed in claim 22;
wherein:
the generated system design includes definition of a placement of the well.

24. The method as claimed in claim 22 or 23;
wherein:
the generated system design includes definition of a completion.

25. The method as claimed in claim 24;
wherein:
the completion includes one or more of a flow control device, a liner, a slotted liner, a sand control device, a blank section, a packer, and an artificial lift apparatus.

26. The method as claimed in any one of claims 22 to 25;
wherein:
the determining is effected while the drilling of the wellbore is being effected, and is with effect that the economic value satisfies an economic metric;
and further comprising:
in response to the determining that the economic value satisfies an economic metric:

continuing the drilling of the wellbore.

27. The method as claimed in any one of claims 22 to 25;
wherein:
the determining is effected while the drilling of the wellbore is being effected, and is with effect that the economic value fails to satisfy an economic metric;
and further comprising:
in response to the determining that the economic value fails to satisfy an economic metric, suspending the drilling of the wellbore, such that the system becomes abandoned.

28. The method as claimed in claim 25;
wherein:
the determining is effected after completing of the drilling of the wellbore, and is with effect that the economic value satisfies an economic metric;
and further comprising:
in response to the determining that the economic value satisfies an economic metric:
installing a completion, based on the defined completion, within the drilled wellbore.

29. The method of claim 25;
wherein:
the determining is effected after the drilling of the wellbore, and is with effect that the economic value fails to satisfy an economic metric;

and further comprising:
in response to the determining that the economic value fails to satisfy an economic metric, abandoning the system prior to installing a completion within the wellbore.

30. The method as claimed in claim 28 or 29, further comprising:
after the abandoning of the system, constructing another system for producing hydrocarbon material from the reservoir of the subterranean formation.

31. The method as claimed in any one of claims 22 to 30;
wherein:
the obtaining of the reservoir data includes obtaining logging while drilling (LWD) data with a LWD tool.

32. The method as claimed in any one of claims 22 to 31;
wherein:
the obtaining of the reservoir data includes obtaining measurement while drilling (MWD) data with a MWD tool.

33. The method as claimed in any one of claims 22 to 32;
wherein:
the reservoir data includes at least one of the following:
seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and gas properties.

34. The method as claimed in any one of claims 22 to 33;
wherein:

the generation of the system design is based on at least a reservoir fluid production measure

35. The method as claimed in any one of claims 22 to 34;
wherein both of:
the processing the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling of the wellbore is being effected.

36. The method as claimed in any one of claims 22 to 35;
wherein:
the reservoir fluid production measure is predicted by a simulation of hydrocarbon production from the reservoir based on the reservoir data-defined geological model and the generated system design.

37. The method as claimed in claim 36;
wherein:
generating the system design comprises using a trained generator model to generate the system design based on the reservoir data-defined geological model.

38. The method as claimed in claim 37;
wherein:
the trained generator model generates the system design based on the reservoir data-defined geological model and a pre-existing system design.

39. The method as claimed in claim 37 or 38;
wherein:
the trained generator model is trained using a training reservoir fluid production measure predicted by the simulation of hydrocarbon production.

40. The method as claimed in any one of claims 37 to 39;
wherein:
the generator model is a trained generator model of a trained generative adversarial network (GBN).

41. A system for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
a processor device; and a memory storing instructions that, when executed by the processor device, cause the system to perform a method as claimed in any one of claims 22 to 40.

42. A non-transitory computer-readable medium storing instructions thereon to be executed by a processor device, the instructions, when executed, causing the processor device to perform a method as claimed in any one of claims 22 to 41.

43. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well, the method comprising:
drilling, along a first drill path, a wellbore of a one of the injection well and the production well;

while the drilling of a wellbore, of a one of the injection well and the production well, is being effected, obtaining, from the subterranean formation, a first set of reservoir data representative of one or more characteristics of the subterranean formation;
processing the reservoir data to define a geological model of the subterranean formation, such that a first reservoir data-defined geological model is obtained;
based on the reservoir data-defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generated system design includes definition of a placement of the wellbore of a one of the injection well and the production well;
where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the injection well, the definition of placement of the well is a definition of placement of the injection well, such that the generated system design includes the definition of a placement of the injection well; and where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the production well, the definition of placement of the well is a definition of placement of the production well, such that the generated system design includes the definition of a placement of the production well;
based on the generated system design, altering the first drill path, along which the drilling of the wellbore, of a one of the injection well and the production well, is being effected;
wherein:
where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the injection well, the altering of the first drill path is an altering of the first drill path of the wellbore of the injection well; and where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the production well, the altering of the first drill path is an altering of the first drill path of the wellbore of the production well;
and after completing of the drilling of the wellbore of a one of the injection well and the production well, drilling, along a second drill path, a wellbore of the other one of the injection well and the production well.

44. The method as claimed in claim 43;
wherein:
the altering of the first drill path is effected while the drilling of a wellbore, of a one of the injection well and the production well, is being effected.

45. The method as claimed in claim 43 or 44;
wherein:
the altering of the first drill path includes changing a direction of the drilling of the wellbore by at least ten degrees.

46. The method as claimed in any one of claims 43 to 45;
wherein:
the second drill path is based upon the generated system design.

47. The method as claimed in any one of claims 43 to 46;
further comprising:

while the drilling of the wellbore, of the other one of the injection well and the production well, is being effected along the second drill path, obtaining, from the subterranean formation, a second set of reservoir data representative of one or more characteristics of the subterranean formation;
processing the second set of reservoir data to update the first reservoir data-defined geological model of the subterranean formation, such that a second reservoir data-defined geological model is obtained;
based on the second reservoir data-defined geological model, generating an updated system design for the hydrocarbon production system;
wherein:
the generated updated system design includes definition of a placement of the well of the other one of the injection well and the production well;
where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the injection well, the definition of placement of the well is a definition of placement of the injection well, such that the generated updated system design includes the definition of a placement of the injection well; and where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the production well, the definition of placement of the well is a definition of placement of the production well, such that the generated updated system design includes the definition of a placement of the production well;
and based on the generated updated system design, altering the second drill path, along which the drilling of the wellbore, of the other one of the injection well and the production well, is being effected;
wherein:

where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the injection well, the altering of the second drill path is an altering of a drill path of the wellbore of the injection well; and where the drilling of a wellbore of the other one of the injection well and the production well is a drilling of a wellbore of the production well, the altering of the second drill path is an altering of a drill path of the wellbore of the production well.

48. The method as claimed in claim 47;
wherein:
the altering of the second drill path is effected while the drilling of the wellbore, of the other one of the injection well and the production well, is being effected.

49. The method as claimed in claim 47 or 48;
wherein:
the altering of the second drill path includes changing a direction of the drilling of the wellbore by at least ten degrees.

50. The method as claimed in any one of claims 43 to 49;
wherein both of:
the processing of the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling is being effected along the first drill path.

51. The method as claimed in any one of claims 43 to 50;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure.

52. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well, the method comprising:
drilling a wellbore of a one of the injection well and the production well;
while the drilling of a wellbore, of a one of the injection well and the production well, is being effected, obtaining, from the subterranean formation, a first set of reservoir data representative of one or more characteristics of the subterranean formation;
after completing the drilling of a wellbore of a one of the injection well and the production well, drilling, along a drill path, a wellbore of the other one of the injection well and the production well;
while the drilling of a wellbore, of the other one of the injection well and the production well, is being effected, obtaining, from the subterranean formation, a second set of reservoir data representative of one or more characteristics of the subterranean formation;
processing the first and second sets of reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the reservoir date-defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generated system design includes definition of a placement of the wellbore of the other one of the injection well and the production well;
wherein:
where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the injection well, the definition of placement of the well is a definition of placement of the injection well, such that the generated system design includes the definition of a placement of the injection well; and where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the production well, the definition of placement of the well is a definition of placement of the production well, such that the generated system design includes the definition of a placement of the production well;
and based on the generated system design, altering the drill path, along which the drilling of the wellbore, of the other one of the injection well and the production well, is being effected;
wherein:
where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the injection well, the altering of the first drill path is an altering of the drill path of the wellbore of the injection well; and where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the production well, the altering of the first drill path is an altering of the drill path of the wellbore of the production well.

53. The method as claimed in claim 52;
wherein:

the altering of the drill path, along which the drilling of the wellbore, of the other one of the injection well and the production well, is being effected, is effected while the drilling of the wellbore, of the other one of the injection well and the production well, is being effected.

54. The method as claimed in claim 52 or 53;
wherein:
the altering of the drill path, along which the drilling of the wellbore, of the other one of the injection well and the production well, is being effected, includes changing a direction of the drilling of the wellbore by at least ten degrees.

55. The method as claimed in any one of claims 50 to 54;
wherein both of:
the processing of the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling is being effected along the drill path.

56. The method as claimed in any one of claims 50 to 55;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure

57. The method of any one of claims 43 to 56;
wherein:
the injection well and the production well define a SAGD well pair; and the drilling of the wellbore of a one of the injection well and the production well is a drilling of the wellbore of the production well.

58. The method of any one of claims 43 to 56;
wherein:
the injection well and the production well define an ES-SAGD well pair; and the drilling of the wellbore of a one of the injection well and the production well is a drilling of the wellbore of the production well.

59. The method as claimed in any one of claims 43 to 58;
wherein:
the obtaining of the reservoir data includes obtaining logging while drilling (LWD) data with a LWD tool.

60. The method as claimed in any one of claims 43 to 59;
wherein:
the obtaining of the reservoir data includes obtaining measurement while drilling (MWD) data with a MWD tool.

61. The method as claimed in any one of claims 43 to 60;
wherein:
the reservoir data includes at least one of the following:
seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and gas properties.

62. The method as claimed in any one of claims 43 to 61;
wherein:

the reservoir fluid production measure is predicted by a simulation of hydrocarbon production from the reservoir based on the reservoir data-defined geological model and the generated system design.

63. The method as claimed in claim 62;
wherein:
generating the system design comprises using a trained generator model to generate the system design based on the reservoir data-defined geological model.

64. The method as claimed in claim 63;
wherein:
the trained generator model generates the system design based on the reservoir data-defined geological model and a pre-existing system design.

65. The method as claimed in claim 63 or 64;
wherein:
the trained generator model is trained using a training reservoir fluid production measure predicted by the simulation of hydrocarbon production.

66. The method as claimed in any one of claims 63 to 65;
wherein:
the generator model is a trained generator model of a trained generative adversarial network (GCN).

67. A system for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
a processor device; and a memory storing instructions that, when executed by the processor device, cause the system to perform a method as claimed in any one of claims 43 to 66.

68. A non-transitory computer-readable medium storing instructions thereon to be executed by a processor device, the instructions, when executed, causing the processor device to perform a method as claimed in any one of claims 43 to 67.

69. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well, the method comprising:
drilling a wellbore of a one of the injection well and the production well;
while the drilling of a wellbore, of a one of the injection well and the production well, is being effected, obtaining, from the subterranean formation, a first set of reservoir data representative of one or more characteristics of the subterranean formation;
drilling a wellbore of the other one of the injection well and the production well;
while the drilling of a wellbore, of the other one of the injection well and the production well, is being effected, obtaining, from the subterranean formation, a second set of reservoir data representative of one or more characteristics of the subterranean formation;
processing the first and second sets of reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;

based on the reservoir data-defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generated system design includes definition of a completion design;
and after the drilling of the wellbore of the other one of the injection well and the production well:
installing a completion relative to the wellbore of the injection well; and installing a completion relative to the wellbore of the production well;
wherein:
where the generated system design includes definition of a completion design of the injection well, the completion installed relative the wellbore of the injection well is based on the completion design defined by the generated system design; and where the generated system design includes definition of a completion design of the production well, the completion installed relative to the wellbore of the production well is based on the completion design defined by the generated system design.

70. The method as claimed in claim 69;
wherein:
the installing of a completion, relative to the wellbore, is an installation within the wellbore.

71. The method as claimed in claim 69 or 70;
wherein:
the completion includes one or more of a flow control device, a liner, a slotted liner, a sand control device, a blank section, a packer, and an artificial lift apparatus.

72. The method as claimed in any one of claims 69 to 71;
wherein:
the drilling of the other one of the injection well and the production well is effected after completing of the drilling of a wellbore of a one of the injection well and the production well.

73. The method as claimed in any one of claims 69 to 72;
wherein:
the injection well and the production well define a SAGD well pair; and the drilling of the wellbore of a one of the injection well and the production well is a drilling of the wellbore of the production well.

74. The method as claimed in any one of claims 69 to 72;
wherein:
the injection well and the production well define an ES-SAGD well pair; and the drilling of the wellbore of a one of the injection well and the production well is a drilling of the wellbore of the production well.

75. The method as claimed in any one of claims 69 to 74;
wherein:
the obtaining of the reservoir data comprises obtaining logging while drilling (LWD) data with a LWD tool.

76. The method as claimed in any one of claims 69 to 75;
wherein:
the obtaining of the reservoir data comprises obtaining measurement while drilling (MWD) data with a MWD tool.

77. The method as claimed in any one of claims 69 to 76;
wherein:
the reservoir data includes at least one of the following:
seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and gas properties.

78. The method as claimed in any one of claims 69 to 77;
wherein, both of:
the processing of the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling of the wellbore is being effected.

79. The method as claimed in any one of claims 69 to 78;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure.

80. The method as claimed in any one of claims 69 to 79;
wherein:
the reservoir fluid production measure is predicted by a simulation of hydrocarbon production from the reservoir based on the reservoir data-defined geological model and the generated system design.

81. The method as claimed in claim 80;
wherein:
generating the system design comprises using a trained generator model to generate the system design based on the reservoir data-defined geological model.

82. The method as claimed in claim 81;
wherein:
the trained generator model generates the system design based on the reservoir data-defined geological model and a pre-existing system design.

83. The method as claimed in claim 81 or 82;
wherein:
the trained generator model is trained using a training reservoir fluid production measure predicted by the simulation of hydrocarbon production.

84. The method as claimed in any one of claims 81 to 83;
wherein:
the generator model is a trained generator model of a trained generative adversarial network (GCN).

85. A system for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
a processor device; and a memory storing instructions that, when executed by the processor device, cause the system to perform a method as claimed in any one of claims 69 to 84.

86. A non-transitory computer-readable medium storing instructions thereon to be executed by a processor device, the instructions, when executed, causing the processor device to perform a method as claimed in any one of claims 69 to 85.

87. A method for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a production well in response to at least injecting of stimulation fluid via an injection well, the method comprising:
drilling a wellbore of one of the injection well and the production well;
while the drilling of a wellbore, of a one of the injection well and the production well, is being effected, obtaining, from the subterranean formation, a first set of reservoir data, representative of one or more characteristics of the subterranean formation;
after completing of the drilling of a wellbore of one of the injection well and the production well, drilling a wellbore of the other one of the injection well and the production well;
while the drilling of a wellbore of the other one of the injection well and the production well is being effected, obtaining, from the subterranean formation, a second set of reservoir data representative of one or more characteristics of the subterranean formation;
processing the first and second sets of reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the reservoir data-defined geological model, generating a system design for the hydrocarbon production system;
computing an economic value based on the generated system design; and determining whether the economic value satisfies an economic metric.

88. The method of claim 87, wherein:
the determining is effected while the drilling of the wellbore of the other one of the injection well and the production well is being effected, and is with effect that the economic value satisfies an economic metric;
and further comprising:
in response to the determining that the economic value satisfies an economic metric:
continuing the drilling of the wellbore of the other one of the injection well and the production well.

89. The method of claim 87;
wherein:
the determining is effected after the drilling of the wellbore of the other one of the injection well and the production well, and is with effect that the economic value satisfies an economic metric;
and further comprising:

in response to the determining that the economic value satisfies an economic metric:
within each one of the injection well and the production well, independently, installing a completion.

90. The method of claim 87;
wherein:
the determining is effected while the drilling of the wellbore of the other one of the injection well and the production well is being effected, and is with effect that the economic value fails to satisfy an economic metric;
and further comprising:
in response to the determining that the economic value fails to satisfy an economic metric, suspending the drilling of the wellbore of the other one of the injection well and the production well, such that the system becomes abandoned.

91. The method of claim 87;
wherein:
the determining is effected after the drilling of the wellbore of the other one of the injection well and the production well, and is with effect that the economic value fails to satisfy an economic metric;
and further comprising:
in response to the determining that the economic value fails to satisfy an economic metric, abandoning the system prior to installing completions within the wellbores.

92. The method as claimed in claim 90 or 91, further comprising:
after the abandoning of the system, constructing another system for producing hydrocarbon material from the reservoir of the subterranean formation.

93. The method of any one of claims 87 to 92;
wherein:
the generated system design includes definition of a placement of the well of the other one of the injection well and the production well;
where the drilling of a wellbore, of the other one of the injection well and the production well, is a drilling of a wellbore of the injection well, the definition of placement of the well is a definition of placement of the injection well, such that the generated updated system design includes the definition of a placement of the injection well; and where the drilling of a wellbore, of a one of the injection well and the production well, is a drilling of a wellbore of the production well, the definition of placement of the well is a definition of placement of the production well, such that the generated updated system design includes the definition of a placement of the production well.

94. The method of any one of claims 87 to 93;
wherein:
the generated system design includes definition of a completion design of at least one of the injection well and the production well, such that the generated system design includes definition of at least one of a completion design of the injection well and a completion design of the production well.

95. The method as claimed in any one of claims 87 to 94;
wherein:
the injection well and the production well define a SAGD well pair; and the drilling of the wellbore of a one of the injection well and the production well is a drilling of the wellbore of the production well.

96. The method as claimed in any one of claims 87 to 94;
wherein:
the injection well and the production well define an ES-SAGD well pair; and the drilling of the wellbore of a one of the injection well and the production well is a drilling of the wellbore of the production well.

97. The method as claimed in any one of claims 87 to 96;
wherein:
the obtaining of the reservoir data includes obtaining logging while drilling (LWD) data with a LWD tool.

98. The method as claimed in any one of claims 87 to 97;
wherein:
the obtaining of the reservoir data comprises obtaining measurement while drilling (MWD) data with a MWD tool.

99. The method as claimed in any one of claims 87 to 98;
wherein:
the reservoir data includes at least one of the following:

seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and gas properties.

100. The method as claimed in any one of claims 87 to 99;
wherein, both of:
the processing of the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling of the wellbore of the other one of the injection well and the production well is being effected.

101. The method as claimed in any one of claims 87 to 100;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure.

102. The method as claimed in any one of claims 87 to 101;
wherein:
the reservoir fluid production measure is predicted by a simulation of hydrocarbon production from the reservoir based on the reservoir data-defined geological model and the generated system design.

103. The method as claimed in claim 102;
wherein:
generating the system design comprises using a trained generator model to generate the system design based on the reservoir data-defined geological model.

104. The method as claimed in claim 103;
wherein:
the trained generator model generates the system design based on the reservoir data-defined geological model and a pre-existing system design.

105. The method as claimed in claim 103 or 104;
wherein:
the trained generator model is trained using a training reservoir fluid production measure predicted by the simulation of hydrocarbon production.

106. The method as claimed in any one of claims 103 to 105;
wherein:
the generator model is a trained generator model of a trained generative adversarial network (GEN).

107. A system for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
a processor device; and a memory storing instructions that, when executed by the processor device, cause the system to perform a method as claimed in any one of claims 87 to 106.

108. A non-transitory computer-readable medium storing instructions thereon to be executed by a processor device, the instructions, when executed, causing the processor device to perform a method as claimed in any one of claims 87 to 105.

109. A method for producing hydrocarbon material from a reservoir of a subterranean formation during a first time interval, with effect that residual hydrocarbon material remains within the reservoir after the first time interval, and constructing an infill well for producing the residual hydrocarbon, comprising:
producing hydrocarbon material from the reservoir of the subterranean formation during the first time interval with an early stage hydrocarbon production system;
after the first time interval, drilling, along a drill path, a wellbore of the infill well;
while the drilling of the wellbore of the infill well is being effected along the drill path, obtaining, from the subterranean formation, reservoir data representative of one or more characteristics of the subterranean formation;
processing the reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the reservoir data-defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generated system design includes definition of a placement of the well;
and altering the drill path based on the generated design.

110. The method as claimed in claim 109;
wherein:
the altering of the drill path is effected while the drilling of the wellbore, of the one of the injection well and the production well, is being effected.

111. The method as claimed in claim 109 or 110;
wherein:
the altering of the drill path includes changing a direction of the drilling of the wellbore by at least ten degrees.

112. A method for producing hydrocarbon material from a reservoir of a subterranean formation during a first stage, with effect that residual hydrocarbon material remains within the reservoir after the first time interval, and constructing an infill well for producing the residual hydrocarbon, comprising:
producing hydrocarbon material from the reservoir of the subterranean formation during a first time interval with an early stage hydrocarbon production system;
after the first time interval, drilling, along a drill path, a wellbore of the infill well;
while the drilling of the wellbore of the infill well is being effected along the drill path, obtaining, from the subterranean formation, reservoir data representative of one or more characteristics of the subterranean formation;
processing the reservoir data to define a geological model of the subterranean formation, such that a reservoir data-defined geological model is obtained;
based on the defined geological model, generating a system design for the hydrocarbon production system;
wherein:
the generated system design includes definition of a completion design;
and after the drilling of the wellbore, installing a completion, relative to the wellbore, based on the completion design.

113. The method as claimed in claim 112;
wherein the installing of a completion, relative to the wellbore, is an installation within the wellbore.

114. The method as claimed in claim 112 or 113;
wherein:
the completion includes one or more of a flow control device, a liner, a slotted liner, a sand control device, a blank section, a packer, and an artificial lift apparatus.

115. The method as claimed in any one of claims 109 to 114;
wherein:
the early stage hydrocarbon production system includes a early stage production system well extending into the subterranean formation; and the well and the infill well are co-operatively configured such that hydrocarbon material is producible from the reservoir via the infill well in response to at least injecting of stimulation fluid via the early stage production system well.

116. The method as claimed in any one of claims 109 to 114;
wherein:
the early stage hydrocarbon production system is a SAGD system including a SAGD well pair;
at least one of the wells of SAGD well pair and the infill well are co-operatively configured such that hydrocarbon material is producible from the reservoir via the infill well in response to at least injecting of stimulation fluid via the at least one SAGD well pair.

117. The method as claimed in any one of claims 109 to 116;
wherein:
the obtaining of the reservoir data includes obtaining logging while drilling (LWD) data with a LWD tool.

118. The method as claimed in any one of claims 109 to 117;
wherein:
the obtaining of the reservoir data comprises obtaining measurement while drilling (MWD) data with a MWD tool.

119. The method as claimed in any one of claims 109 to 118;
wherein:
the reservoir data includes at least one of the following:
seismic data, structural data, fluid contact data, temperature data, pressure data, electrical resistivity data, permeability data, porosity data, chemical composition data, oil saturation data, data indicating the presence of mud, wire line well logs, vertical well core data, geological tops, reservoir saturation logs, observation well pressure observation well temperature, initial seismic data, time lapsed seismic data, rock thermal properties, gas-oil ratio (GOR), oil viscosity, oil density, and gas properties.

120. The method as claimed in any one of claims 109 to 119;
wherein, both of:
the processing of the reservoir data to define the geological model; and the generation of the system design;
are performed while the drilling is being effected along the drill path.

121. The method as claimed in any one of claims 109 to 120;
wherein:
the generation of the system design is based on at least a reservoir fluid production measure.

122. The method as claimed in any one of claims 109 to 121;
wherein:
the reservoir fluid production measure is predicted by a simulation of hydrocarbon production from the reservoir based on the reservoir data-defined geological model and the generated system design.

123. The method as claimed in claim 122;
wherein:
generating the system design comprises using a trained generator model to generate the system design based on the reservoir data-defined geological model.

124. The method as claimed in claim 123;
wherein:
the trained generator model generates the system design based on the reservoir data-defined geological model and a pre-existing system design.

125. The method as claimed in claim 123 or 124;
wherein:
the trained generator model is trained using a training reservoir fluid production measure predicted by the simulation of hydrocarbon production.

126. The method as claimed in any one of claims 123 to 125;
wherein:
the generator model is a trained generator model of a trained generative adversarial network (GCN).

127. A system for constructing a system for producing hydrocarbon material from a reservoir of a subterranean formation via a wellbore of a well extending into the subterranean formation, comprising:
a processor device; and a memory storing instructions that, when executed by the processor device, cause the system to perform a method as claimed in any one of claims 109 to 126.

128. A non-transitory computer-readable medium storing instructions thereon to be executed by a processor device, the instructions, when executed, causing the processor device to perform a method as claimed in any one of claims 109 to 127.