Dynamic infill producer well placement

Abstract

In a computer-implemented techniques for dynamic infill producer well placement, a computer system identifies an area of interest in a hydrocarbon field. The area of interest represents a geographical area in which multiple infill producer wells are to be formed to produce hydrocarbons. Within the area of interest, the computer system identifies multiple sweet spot areas. The computer system receives well criteria associated with the multiple infill producer wells and a trigger event to trigger forming the multiple infill producer wells in the multiple sweet spot areas. The computer system determines that the trigger event has occurred. In response, the computer system controls wellbore drilling machinery to form the multiple infill producer wells according to the well criteria in the multiple sweet spot areas.

Description

TECHNICAL FIELD

[0001] This disclosure relates to computer-implemented methods, computer-readable media and computer systems to determine placement of and control machinery to form wellbores in hydrocarbon fields.BACKGROUND

[0002] Hydrocarbon entrapped in subsurface reservoirs can be raised to the surface (i.e., produced) by drilling wellbores from the surface to the subsurface reservoirs through a subterranean zone (e.g., a formation, a portion of a formation, multiple formations). The pressure of the subterranean zone causes the hydrocarbons to naturally flow to the surface. Over time, the pressure decreases necessitating secondary and tertiary forms of hydrocarbon recovery (sometimes called enhanced oil recovery or EOR) techniques. One such EOR technique is the formation of injector wells surrounding producer wells, i.e., the wells through which the hydrocarbons are produced to the surface. Injecting fluids (e.g., water) through the injector wells sweeps the hydrocarbons towards the producer wells and ultimately to the surface. Infill drilling is another EOR technique in which additional wells are drilled near existing wells. The infill wells (or infill producer wells) are strategically formed in regions of the subterranean zone in which hydrocarbons are expected to reside.SUMMARY

[0003] This disclosure describes technologies relating to computer-implemented methods, computer-readable media and computer systems to dynamically place infill producer wells in a hydrocarbon field and to control machinery to form such wells through the subterranean zone.

[0004] The details of one or more implementations of the subject matter described in this specification are set forth in the accompanying drawings and the description below. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.BRIEF DESCRIPTION OF THE DRAWINGS

[0005] FIGS. 1A and 1B are schematic diagrams of a computer system operatively coupled to a computer monitor that shows a computational model of a hydrocarbon field.

[0006] FIG. 2 is a flowchart of an example of a computer-implemented method of forming infill producer wells in a hydrocarbon field in response to a trigger event.

[0007] FIG. 3 illustrates hydrocarbon production operations that include both one or more field operations and one or more computational operations, which exchange information and control exploration for the production of hydrocarbons.

[0008] Like reference numbers and designations in the various drawings indicate like elements.DETAILED DESCRIPTION

[0009] This disclosure describes computer-implemented methods, computer-readable storage media and computer systems that can implement an automated workflow to place infill producer wells at optimal sweet spots (or sweet spot locations) in a hydrocarbon field. The geographic locations of the infill producer wells are selected based on certain criteria that each infill producer well satisfies, e.g., horizontal, vertical or slanted well. The infill producer wells are formed by wellbore drilling machinery that are controlled to automatically drill the wells in response to a trigger event being triggered. For example, the trigger event can be a drop in production flow rate from producer wells, i.e., all producers that are already drilled, below a certain threshold production flow rate. During and after formation of the infill producer wells, the production flow rate from the producer wells and any newly formed infill producer wells can continue to be monitored. Once the production flow rate increases beyond the threshold production flow, the operations of the wellbore drilling machinery can be stopped. A computer system can implement the process of identifying optimal sweet spots to place the infill producer wells. In parallel, the computer system can also implement the process of monitoring the production flow rate from the producer wells and the newly formed infill producer wells. The operations of the wellbore drilling machinery to form the infill producer wells can be automatically (i.e., without human intervention) be performed by the same computer system.

[0010] Implementing the techniques described here can yield some advantages. Optimal locations for infill producer wells can be determined computationally and automatically without human intervention. The optimal locations for infill producer wells can change over time due to changes in oil saturation over time. Tracking the changes of the optimal locations at each time step would be very time consuming. By implementing the techniques described here, changes to the optimal locations be determined effectively and more efficiently. Such operations can save computational resources and time. Wellbore drilling machinery to form infill producer wells can be controlled using computer systems that implement simulations to determine optimal locations for infill producer wells. Doing so can reduce human error and can also save computational resources.

[0011] FIGS. 1A and 1B are schematic diagrams of a computer system 100 operatively coupled to a computer monitor 102 that shows a computational model 104 of a hydrocarbon field. The computer system includes a computer-readable storage medium 103A and one or more processors 103B. The computer-readable storage medium 103A (e.g., a non-transitory computer-readable storage medium) can store computer instructions that are executable by the one or more processors 103B to perform operations described in this disclosure. A computer monitor 102 (e.g., a display device) can be operatively connected to the computer system 100. The computer system 100 can also be connected to input devices (not shown). The computer system 100 can receive input, e.g., from the input devices or from other sources, process the input and display output on the computer monitor 102.

[0012] In some implementations, the computer system 100 can run a simulation of the hydrocarbon field with the subsurface hydrocarbon reservoirs. The computer system 100 can show the output of the simulation as a model 104 (or a map) on the computer monitor 102. The computer system 100 can implement the simulation to analyze the geographical area covered by the hydrocarbon field. Based on the analysis, the computer system 100 can generate the model 104. The hydrocarbon field can include certain geographic areas that are more saturated with hydrocarbons compared to other geographic areas in the hydrocarbon field. The computer system 100 can show such geographic areas as regions 106 in the model 104. For example, the computer system 100 can show the regions 106 in a different color compared to a color of the rest of the model 104. In this manner, the computer system 100 can implement the simulation to identify specific geographic areas in the hydrocarbon field that are rich in hydrocarbons.

[0013] Producer wells can be formed in such hydrocarbon-rich geographic areas of the hydrocarbon field. For example, wellbore drilling machinery can be used to form each producer well. After completion, each well can be commissioned to produce hydrocarbons from the hydrocarbon-rich geographic areas. Various well and hydrocarbon properties including, for example, a hydrocarbon production flow rate, can be monitored. To do so, various sensors and flowmeters can be deployed above or below the surface of the well and at multiple downhole locations. The values sensed by the sensors and flowmeters including the hydrocarbon production flow rate value can be periodically (e.g., once an hour, once a minute, once per second, more than once per second or other frequency) transmitted to the computer system 100. The computer system 100 can continue to implement the simulation of the hydrocarbon field using the various values received from the various sensors and flowmeters. Alternatively or in addition, the computer system 100 can implement the simulation of the hydrocarbon field using simulation data generated by the computer system 100.

[0014] Turning to the computer monitor 102, each producer well can be represented on the model 104. For example, a user of the computer system 100 can select locations on the model 104 on which the producer wells are formed. In response, the computer system 100 can display representations of the producer well on the model 104. For example, the computer system 100 can display object 108a, object 108b, object 108c, each representing a-producer well, within the regions 106 representing the hydrocarbon-rich geographic areas of the hydrocarbon field. Thus, the model 104 in FIG. 1A schematically shows hydrocarbon-rich geographic areas in the hydrocarbon field and producer wells formed in those areas during the early stages of wellbore production.

[0015] Over time, as more hydrocarbon is produced from the hydrocarbon field, the hydrocarbon saturation levels change. Such change can be due to removal of the hydrocarbons from the hydrocarbon field. Alternatively or in addition, such change can be due to migration of the hydrocarbons within the hydrocarbon field. Migration can also cause hydrocarbons to move away from the hydrocarbon field to adjacent geographic areas and / or cause hydrocarbons from adjacent geographic areas to migrate into the hydrocarbon field. As mentioned above, the computer system 100 continues to implement the simulation of the hydrocarbon field using the various values received from the various sensors and flowmeters over time or using simulation data generated by the computer system 100 (or both).

[0016] FIG. 1B schematically shows a modified model 110 that appears different from the model 106 schematically shown in FIG. 1A. The modified model 110 is a representation of a change in the hydrocarbon saturation levels in the hydrocarbon field. In some instances, the modified model 110 shows that geographic areas saturated in hydrocarbons are no longer near the producer wells drilled during early stages of hydrocarbon production. In such instances, production flow rate through the producer wells can decrease, e.g., below threshold production flow rates. In response, secondary or tertiary EOR techniques can be implemented to enhance production through the hydrocarbon field. Such EOR techniques can include forming infill producer wells in strategic locations in the hydrocarbon field to enhance production through the new producer wells.

[0017] As described below with reference to FIG. 2, the computer system 100 can computationally and automatically (i.e., without human intervention) determine optimal locations for the infill producer wells. To do so, the computer system 100 can use data from the simulation that identifies sweet spots in which infill producer wells can be formed. The computer system 100 can receive input (e.g., from a user of the computer system 100) identifying characteristics of the infill producer wells. Based on data received from the simulation and input identifying characteristics of the infill producer wells, the computer system 100 can automatically control wellbore drilling machinery 112 to form one or more infill producer wells in the hydrocarbon field. In addition, the computer system 100 can display objects (e.g., object 114a, object 114b, object 114c) on the modified model 110. Each object can represent a corresponding infill producer well formed by the wellbore drilling machinery 112. An object representing an infill producer well can have a different appearance compared to an object representing a producer well. As described below, the computer system 100 can control the wellbore drilling machinery 112 to form the infill producer wells in response to a triggering event (e.g., producer wells' production flow rate dropping below a threshold production flow rate).

[0018] FIG. 2 is a flowchart of an example of a computer-implemented method 200 of forming infill producer wells in a hydrocarbon field in response to a trigger event. The infill producer wells can be formed by wellbore drilling machinery. The machinery can be controlled by a computer system (e.g., the computer system 100) based on hydrocarbon saturation data and based on characteristics of the infill producer wells.

[0019] At 202, an area of interest in a hydrocarbon field is identified. The area of interest represents a geographical area in which multiple infill producer wells are to be formed. The area of interest can be certain layers in the subterranean zone or certain geographic areas in the hydrocarbon field or a combination of them. In some implementations, the area of interest can be determined using the simulation described earlier. The computer system 100 can implement the simulations to determine, among other things, hydrocarbon saturation levels in the hydrocarbon field. From the determined hydrocarbon saturation levels, the computer system 100 can identify geographical areas with higher hydrocarbon saturation compared to other geographical areas in the hydrocarbon field. For example, the computer system 100 can compare hydrocarbon saturation values at different locations in the hydrocarbon field. The computer system 100 can determine the hydrocarbon saturation values using data received from multiple sensors deployed across the hydrocarbon field at different depths in the subterranean zone or using simulation data generated by the computer system 100 (or both). The computer system 100 can process the received data to determine the hydrocarbon saturation values. The computer system 100 can then identify a maximum (or a maximum range) of hydrocarbon saturation values based on the comparison. The computer system 100 can then identify the locations at which the maximum (or maximum range) of hydrocarbon saturation values were measured as the area of interest.

[0020] Alternatively or in addition, the computer system 100 can receive the area of interest from a user of the computer system 100. For example, as described above, the computer system 100 can display a model 106 (FIG. 1A) or a modified model 110 (FIG. 1B) that includes representations of geographical areas with hydrocarbon saturation. A user of the computer system 100 can select portions of the model that correspond to geographical areas of high hydrocarbon saturation.

[0021] At 204, multiple sweet spot areas can be identified within the area of interest. The computer system 100 can identify sweet spot areas by solving sweet spot formulas that identify sweet spot areas. For oil reservoirs, the sweet spot formula is shown in Equation 1.Sweet⁢ Spot=So*∅Equation⁢ 1

[0022] In Equation 1, So is the oil saturation and Φ is rock porosity. The oil saturation and rock porosity can be determined based on the simulation implemented by the computer system 100. In one example, if the output of Equation 1 is ≥30%, then that region is a sweet spot area.

[0023] For gas reservoirs, the sweet spot formula is shown in Equation 2.Sweet⁢ Spot=Sg*∅Equation⁢ 2

[0024] In Equation 1, Sg is the gas saturation and Φ is rock porosity. The gas saturation and rock porosity can be determined based on the simulation implemented by the computer system 100.

[0025] The computer system 100 can implement other sweet spot formulas as well. Further, the computer system 100 can implement different sweet spot formulas at different instances of implementing the computer-implemented method 200. For example, an operator of the computer system 100 can select a first sweet spot formula at a first instance of implementing the method 200 and a second, different sweet spot formula at a second, subsequent instance of implementing the method 200.

[0026] In some implementations, to identify the sweet spot areas, the computer system 100 can implement a clustering algorithm on the sweet spot areas determined using the sweet spot formula. For example, the clustering algorithm can be a density-based clustering algorithm (e.g., DBSCAN) that segregates data points into high-density regions separated by low density regions. The DBSCAN algorithm can automatically determine clusters based on the density of the data point. The output of the method step 204 are clustered sweet spot areas in which infill producer wells can be drilled to enhance hydrocarbon recovery through the new producer wells.

[0027] At 206, well criteria associated with the multiple infill producer wells is received. For example, using the input devices, a user of the computer system 100 can provide well criteria for each infill producer well. The criteria can include, for example, a well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field, spacing relative to other infill producer wells, whether the infill producer well is a vertical, horizontal or slanted well, to name a few. Infill producer wells that will be formed in the clustered sweet spot areas will have the criteria received by the computer system in method step 206.

[0028] At 208, a trigger event to trigger forming the infill producer wells is received. The occurrence of the trigger event indicates that infill producer wells need to be drilled. In some implementations, the trigger event is a decrease in production flow rate from the producer wells. Each producer well can be associated with a threshold production flow rate value. Multiple producer wells can be associated with a similar threshold production flow rate value, which can be a summation of the threshold production flow rate value associated with each producer well. The computer system 100 can receive the threshold production flow rate value and store the value in the computer-readable storage medium 103B (FIGS. 1A, 1B). Another example of a trigger event is decrease in hydrocarbon production rate (e.g., measured in barrels per day or billions of barrels per day) below a threshold hydrocarbon production rate value.

[0029] At 210, a determination is made that the trigger event has occurred. As described earlier, the computer system 100 continuously receives various values and signals representing well and flow characteristics from various sensors and flowmeters deployed in and around the producer well. Alternatively or in addition, the occurrence of the trigger event can be determined based on simulation data generated by the computer system 100. The received values include production flow rate from the producer well. The computer system 100 periodically compares the received production flow rate value with the threshold production flow rate value stored in the computer-readable storage medium 103B (FIGS. 1A, 1B). If the received value is less than the threshold production flow rate value, then the computer system 100 determines that the trigger event has occurred. The determination signifies that the production flow rate from the producer well (or wells) has dropped to a level at which EOR techniques need to be implemented. Specifically and in the context of this disclosure, the determination that the trigger event has occurred signifies that infill producer wells need to be drilled according to the well criteria in the sweet spot areas identified as described earlier.

[0030] At 212, in response to determining that the trigger event has occurred, the wellbore drilling machinery are controlled to form multiple infill producer wells according to the well criteria in the multiple sweet spot areas. In particular, the computer system 100 automatically (i.e., without human intervention) controls the wellbore drilling machinery to drill the infill producer wells according to the criteria received at method step 208.

[0031] While drilling the infill producer wells and after the infill producer wells have been drilled, the computer system 100 continues to receive values from the various sensors and flowmeters as described above. The infill producer wells enhance hydrocarbon recovery from the hydrocarbon field by producing hydrocarbons that have migrated through the new producer wells (i.e., the infill producer wells). As the hydrocarbon recovery is enhanced, the values received from the sensors and flowmeters communicate an increase in production flow rate through all producer wells. Alternatively or in addition, the simulation data generated by the computer system 100 communicates an increase in production flow rate through all producer wells. The computer system 100 compares the increased production flow rate with the threshold production flow rate. In particular, the computer system 100 compares the increased production flow from the existing producer wells and any newly formed infill producer wells through which production has commenced. Upon determining that the increased production flow rate is greater than the threshold production flow rate, the computer system 100 stops the wellbore drilling machinery from forming more infill producer wells.

[0032] In addition, while the infill producer wells are implemented to enhance hydrocarbon recovery from the hydrocarbon reservoir, the computer system 100 continues to implement the simulation of the hydrocarbon field. Over time, the hydrocarbon saturation in the field can change as described above. Such change can once again cause the production flow rate from the producer wells to drop below the threshold production flow rate value (or a different trigger event to be triggered). In response, the computer system 100 can once again implement the method 200 to identify sweet spot areas. The computer system 100 can receive criteria for new infill producer wells to be formed in the identified sweet spot areas. The computer system 100 can control wellbore drilling machinery to form the new infill producer wells. In this manner, the computer system 100 can implement an automated workflow of monitoring the hydrocarbon field and automatically forming inflow producer wells to enhance hydrocarbon recovery from the hydrocarbon field.

[0033] FIG. 3 illustrates hydrocarbon production operations 300 that include both one or more field operations 310 and one or more computational operations 312, which exchange information and control exploration for the production of hydrocarbons. In some implementations, outputs of techniques of the present disclosure can be performed before, during, or in combination with the hydrocarbon production operations 300, specifically, for example, either as field operations 310 or computational operations 312, or both.

[0034] Examples of field operations 310 include forming / drilling a wellbore, reservoir characterization, hydraulic fracturing, producing through the wellbore, injecting fluids (such as water) through the wellbore, to name a few. In some implementations, methods of the present disclosure can trigger or control the field operations 310. For example, the methods of the present disclosure can generate data from hardware / software including sensors and physical data gathering equipment (e.g., seismic sensors, well logging tools, flow meters, and temperature and pressure sensors). The methods of the present disclosure can include transmitting the data from the hardware / software to the field operations 310 and responsively triggering the field operations 310 including, for example, generating plans and signals that provide feedback to and control physical components of the field operations 310. Alternatively or in addition, the field operations 310 can trigger the methods of the present disclosure. For example, implementing physical components (including, for example, hardware, such as sensors) deployed in the field operations 310 can generate plans and signals that can be provided as input or feedback (or both) to the methods of the present disclosure.

[0035] Examples of computational operations 312 include one or more computer systems 320 that include one or more processors and computer-readable media (e.g., non-transitory computer-readable media) operatively coupled to the one or more processors to execute computer operations to perform the methods of the present disclosure. The computational operations 312 can be implemented using one or more databases 318, which store data received from the field operations 310 and / or generated internally within the computational operations 312 (e.g., by implementing the methods of the present disclosure) or both. For example, the one or more computer systems 320 process inputs from the field operations 310 to assess conditions in the physical world, the outputs of which are stored in the databases 318. For example, seismic sensors of the field operations 310 can be used to perform a seismic survey to map subterranean features, such as facies and faults. In performing a seismic survey, seismic sources (e.g., seismic vibrators or explosions) generate seismic waves that propagate in the earth and seismic receivers (e.g., geophones) measure reflections generated as the seismic waves interact with boundaries between layers of a subsurface formation. The source and received signals are provided to the computational operations 312 where they are stored in the databases 318 and analyzed by the one or more computer systems 320.

[0036] In some implementations, one or more outputs 322 generated by the one or more computer systems 320 can be provided as feedback / input to the field operations 310 (either as direct input or stored in the databases 318). The field operations 310 can use the feedback / input to control physical components used to perform the field operations 310 in the real world.

[0037] For example, the computational operations 312 can process the seismic data to generate three-dimensional (3D) maps of the subsurface formation. The computational operations 312 can use these 3D maps to provide plans for locating and drilling exploratory wells. In some operations, the exploratory wells are drilled using logging-while-drilling (LWD) techniques which incorporate logging tools into the drill string. LWD techniques can enable the computational operations 312 to process new information about the formation and control the drilling to adjust to the observed conditions in real-time.

[0038] The one or more computer systems 320 can update the 3D maps of the subsurface formation as information from one exploration well is received and the computational operations 312 can adjust the location of the next exploration well based on the updated 3D maps. Similarly, the data received from production operations can be used by the computational operations 312 to control components of the production operations. For example, production well and pipeline data can be analyzed to predict slugging in pipelines leading to a refinery and the computational operations 312 can control machine operated valves upstream of the refinery to reduce the likelihood of plant disruptions that run the risk of taking the plant offline.

[0039] In some implementations of the computational operations 312, customized user interfaces can present intermediate or final results of the above-described processes to a user. Information can be presented in one or more textual, tabular, or graphical formats, such as through a dashboard. The information can be presented at one or more on-site locations (such as at an oil well or other facility), on the Internet (such as on a webpage), on a mobile application (or app), or at a central processing facility.

[0040] The presented information can include feedback, such as changes in parameters or processing inputs, that the user can select to improve a production environment, such as in the exploration, production, and / or testing of petrochemical processes or facilities. For example, the feedback can include parameters that, when selected by the user, can cause a change to, or an improvement in, drilling parameters (including drill bit speed and direction) or overall production of a gas or oil well. The feedback, when implemented by the user, can improve the speed and accuracy of calculations, streamline processes, improve models, and solve problems related to efficiency, performance, safety, reliability, costs, downtime, and the need for human interaction.

[0041] In some implementations, the feedback can be implemented in real-time, such as to provide an immediate or near-immediate change in operations or in a model. The term real-time (or similar terms as understood by one of ordinary skill in the art) means that an action and a response are temporally proximate such that an individual perceives the action and the response occurring substantially simultaneously. For example, the time difference for a response to display (or for an initiation of a display) of data following the individual's action to access the data can be less than 1 millisecond (ms), less than 1 second(s), or less than 5 s. While the requested data need not be displayed (or initiated for display) instantaneously, it is displayed (or initiated for display) without any intentional delay, taking into account processing limitations of a described computing system and time required to, for example, gather, accurately measure, analyze, process, store, or transmit the data.

[0042] Events can include readings or measurements captured by downhole equipment such as sensors, pumps, bottom hole assemblies, or other equipment. The readings or measurements can be analyzed at the surface, such as by using applications that can include modeling applications and machine learning. The analysis can be used to generate changes to settings of downhole equipment, such as drilling equipment. In some implementations, values of parameters or other variables that are determined can be used automatically (such as through using rules) to implement changes in oil or gas well exploration, production / drilling, or testing. For example, outputs of the present disclosure can be used as inputs to other equipment and / or systems at a facility. This can be especially useful for systems or various pieces of equipment that are located several meters or several miles apart, or are located in different countries or other jurisdictions.

[0043] Implementations of the subject matter and the functional operations described in this specification can be implemented in digital electronic circuitry, in tangibly embodied computer software or firmware, in computer hardware, including the structures disclosed in this specification and their structural equivalents, or in combinations of one or more of them. Software implementations of the described subject matter can be implemented as one or more computer programs. Each computer program can include one or more modules of computer program instructions encoded on a tangible, non-transitory, computer-readable computer-storage medium for execution by, or to control the operation of, data processing apparatus. Alternatively, or additionally, the program instructions can be encoded in / on an artificially generated propagated signal. The example, the signal can be a machine-generated electrical, optical, or electromagnetic signal that is generated to encode information for transmission to suitable receiver apparatus for execution by a data processing apparatus. The computer-storage medium can be a machine-readable storage device, a machine-readable storage substrate, a random or serial access memory device, or a combination of computer-storage mediums.

[0044] The terms “data processing apparatus,”“computer,” and “electronic computer device” (or equivalent as understood by one of ordinary skill in the art) refer to data processing hardware. For example, a data processing apparatus can encompass all kinds of apparatus, devices, and machines for processing data, including by way of example, a programmable processor, a computer, or multiple processors or computers. The apparatus can also include special purpose logic circuitry including, for example, a central processing unit (CPU), a field programmable gate array (FPGA), or an application specific integrated circuit (ASIC). In some implementations, the data processing apparatus or special purpose logic circuitry (or a combination of the data processing apparatus or special purpose logic circuitry) can be hardware- or software-based (or a combination of both hardware- and software-based). The apparatus can optionally include code that creates an execution environment for computer programs, for example, code that constitutes processor firmware, a protocol stack, a database management system, an operating system, or a combination of execution environments. The present disclosure contemplates the use of data processing apparatuses with or without conventional operating systems, for example, LINUX, UNIX, WINDOWS, MAC OS, ANDROID, or IOS.

[0045] A computer program, which can also be referred to or described as a program, software, a software application, a module, a software module, a script, or code, can be written in any form of programming language. Programming languages can include, for example, compiled languages, interpreted languages, declarative languages, or procedural languages. Programs can be deployed in any form, including as stand-alone programs, modules, components, subroutines, or units for use in a computing environment. A computer program can, but need not, correspond to a file in a file system. A program can be stored in a portion of a file that holds other programs or data, for example, one or more scripts stored in a markup language document, in a single file dedicated to the program in question, or in multiple coordinated files storing one or more modules, sub programs, or portions of code. A computer program can be deployed for execution on one computer or on multiple computers that are located, for example, at one site or distributed across multiple sites that are interconnected by a communication network. While portions of the programs illustrated in the various figures may be shown as individual modules that implement the various features and functionality through various objects, methods, or processes, the programs can instead include a number of sub-modules, third-party services, components, and libraries. Conversely, the features and functionality of various components can be combined into single components as appropriate. Thresholds used to make computational determinations can be statically, dynamically, or both statically and dynamically determined.

[0046] The methods, processes, or logic flows described in this specification can be performed by one or more programmable computers executing one or more computer programs to perform functions by operating on input data and generating output. The methods, processes, or logic flows can also be performed by, and apparatus can also be implemented as, special purpose logic circuitry, for example, a CPU, an FPGA, or an ASIC.

[0047] Computers suitable for the execution of a computer program can be based on one or more of general and special purpose microprocessors and other kinds of CPUs. The elements of a computer are a CPU for performing or executing instructions and one or more memory devices for storing instructions and data. Generally, a CPU can receive instructions and data from (and write data to) a memory. A computer can also include, or be operatively coupled to, one or more mass storage devices for storing data. In some implementations, a computer can receive data from, and transfer data to, the mass storage devices including, for example, magnetic, magneto optical disks, or optical disks. Moreover, a computer can be embedded in another device, for example, a mobile telephone, a personal digital assistant (PDA), a mobile audio or video player, a game console, a global positioning system (GPS) receiver, or a portable storage device such as a universal serial bus (USB) flash drive.

[0048] Computer readable media (transitory or non-transitory, as appropriate) suitable for storing computer program instructions and data can include all forms of permanent / non-permanent and volatile / non-volatile memory, media, and memory devices. Computer readable media can include, for example, semiconductor memory devices such as random access memory (RAM), read only memory (ROM), phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM), and flash memory devices. Computer readable media can also include, for example, magnetic devices such as tape, cartridges, cassettes, and internal / removable disks. Computer readable media can also include magneto optical disks and optical memory devices and technologies including, for example, digital video disc (DVD), CD ROM, DVD+ / −R, DVD-RAM, DVD-ROM, HD-DVD, and BLURAY. The memory can store various objects or data, including caches, classes, frameworks, applications, modules, backup data, jobs, web pages, web page templates, data structures, database tables, repositories, and dynamic information. Types of objects and data stored in memory can include parameters, variables, algorithms, instructions, rules, constraints, and references. Additionally, the memory can include logs, policies, security or access data, and reporting files. The processor and the memory can be supplemented by, or incorporated in, special purpose logic circuitry.

[0049] Implementations of the subject matter described in the present disclosure can be implemented on a computer having a display device for providing interaction with a user, including displaying information to (and receiving input from) the user. Types of display devices can include, for example, a cathode ray tube (CRT), a liquid crystal display (LCD), a light-emitting diode (LED), and a plasma monitor. Display devices can include a keyboard and pointing devices including, for example, a mouse, a trackball, or a trackpad. User input can also be provided to the computer through the use of a touchscreen, such as a tablet computer surface with pressure sensitivity or a multi-touch screen using capacitive or electric sensing. Other kinds of devices can be used to provide for interaction with a user, including to receive user feedback including, for example, sensory feedback including visual feedback, auditory feedback, or tactile feedback. Input from the user can be received in the form of acoustic, speech, or tactile input. In addition, a computer can interact with a user by sending documents to, and receiving documents from, a device that is used by the user. For example, the computer can send web pages to a web browser on a user's client device in response to requests received from the web browser.

[0050] The term “graphical user interface,” or “GUI,” can be used in the singular or the plural to describe one or more graphical user interfaces and each of the displays of a particular graphical user interface. Therefore, a GUI can represent any graphical user interface, including, but not limited to, a web browser, a touch screen, or a command line interface (CLI) that processes information and efficiently presents the information results to the user. In general, a GUI can include a plurality of user interface (UI) elements, some or all associated with a web browser, such as interactive fields, pull-down lists, and buttons. These and other UI elements can be related to or represent the functions of the web browser.

[0051] Implementations of the subject matter described in this specification can be implemented in a computing system that includes a back end component, for example, as a data server, or that includes a middleware component, for example, an application server. Moreover, the computing system can include a front-end component, for example, a client computer having one or both of a graphical user interface or a Web browser through which a user can interact with the computer. The components of the system can be interconnected by any form or medium of wireline or wireless digital data communication (or a combination of data communication) in a communication network. Examples of communication networks include a local area network (LAN), a radio access network (RAN), a metropolitan area network (MAN), a wide area network (WAN), Worldwide Interoperability for Microwave Access (WIMAX), a wireless local area network (WLAN) (for example, using 802.11 a / b / g / n or 802.20 or a combination of protocols), all or a portion of the Internet, or any other communication system or systems at one or more locations (or a combination of communication networks). The network can communicate with, for example, Internet Protocol (IP) packets, frame relay frames, asynchronous transfer mode (ATM) cells, voice, video, data, or a combination of communication types between network addresses.

[0052] The computing system can include clients and servers. A client and server can generally be remote from each other and can typically interact through a communication network. The relationship of client and server can arise by virtue of computer programs running on the respective computers and having a client-server relationship. Cluster file systems can be any file system type accessible from multiple servers for read and update. Locking or consistency tracking may not be necessary since the locking of exchange file system can be done at application layer. Furthermore, Unicode data files can be different from non-Unicode data files.Examples

[0053] Certain aspects of the subject matter described here can be implemented as a computer-implemented method. The method can be implemented by a computer system. The computer system identifies an area of interest in a hydrocarbon field. The area of interest represents a geographical area in which multiple infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field. The multiple infill producer wells are to be formed through the subterranean zone to produce hydrocarbons. Within the area of interest, the computer system identifies multiple sweet spot areas. Each sweet spot area resides within the geographical area in which the multiple infill producer wells are to be formed. Each sweet spot area represents a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir. The computer system receives well criteria associated with the multiple infill producer wells. The computer system receives a trigger event to trigger forming the multiple infill producer wells in the multiple sweet spot areas. The computer system determines that the trigger event has occurred. In response, the computer system controls wellbore drilling machinery to form the multiple infill producer wells according to the well criteria in the multiple sweet spot areas.

[0054] An aspect combinable with any other aspect includes the following features. The trigger event is a decrease in production flow rate from the producer wells. To receive the trigger event, the computer system receives a threshold production flow rate for multiple producer wells drilled in the hydrocarbon field and through which hydrocarbons are produced.

[0055] An aspect combinable with any other aspect includes the following features. To determine that the trigger event has occurred, the computer system receives a production flow rate value representing the production flow rate through the multiple producer wells. The computer system determines that the received production flow rate value is less than the threshold production flow rate.

[0056] An aspect combinable with any other aspect includes the following features. After controlling the wellbore drilling machinery to form the multiple infill producer wells in the multiple sweet spot areas, the computer system monitors a modified production flow rate value representing the production flow rate through the multiple producer wells and one or more of the multiple infill producer wells through which hydrocarbon production has commenced. In response to the monitoring, determining that the modified production flow rate is greater than the threshold production flow rate. In response to determining that the modified production flow rate value is greater than the threshold production flow rate, controlling the wellbore drilling machinery to stop forming additional infill producer wells.

[0057] An aspect combinable with any other aspect includes the following features. To receive the well criteria, the computer system receives, for each infill producer well, a respective well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field and spacing relative to other infill producer wells.

[0058] An aspect combinable with any other aspect includes the following features. To identify the multiple sweet spot areas within the area of interest, the computer system determines the multiple sweet spot areas using a sweet spot formula and implements a clustering algorithm on the multiple sweet spot areas. The clustering algorithm can be a DBSCAN algorithm.

[0059] An aspect combinable with any other aspect includes the following features. To identify the area of interest, the computer system computationally simulates the hydrocarbon field to generate a computational model of the hydrocarbon field. Within the model, the computer system identifies the area of interest in the hydrocarbon field.

[0060] Certain aspects of the subject matter described here can be implemented as a computer-readable medium storing computer instructions that, when executed by at least one processor, cause the at least one processor to perform operations described here. Certain aspects of the subject matter described here can be implemented as a computer system that includes one or more processors and a computer-readable medium storing computer instructions that, when executed by at least one processor, cause the at least one processors to perform operations described here.

[0061] While this specification contains many specific implementation details, these should not be construed as limitations on the scope of what may be claimed, but rather as descriptions of features that may be specific to particular implementations. Certain features that are described in this specification in the context of separate implementations can also be implemented, in combination, in a single implementation. Conversely, various features that are described in the context of a single implementation can also be implemented in multiple implementations, separately, or in any suitable sub-combination. Moreover, although previously described features may be described as acting in certain combinations and even initially claimed as such, one or more features from a claimed combination can, in some cases, be excised from the combination, and the claimed combination may be directed to a sub-combination or variation of a sub-combination.

[0062] Particular implementations of the subject matter have been described. Other implementations, alterations, and permutations of the described implementations are within the scope of the following claims as will be apparent to those skilled in the art. While operations are depicted in the drawings or claims in a particular order, this should not be understood as requiring that such operations be performed in the particular order shown or in sequential order, or that all illustrated operations be performed (some operations may be considered optional), to achieve desirable results. In certain circumstances, multitasking or parallel processing (or a combination of multitasking and parallel processing) may be advantageous and performed as deemed appropriate.

[0063] Moreover, the separation or integration of various system modules and components in the previously described implementations should not be understood as requiring such separation or integration in all implementations, and it should be understood that the described program components and systems can generally be integrated together in a single software product or packaged into multiple software products.

[0064] Accordingly, the previously described example implementations do not define or constrain the present disclosure. Other changes, substitutions, and alterations are also possible without departing from the spirit and scope of the present disclosure.

[0065] Furthermore, any claimed implementation is considered to be applicable to at least a computer-implemented method; a non-transitory, computer-readable medium storing computer-readable instructions to perform the computer-implemented method; and a computer system comprising a computer memory interoperably coupled with a hardware processor configured to perform the computer-implemented method or the instructions stored on the non-transitory, computer-readable medium.

[0066] Particular implementations of the subject matter have been described. Other implementations are within the scope of the following claims. For example, the actions recited in the claims can be performed in a different order and still achieve desirable results. As one example, some processes depicted in the accompanying figures do not necessarily require the particular order shown, or sequential order, to achieve desirable results.

Examples

examples

[0053]Certain aspects of the subject matter described here can be implemented as a computer-implemented method. The method can be implemented by a computer system. The computer system identifies an area of interest in a hydrocarbon field. The area of interest represents a geographical area in which multiple infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field. The multiple infill producer wells are to be formed through the subterranean zone to produce hydrocarbons. Within the area of interest, the computer system identifies multiple sweet spot areas. Each sweet spot area resides within the geographical area in which the multiple infill producer wells are to be formed. Each sweet spot area represents a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir. The computer system receives well criteria associated with the multiple infill producer wells. The computer system r...

TECHNICAL FIELD

[0001] This disclosure relates to computer-implemented methods, computer-readable media and computer systems to determine placement of and control machinery to form wellbores in hydrocarbon fields.BACKGROUND

[0002] Hydrocarbon entrapped in subsurface reservoirs can be raised to the surface (i.e., produced) by drilling wellbores from the surface to the subsurface reservoirs through a subterranean zone (e.g., a formation, a portion of a formation, multiple formations). The pressure of the subterranean zone causes the hydrocarbons to naturally flow to the surface. Over time, the pressure decreases necessitating secondary and tertiary forms of hydrocarbon recovery (sometimes called enhanced oil recovery or EOR) techniques. One such EOR technique is the formation of injector wells surrounding producer wells, i.e., the wells through which the hydrocarbons are produced to the surface. Injecting fluids (e.g., water) through the injector wells sweeps the hydrocarbons towards the producer wells and ultimately to the surface. Infill drilling is another EOR technique in which additional wells are drilled near existing wells. The infill wells (or infill producer wells) are strategically formed in regions of the subterranean zone in which hydrocarbons are expected to reside.SUMMARY

[0003] This disclosure describes technologies relating to computer-implemented methods, computer-readable media and computer systems to dynamically place infill producer wells in a hydrocarbon field and to control machinery to form such wells through the subterranean zone.

[0004] The details of one or more implementations of the subject matter described in this specification are set forth in the accompanying drawings and the description below. Other features, aspects, and advantages of the subject matter will become apparent from the description, the drawings, and the claims.BRIEF DESCRIPTION OF THE DRAWINGS

[0005] FIGS. 1A and 1B are schematic diagrams of a computer system operatively coupled to a computer monitor that shows a computational model of a hydrocarbon field.

[0006] FIG. 2 is a flowchart of an example of a computer-implemented method of forming infill producer wells in a hydrocarbon field in response to a trigger event.

[0007] FIG. 3 illustrates hydrocarbon production operations that include both one or more field operations and one or more computational operations, which exchange information and control exploration for the production of hydrocarbons.

[0008] Like reference numbers and designations in the various drawings indicate like elements.DETAILED DESCRIPTION

[0009] This disclosure describes computer-implemented methods, computer-readable storage media and computer systems that can implement an automated workflow to place infill producer wells at optimal sweet spots (or sweet spot locations) in a hydrocarbon field. The geographic locations of the infill producer wells are selected based on certain criteria that each infill producer well satisfies, e.g., horizontal, vertical or slanted well. The infill producer wells are formed by wellbore drilling machinery that are controlled to automatically drill the wells in response to a trigger event being triggered. For example, the trigger event can be a drop in production flow rate from producer wells, i.e., all producers that are already drilled, below a certain threshold production flow rate. During and after formation of the infill producer wells, the production flow rate from the producer wells and any newly formed infill producer wells can continue to be monitored. Once the production flow rate increases beyond the threshold production flow, the operations of the wellbore drilling machinery can be stopped. A computer system can implement the process of identifying optimal sweet spots to place the infill producer wells. In parallel, the computer system can also implement the process of monitoring the production flow rate from the producer wells and the newly formed infill producer wells. The operations of the wellbore drilling machinery to form the infill producer wells can be automatically (i.e., without human intervention) be performed by the same computer system.

[0010] Implementing the techniques described here can yield some advantages. Optimal locations for infill producer wells can be determined computationally and automatically without human intervention. The optimal locations for infill producer wells can change over time due to changes in oil saturation over time. Tracking the changes of the optimal locations at each time step would be very time consuming. By implementing the techniques described here, changes to the optimal locations be determined effectively and more efficiently. Such operations can save computational resources and time. Wellbore drilling machinery to form infill producer wells can be controlled using computer systems that implement simulations to determine optimal locations for infill producer wells. Doing so can reduce human error and can also save computational resources.

[0011] FIGS. 1A and 1B are schematic diagrams of a computer system 100 operatively coupled to a computer monitor 102 that shows a computational model 104 of a hydrocarbon field. The computer system includes a computer-readable storage medium 103A and one or more processors 103B. The computer-readable storage medium 103A (e.g., a non-transitory computer-readable storage medium) can store computer instructions that are executable by the one or more processors 103B to perform operations described in this disclosure. A computer monitor 102 (e.g., a display device) can be operatively connected to the computer system 100. The computer system 100 can also be connected to input devices (not shown). The computer system 100 can receive input, e.g., from the input devices or from other sources, process the input and display output on the computer monitor 102.

[0012] In some implementations, the computer system 100 can run a simulation of the hydrocarbon field with the subsurface hydrocarbon reservoirs. The computer system 100 can show the output of the simulation as a model 104 (or a map) on the computer monitor 102. The computer system 100 can implement the simulation to analyze the geographical area covered by the hydrocarbon field. Based on the analysis, the computer system 100 can generate the model 104. The hydrocarbon field can include certain geographic areas that are more saturated with hydrocarbons compared to other geographic areas in the hydrocarbon field. The computer system 100 can show such geographic areas as regions 106 in the model 104. For example, the computer system 100 can show the regions 106 in a different color compared to a color of the rest of the model 104. In this manner, the computer system 100 can implement the simulation to identify specific geographic areas in the hydrocarbon field that are rich in hydrocarbons.

[0013] Producer wells can be formed in such hydrocarbon-rich geographic areas of the hydrocarbon field. For example, wellbore drilling machinery can be used to form each producer well. After completion, each well can be commissioned to produce hydrocarbons from the hydrocarbon-rich geographic areas. Various well and hydrocarbon properties including, for example, a hydrocarbon production flow rate, can be monitored. To do so, various sensors and flowmeters can be deployed above or below the surface of the well and at multiple downhole locations. The values sensed by the sensors and flowmeters including the hydrocarbon production flow rate value can be periodically (e.g., once an hour, once a minute, once per second, more than once per second or other frequency) transmitted to the computer system 100. The computer system 100 can continue to implement the simulation of the hydrocarbon field using the various values received from the various sensors and flowmeters. Alternatively or in addition, the computer system 100 can implement the simulation of the hydrocarbon field using simulation data generated by the computer system 100.

[0014] Turning to the computer monitor 102, each producer well can be represented on the model 104. For example, a user of the computer system 100 can select locations on the model 104 on which the producer wells are formed. In response, the computer system 100 can display representations of the producer well on the model 104. For example, the computer system 100 can display object 108a, object 108b, object 108c, each representing a-producer well, within the regions 106 representing the hydrocarbon-rich geographic areas of the hydrocarbon field. Thus, the model 104 in FIG. 1A schematically shows hydrocarbon-rich geographic areas in the hydrocarbon field and producer wells formed in those areas during the early stages of wellbore production.

[0015] Over time, as more hydrocarbon is produced from the hydrocarbon field, the hydrocarbon saturation levels change. Such change can be due to removal of the hydrocarbons from the hydrocarbon field. Alternatively or in addition, such change can be due to migration of the hydrocarbons within the hydrocarbon field. Migration can also cause hydrocarbons to move away from the hydrocarbon field to adjacent geographic areas and / or cause hydrocarbons from adjacent geographic areas to migrate into the hydrocarbon field. As mentioned above, the computer system 100 continues to implement the simulation of the hydrocarbon field using the various values received from the various sensors and flowmeters over time or using simulation data generated by the computer system 100 (or both).

[0016] FIG. 1B schematically shows a modified model 110 that appears different from the model 106 schematically shown in FIG. 1A. The modified model 110 is a representation of a change in the hydrocarbon saturation levels in the hydrocarbon field. In some instances, the modified model 110 shows that geographic areas saturated in hydrocarbons are no longer near the producer wells drilled during early stages of hydrocarbon production. In such instances, production flow rate through the producer wells can decrease, e.g., below threshold production flow rates. In response, secondary or tertiary EOR techniques can be implemented to enhance production through the hydrocarbon field. Such EOR techniques can include forming infill producer wells in strategic locations in the hydrocarbon field to enhance production through the new producer wells.

[0017] As described below with reference to FIG. 2, the computer system 100 can computationally and automatically (i.e., without human intervention) determine optimal locations for the infill producer wells. To do so, the computer system 100 can use data from the simulation that identifies sweet spots in which infill producer wells can be formed. The computer system 100 can receive input (e.g., from a user of the computer system 100) identifying characteristics of the infill producer wells. Based on data received from the simulation and input identifying characteristics of the infill producer wells, the computer system 100 can automatically control wellbore drilling machinery 112 to form one or more infill producer wells in the hydrocarbon field. In addition, the computer system 100 can display objects (e.g., object 114a, object 114b, object 114c) on the modified model 110. Each object can represent a corresponding infill producer well formed by the wellbore drilling machinery 112. An object representing an infill producer well can have a different appearance compared to an object representing a producer well. As described below, the computer system 100 can control the wellbore drilling machinery 112 to form the infill producer wells in response to a triggering event (e.g., producer wells' production flow rate dropping below a threshold production flow rate).

[0018] FIG. 2 is a flowchart of an example of a computer-implemented method 200 of forming infill producer wells in a hydrocarbon field in response to a trigger event. The infill producer wells can be formed by wellbore drilling machinery. The machinery can be controlled by a computer system (e.g., the computer system 100) based on hydrocarbon saturation data and based on characteristics of the infill producer wells.

[0019] At 202, an area of interest in a hydrocarbon field is identified. The area of interest represents a geographical area in which multiple infill producer wells are to be formed. The area of interest can be certain layers in the subterranean zone or certain geographic areas in the hydrocarbon field or a combination of them. In some implementations, the area of interest can be determined using the simulation described earlier. The computer system 100 can implement the simulations to determine, among other things, hydrocarbon saturation levels in the hydrocarbon field. From the determined hydrocarbon saturation levels, the computer system 100 can identify geographical areas with higher hydrocarbon saturation compared to other geographical areas in the hydrocarbon field. For example, the computer system 100 can compare hydrocarbon saturation values at different locations in the hydrocarbon field. The computer system 100 can determine the hydrocarbon saturation values using data received from multiple sensors deployed across the hydrocarbon field at different depths in the subterranean zone or using simulation data generated by the computer system 100 (or both). The computer system 100 can process the received data to determine the hydrocarbon saturation values. The computer system 100 can then identify a maximum (or a maximum range) of hydrocarbon saturation values based on the comparison. The computer system 100 can then identify the locations at which the maximum (or maximum range) of hydrocarbon saturation values were measured as the area of interest.

[0020] Alternatively or in addition, the computer system 100 can receive the area of interest from a user of the computer system 100. For example, as described above, the computer system 100 can display a model 106 (FIG. 1A) or a modified model 110 (FIG. 1B) that includes representations of geographical areas with hydrocarbon saturation. A user of the computer system 100 can select portions of the model that correspond to geographical areas of high hydrocarbon saturation.

[0021] At 204, multiple sweet spot areas can be identified within the area of interest. The computer system 100 can identify sweet spot areas by solving sweet spot formulas that identify sweet spot areas. For oil reservoirs, the sweet spot formula is shown in Equation 1.Sweet⁢ Spot=So*∅Equation⁢ 1

[0022] In Equation 1, So is the oil saturation and Φ is rock porosity. The oil saturation and rock porosity can be determined based on the simulation implemented by the computer system 100. In one example, if the output of Equation 1 is ≥30%, then that region is a sweet spot area.

[0023] For gas reservoirs, the sweet spot formula is shown in Equation 2.Sweet⁢ Spot=Sg*∅Equation⁢ 2

[0024] In Equation 1, Sg is the gas saturation and Φ is rock porosity. The gas saturation and rock porosity can be determined based on the simulation implemented by the computer system 100.

[0025] The computer system 100 can implement other sweet spot formulas as well. Further, the computer system 100 can implement different sweet spot formulas at different instances of implementing the computer-implemented method 200. For example, an operator of the computer system 100 can select a first sweet spot formula at a first instance of implementing the method 200 and a second, different sweet spot formula at a second, subsequent instance of implementing the method 200.

[0026] In some implementations, to identify the sweet spot areas, the computer system 100 can implement a clustering algorithm on the sweet spot areas determined using the sweet spot formula. For example, the clustering algorithm can be a density-based clustering algorithm (e.g., DBSCAN) that segregates data points into high-density regions separated by low density regions. The DBSCAN algorithm can automatically determine clusters based on the density of the data point. The output of the method step 204 are clustered sweet spot areas in which infill producer wells can be drilled to enhance hydrocarbon recovery through the new producer wells.

[0027] At 206, well criteria associated with the multiple infill producer wells is received. For example, using the input devices, a user of the computer system 100 can provide well criteria for each infill producer well. The criteria can include, for example, a well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field, spacing relative to other infill producer wells, whether the infill producer well is a vertical, horizontal or slanted well, to name a few. Infill producer wells that will be formed in the clustered sweet spot areas will have the criteria received by the computer system in method step 206.

[0028] At 208, a trigger event to trigger forming the infill producer wells is received. The occurrence of the trigger event indicates that infill producer wells need to be drilled. In some implementations, the trigger event is a decrease in production flow rate from the producer wells. Each producer well can be associated with a threshold production flow rate value. Multiple producer wells can be associated with a similar threshold production flow rate value, which can be a summation of the threshold production flow rate value associated with each producer well. The computer system 100 can receive the threshold production flow rate value and store the value in the computer-readable storage medium 103B (FIGS. 1A, 1B). Another example of a trigger event is decrease in hydrocarbon production rate (e.g., measured in barrels per day or billions of barrels per day) below a threshold hydrocarbon production rate value.

[0029] At 210, a determination is made that the trigger event has occurred. As described earlier, the computer system 100 continuously receives various values and signals representing well and flow characteristics from various sensors and flowmeters deployed in and around the producer well. Alternatively or in addition, the occurrence of the trigger event can be determined based on simulation data generated by the computer system 100. The received values include production flow rate from the producer well. The computer system 100 periodically compares the received production flow rate value with the threshold production flow rate value stored in the computer-readable storage medium 103B (FIGS. 1A, 1B). If the received value is less than the threshold production flow rate value, then the computer system 100 determines that the trigger event has occurred. The determination signifies that the production flow rate from the producer well (or wells) has dropped to a level at which EOR techniques need to be implemented. Specifically and in the context of this disclosure, the determination that the trigger event has occurred signifies that infill producer wells need to be drilled according to the well criteria in the sweet spot areas identified as described earlier.

[0030] At 212, in response to determining that the trigger event has occurred, the wellbore drilling machinery are controlled to form multiple infill producer wells according to the well criteria in the multiple sweet spot areas. In particular, the computer system 100 automatically (i.e., without human intervention) controls the wellbore drilling machinery to drill the infill producer wells according to the criteria received at method step 208.

[0031] While drilling the infill producer wells and after the infill producer wells have been drilled, the computer system 100 continues to receive values from the various sensors and flowmeters as described above. The infill producer wells enhance hydrocarbon recovery from the hydrocarbon field by producing hydrocarbons that have migrated through the new producer wells (i.e., the infill producer wells). As the hydrocarbon recovery is enhanced, the values received from the sensors and flowmeters communicate an increase in production flow rate through all producer wells. Alternatively or in addition, the simulation data generated by the computer system 100 communicates an increase in production flow rate through all producer wells. The computer system 100 compares the increased production flow rate with the threshold production flow rate. In particular, the computer system 100 compares the increased production flow from the existing producer wells and any newly formed infill producer wells through which production has commenced. Upon determining that the increased production flow rate is greater than the threshold production flow rate, the computer system 100 stops the wellbore drilling machinery from forming more infill producer wells.

[0032] In addition, while the infill producer wells are implemented to enhance hydrocarbon recovery from the hydrocarbon reservoir, the computer system 100 continues to implement the simulation of the hydrocarbon field. Over time, the hydrocarbon saturation in the field can change as described above. Such change can once again cause the production flow rate from the producer wells to drop below the threshold production flow rate value (or a different trigger event to be triggered). In response, the computer system 100 can once again implement the method 200 to identify sweet spot areas. The computer system 100 can receive criteria for new infill producer wells to be formed in the identified sweet spot areas. The computer system 100 can control wellbore drilling machinery to form the new infill producer wells. In this manner, the computer system 100 can implement an automated workflow of monitoring the hydrocarbon field and automatically forming inflow producer wells to enhance hydrocarbon recovery from the hydrocarbon field.

[0033] FIG. 3 illustrates hydrocarbon production operations 300 that include both one or more field operations 310 and one or more computational operations 312, which exchange information and control exploration for the production of hydrocarbons. In some implementations, outputs of techniques of the present disclosure can be performed before, during, or in combination with the hydrocarbon production operations 300, specifically, for example, either as field operations 310 or computational operations 312, or both.

[0034] Examples of field operations 310 include forming / drilling a wellbore, reservoir characterization, hydraulic fracturing, producing through the wellbore, injecting fluids (such as water) through the wellbore, to name a few. In some implementations, methods of the present disclosure can trigger or control the field operations 310. For example, the methods of the present disclosure can generate data from hardware / software including sensors and physical data gathering equipment (e.g., seismic sensors, well logging tools, flow meters, and temperature and pressure sensors). The methods of the present disclosure can include transmitting the data from the hardware / software to the field operations 310 and responsively triggering the field operations 310 including, for example, generating plans and signals that provide feedback to and control physical components of the field operations 310. Alternatively or in addition, the field operations 310 can trigger the methods of the present disclosure. For example, implementing physical components (including, for example, hardware, such as sensors) deployed in the field operations 310 can generate plans and signals that can be provided as input or feedback (or both) to the methods of the present disclosure.

[0035] Examples of computational operations 312 include one or more computer systems 320 that include one or more processors and computer-readable media (e.g., non-transitory computer-readable media) operatively coupled to the one or more processors to execute computer operations to perform the methods of the present disclosure. The computational operations 312 can be implemented using one or more databases 318, which store data received from the field operations 310 and / or generated internally within the computational operations 312 (e.g., by implementing the methods of the present disclosure) or both. For example, the one or more computer systems 320 process inputs from the field operations 310 to assess conditions in the physical world, the outputs of which are stored in the databases 318. For example, seismic sensors of the field operations 310 can be used to perform a seismic survey to map subterranean features, such as facies and faults. In performing a seismic survey, seismic sources (e.g., seismic vibrators or explosions) generate seismic waves that propagate in the earth and seismic receivers (e.g., geophones) measure reflections generated as the seismic waves interact with boundaries between layers of a subsurface formation. The source and received signals are provided to the computational operations 312 where they are stored in the databases 318 and analyzed by the one or more computer systems 320.

[0036] In some implementations, one or more outputs 322 generated by the one or more computer systems 320 can be provided as feedback / input to the field operations 310 (either as direct input or stored in the databases 318). The field operations 310 can use the feedback / input to control physical components used to perform the field operations 310 in the real world.

[0037] For example, the computational operations 312 can process the seismic data to generate three-dimensional (3D) maps of the subsurface formation. The computational operations 312 can use these 3D maps to provide plans for locating and drilling exploratory wells. In some operations, the exploratory wells are drilled using logging-while-drilling (LWD) techniques which incorporate logging tools into the drill string. LWD techniques can enable the computational operations 312 to process new information about the formation and control the drilling to adjust to the observed conditions in real-time.

[0038] The one or more computer systems 320 can update the 3D maps of the subsurface formation as information from one exploration well is received and the computational operations 312 can adjust the location of the next exploration well based on the updated 3D maps. Similarly, the data received from production operations can be used by the computational operations 312 to control components of the production operations. For example, production well and pipeline data can be analyzed to predict slugging in pipelines leading to a refinery and the computational operations 312 can control machine operated valves upstream of the refinery to reduce the likelihood of plant disruptions that run the risk of taking the plant offline.

[0039] In some implementations of the computational operations 312, customized user interfaces can present intermediate or final results of the above-described processes to a user. Information can be presented in one or more textual, tabular, or graphical formats, such as through a dashboard. The information can be presented at one or more on-site locations (such as at an oil well or other facility), on the Internet (such as on a webpage), on a mobile application (or app), or at a central processing facility.

[0040] The presented information can include feedback, such as changes in parameters or processing inputs, that the user can select to improve a production environment, such as in the exploration, production, and / or testing of petrochemical processes or facilities. For example, the feedback can include parameters that, when selected by the user, can cause a change to, or an improvement in, drilling parameters (including drill bit speed and direction) or overall production of a gas or oil well. The feedback, when implemented by the user, can improve the speed and accuracy of calculations, streamline processes, improve models, and solve problems related to efficiency, performance, safety, reliability, costs, downtime, and the need for human interaction.

[0041] In some implementations, the feedback can be implemented in real-time, such as to provide an immediate or near-immediate change in operations or in a model. The term real-time (or similar terms as understood by one of ordinary skill in the art) means that an action and a response are temporally proximate such that an individual perceives the action and the response occurring substantially simultaneously. For example, the time difference for a response to display (or for an initiation of a display) of data following the individual's action to access the data can be less than 1 millisecond (ms), less than 1 second(s), or less than 5 s. While the requested data need not be displayed (or initiated for display) instantaneously, it is displayed (or initiated for display) without any intentional delay, taking into account processing limitations of a described computing system and time required to, for example, gather, accurately measure, analyze, process, store, or transmit the data.

[0042] Events can include readings or measurements captured by downhole equipment such as sensors, pumps, bottom hole assemblies, or other equipment. The readings or measurements can be analyzed at the surface, such as by using applications that can include modeling applications and machine learning. The analysis can be used to generate changes to settings of downhole equipment, such as drilling equipment. In some implementations, values of parameters or other variables that are determined can be used automatically (such as through using rules) to implement changes in oil or gas well exploration, production / drilling, or testing. For example, outputs of the present disclosure can be used as inputs to other equipment and / or systems at a facility. This can be especially useful for systems or various pieces of equipment that are located several meters or several miles apart, or are located in different countries or other jurisdictions.

[0043] Implementations of the subject matter and the functional operations described in this specification can be implemented in digital electronic circuitry, in tangibly embodied computer software or firmware, in computer hardware, including the structures disclosed in this specification and their structural equivalents, or in combinations of one or more of them. Software implementations of the described subject matter can be implemented as one or more computer programs. Each computer program can include one or more modules of computer program instructions encoded on a tangible, non-transitory, computer-readable computer-storage medium for execution by, or to control the operation of, data processing apparatus. Alternatively, or additionally, the program instructions can be encoded in / on an artificially generated propagated signal. The example, the signal can be a machine-generated electrical, optical, or electromagnetic signal that is generated to encode information for transmission to suitable receiver apparatus for execution by a data processing apparatus. The computer-storage medium can be a machine-readable storage device, a machine-readable storage substrate, a random or serial access memory device, or a combination of computer-storage mediums.

[0044] The terms “data processing apparatus,”“computer,” and “electronic computer device” (or equivalent as understood by one of ordinary skill in the art) refer to data processing hardware. For example, a data processing apparatus can encompass all kinds of apparatus, devices, and machines for processing data, including by way of example, a programmable processor, a computer, or multiple processors or computers. The apparatus can also include special purpose logic circuitry including, for example, a central processing unit (CPU), a field programmable gate array (FPGA), or an application specific integrated circuit (ASIC). In some implementations, the data processing apparatus or special purpose logic circuitry (or a combination of the data processing apparatus or special purpose logic circuitry) can be hardware- or software-based (or a combination of both hardware- and software-based). The apparatus can optionally include code that creates an execution environment for computer programs, for example, code that constitutes processor firmware, a protocol stack, a database management system, an operating system, or a combination of execution environments. The present disclosure contemplates the use of data processing apparatuses with or without conventional operating systems, for example, LINUX, UNIX, WINDOWS, MAC OS, ANDROID, or IOS.

[0045] A computer program, which can also be referred to or described as a program, software, a software application, a module, a software module, a script, or code, can be written in any form of programming language. Programming languages can include, for example, compiled languages, interpreted languages, declarative languages, or procedural languages. Programs can be deployed in any form, including as stand-alone programs, modules, components, subroutines, or units for use in a computing environment. A computer program can, but need not, correspond to a file in a file system. A program can be stored in a portion of a file that holds other programs or data, for example, one or more scripts stored in a markup language document, in a single file dedicated to the program in question, or in multiple coordinated files storing one or more modules, sub programs, or portions of code. A computer program can be deployed for execution on one computer or on multiple computers that are located, for example, at one site or distributed across multiple sites that are interconnected by a communication network. While portions of the programs illustrated in the various figures may be shown as individual modules that implement the various features and functionality through various objects, methods, or processes, the programs can instead include a number of sub-modules, third-party services, components, and libraries. Conversely, the features and functionality of various components can be combined into single components as appropriate. Thresholds used to make computational determinations can be statically, dynamically, or both statically and dynamically determined.

[0046] The methods, processes, or logic flows described in this specification can be performed by one or more programmable computers executing one or more computer programs to perform functions by operating on input data and generating output. The methods, processes, or logic flows can also be performed by, and apparatus can also be implemented as, special purpose logic circuitry, for example, a CPU, an FPGA, or an ASIC.

[0047] Computers suitable for the execution of a computer program can be based on one or more of general and special purpose microprocessors and other kinds of CPUs. The elements of a computer are a CPU for performing or executing instructions and one or more memory devices for storing instructions and data. Generally, a CPU can receive instructions and data from (and write data to) a memory. A computer can also include, or be operatively coupled to, one or more mass storage devices for storing data. In some implementations, a computer can receive data from, and transfer data to, the mass storage devices including, for example, magnetic, magneto optical disks, or optical disks. Moreover, a computer can be embedded in another device, for example, a mobile telephone, a personal digital assistant (PDA), a mobile audio or video player, a game console, a global positioning system (GPS) receiver, or a portable storage device such as a universal serial bus (USB) flash drive.

[0048] Computer readable media (transitory or non-transitory, as appropriate) suitable for storing computer program instructions and data can include all forms of permanent / non-permanent and volatile / non-volatile memory, media, and memory devices. Computer readable media can include, for example, semiconductor memory devices such as random access memory (RAM), read only memory (ROM), phase change memory (PRAM), static random access memory (SRAM), dynamic random access memory (DRAM), erasable programmable read-only memory (EPROM), electrically erasable programmable read-only memory (EEPROM), and flash memory devices. Computer readable media can also include, for example, magnetic devices such as tape, cartridges, cassettes, and internal / removable disks. Computer readable media can also include magneto optical disks and optical memory devices and technologies including, for example, digital video disc (DVD), CD ROM, DVD+ / −R, DVD-RAM, DVD-ROM, HD-DVD, and BLURAY. The memory can store various objects or data, including caches, classes, frameworks, applications, modules, backup data, jobs, web pages, web page templates, data structures, database tables, repositories, and dynamic information. Types of objects and data stored in memory can include parameters, variables, algorithms, instructions, rules, constraints, and references. Additionally, the memory can include logs, policies, security or access data, and reporting files. The processor and the memory can be supplemented by, or incorporated in, special purpose logic circuitry.

[0049] Implementations of the subject matter described in the present disclosure can be implemented on a computer having a display device for providing interaction with a user, including displaying information to (and receiving input from) the user. Types of display devices can include, for example, a cathode ray tube (CRT), a liquid crystal display (LCD), a light-emitting diode (LED), and a plasma monitor. Display devices can include a keyboard and pointing devices including, for example, a mouse, a trackball, or a trackpad. User input can also be provided to the computer through the use of a touchscreen, such as a tablet computer surface with pressure sensitivity or a multi-touch screen using capacitive or electric sensing. Other kinds of devices can be used to provide for interaction with a user, including to receive user feedback including, for example, sensory feedback including visual feedback, auditory feedback, or tactile feedback. Input from the user can be received in the form of acoustic, speech, or tactile input. In addition, a computer can interact with a user by sending documents to, and receiving documents from, a device that is used by the user. For example, the computer can send web pages to a web browser on a user's client device in response to requests received from the web browser.

[0050] The term “graphical user interface,” or “GUI,” can be used in the singular or the plural to describe one or more graphical user interfaces and each of the displays of a particular graphical user interface. Therefore, a GUI can represent any graphical user interface, including, but not limited to, a web browser, a touch screen, or a command line interface (CLI) that processes information and efficiently presents the information results to the user. In general, a GUI can include a plurality of user interface (UI) elements, some or all associated with a web browser, such as interactive fields, pull-down lists, and buttons. These and other UI elements can be related to or represent the functions of the web browser.

[0051] Implementations of the subject matter described in this specification can be implemented in a computing system that includes a back end component, for example, as a data server, or that includes a middleware component, for example, an application server. Moreover, the computing system can include a front-end component, for example, a client computer having one or both of a graphical user interface or a Web browser through which a user can interact with the computer. The components of the system can be interconnected by any form or medium of wireline or wireless digital data communication (or a combination of data communication) in a communication network. Examples of communication networks include a local area network (LAN), a radio access network (RAN), a metropolitan area network (MAN), a wide area network (WAN), Worldwide Interoperability for Microwave Access (WIMAX), a wireless local area network (WLAN) (for example, using 802.11 a / b / g / n or 802.20 or a combination of protocols), all or a portion of the Internet, or any other communication system or systems at one or more locations (or a combination of communication networks). The network can communicate with, for example, Internet Protocol (IP) packets, frame relay frames, asynchronous transfer mode (ATM) cells, voice, video, data, or a combination of communication types between network addresses.

[0052] The computing system can include clients and servers. A client and server can generally be remote from each other and can typically interact through a communication network. The relationship of client and server can arise by virtue of computer programs running on the respective computers and having a client-server relationship. Cluster file systems can be any file system type accessible from multiple servers for read and update. Locking or consistency tracking may not be necessary since the locking of exchange file system can be done at application layer. Furthermore, Unicode data files can be different from non-Unicode data files.Examples

[0053] Certain aspects of the subject matter described here can be implemented as a computer-implemented method. The method can be implemented by a computer system. The computer system identifies an area of interest in a hydrocarbon field. The area of interest represents a geographical area in which multiple infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field. The multiple infill producer wells are to be formed through the subterranean zone to produce hydrocarbons. Within the area of interest, the computer system identifies multiple sweet spot areas. Each sweet spot area resides within the geographical area in which the multiple infill producer wells are to be formed. Each sweet spot area represents a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir. The computer system receives well criteria associated with the multiple infill producer wells. The computer system receives a trigger event to trigger forming the multiple infill producer wells in the multiple sweet spot areas. The computer system determines that the trigger event has occurred. In response, the computer system controls wellbore drilling machinery to form the multiple infill producer wells according to the well criteria in the multiple sweet spot areas.

[0054] An aspect combinable with any other aspect includes the following features. The trigger event is a decrease in production flow rate from the producer wells. To receive the trigger event, the computer system receives a threshold production flow rate for multiple producer wells drilled in the hydrocarbon field and through which hydrocarbons are produced.

[0055] An aspect combinable with any other aspect includes the following features. To determine that the trigger event has occurred, the computer system receives a production flow rate value representing the production flow rate through the multiple producer wells. The computer system determines that the received production flow rate value is less than the threshold production flow rate.

[0056] An aspect combinable with any other aspect includes the following features. After controlling the wellbore drilling machinery to form the multiple infill producer wells in the multiple sweet spot areas, the computer system monitors a modified production flow rate value representing the production flow rate through the multiple producer wells and one or more of the multiple infill producer wells through which hydrocarbon production has commenced. In response to the monitoring, determining that the modified production flow rate is greater than the threshold production flow rate. In response to determining that the modified production flow rate value is greater than the threshold production flow rate, controlling the wellbore drilling machinery to stop forming additional infill producer wells.

[0057] An aspect combinable with any other aspect includes the following features. To receive the well criteria, the computer system receives, for each infill producer well, a respective well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field and spacing relative to other infill producer wells.

[0058] An aspect combinable with any other aspect includes the following features. To identify the multiple sweet spot areas within the area of interest, the computer system determines the multiple sweet spot areas using a sweet spot formula and implements a clustering algorithm on the multiple sweet spot areas. The clustering algorithm can be a DBSCAN algorithm.

[0059] An aspect combinable with any other aspect includes the following features. To identify the area of interest, the computer system computationally simulates the hydrocarbon field to generate a computational model of the hydrocarbon field. Within the model, the computer system identifies the area of interest in the hydrocarbon field.

[0060] Certain aspects of the subject matter described here can be implemented as a computer-readable medium storing computer instructions that, when executed by at least one processor, cause the at least one processor to perform operations described here. Certain aspects of the subject matter described here can be implemented as a computer system that includes one or more processors and a computer-readable medium storing computer instructions that, when executed by at least one processor, cause the at least one processors to perform operations described here.

[0061] While this specification contains many specific implementation details, these should not be construed as limitations on the scope of what may be claimed, but rather as descriptions of features that may be specific to particular implementations. Certain features that are described in this specification in the context of separate implementations can also be implemented, in combination, in a single implementation. Conversely, various features that are described in the context of a single implementation can also be implemented in multiple implementations, separately, or in any suitable sub-combination. Moreover, although previously described features may be described as acting in certain combinations and even initially claimed as such, one or more features from a claimed combination can, in some cases, be excised from the combination, and the claimed combination may be directed to a sub-combination or variation of a sub-combination.

[0062] Particular implementations of the subject matter have been described. Other implementations, alterations, and permutations of the described implementations are within the scope of the following claims as will be apparent to those skilled in the art. While operations are depicted in the drawings or claims in a particular order, this should not be understood as requiring that such operations be performed in the particular order shown or in sequential order, or that all illustrated operations be performed (some operations may be considered optional), to achieve desirable results. In certain circumstances, multitasking or parallel processing (or a combination of multitasking and parallel processing) may be advantageous and performed as deemed appropriate.

[0063] Moreover, the separation or integration of various system modules and components in the previously described implementations should not be understood as requiring such separation or integration in all implementations, and it should be understood that the described program components and systems can generally be integrated together in a single software product or packaged into multiple software products.

[0064] Accordingly, the previously described example implementations do not define or constrain the present disclosure. Other changes, substitutions, and alterations are also possible without departing from the spirit and scope of the present disclosure.

[0065] Furthermore, any claimed implementation is considered to be applicable to at least a computer-implemented method; a non-transitory, computer-readable medium storing computer-readable instructions to perform the computer-implemented method; and a computer system comprising a computer memory interoperably coupled with a hardware processor configured to perform the computer-implemented method or the instructions stored on the non-transitory, computer-readable medium.

[0066] Particular implementations of the subject matter have been described. Other implementations are within the scope of the following claims. For example, the actions recited in the claims can be performed in a different order and still achieve desirable results. As one example, some processes depicted in the accompanying figures do not necessarily require the particular order shown, or sequential order, to achieve desirable results.

Examples

examples

[0053]Certain aspects of the subject matter described here can be implemented as a computer-implemented method. The method can be implemented by a computer system. The computer system identifies an area of interest in a hydrocarbon field. The area of interest represents a geographical area in which multiple infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field. The multiple infill producer wells are to be formed through the subterranean zone to produce hydrocarbons. Within the area of interest, the computer system identifies multiple sweet spot areas. Each sweet spot area resides within the geographical area in which the multiple infill producer wells are to be formed. Each sweet spot area represents a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir. The computer system receives well criteria associated with the multiple infill producer wells. The computer system r...

Claims

1. A computer-implemented method comprising:identifying, by one or more processors, an area of interest in a hydrocarbon field, the area of interest representing a geographical area in which a plurality of infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field, the plurality of infill producer wells to be formed through the subterranean zone to produce hydrocarbons;identifying, by the one or more processors and within the area of interest, a plurality of sweet spot areas, each sweet spot area residing within the geographical area in which the plurality of infill producer wells are to be formed, each sweet spot area representing a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir;receiving, by the one or more processors, well criteria associated with the plurality of infill producer wells;receiving, by the one or more processors, a trigger event to trigger forming the plurality of infill producer wells in the plurality of sweet spot areas;determining, by the one or more processors, that the trigger event has occurred; andin response to determining that the trigger event has occurred, controlling, by the one or more processors, wellbore drilling machinery to form the plurality of infill producer wells according to the well criteria in the plurality of sweet spot areas.

2. The computer-implemented method of claim 1, wherein the trigger event is a decrease in production flow rate from the producer wells, wherein receiving the trigger event comprises receiving a threshold production flow rate for a plurality of producer wells drilled in the hydrocarbon field and through which hydrocarbons are produced.

3. The computer-implemented method of claim 2, wherein determining that the trigger event has occurred comprises:receiving, by the one or more processors, a production flow rate value representing the production flow rate through the plurality of producer wells; anddetermining, by the one or more processors, that the received production flow rate value is less than the threshold production flow rate.

4. The computer-implemented method of claim 3, further comprising, after controlling the wellbore drilling machinery to form the plurality of infill producer wells in the plurality of sweet spot areas:monitoring a modified production flow rate value representing the production flow rate through the plurality of producer wells and a production flow rate through one or more of the plurality of infill producer wells through which hydrocarbon production has commenced;in response to the monitoring, determining that the modified production flow rate value is greater than the threshold production flow rate;in response to determining that the modified production flow rate value is greater than the threshold production flow rate, controlling the wellbore drilling machinery to stop forming additional infill producer wells.

5. The computer-implemented method of claim 1, wherein receiving, by the one or more processors, the well criteria comprises, for each infill producer well, receiving a respective well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field and spacing relative to other infill producer wells.

6. The computer-implemented method of claim 1, wherein identifying the plurality of sweet spot areas within the area of interest comprises:determining the plurality of sweet spot areas using a sweet spot formula; andimplementing a clustering algorithm on the plurality of sweet spot areas.

7. The computer-implemented method of claim 6, wherein identifying the area of interest comprises:computationally simulating the hydrocarbon field to generate a computational model of the hydrocarbon field; andidentifying, within the model, the area of interest in the hydrocarbon field.

8. A computer-readable medium storing computer instructions that, when executed by at least one processor, cause the at least one processor to perform operations comprising:identifying an area of interest in a hydrocarbon field, the area of interest representing a geographical area in which a plurality of infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field, the plurality of infill producer wells to be formed through the subterranean zone to produce hydrocarbons;identifying, within the area of interest, a plurality of sweet spot areas, each sweet spot area residing within the geographical area in which the plurality of infill producer wells are to be formed, each sweet spot area representing a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir;receiving well criteria associated with the plurality of infill producer wells;receiving a trigger event to trigger forming the plurality of infill producer wells in the plurality of sweet spot areas;determining that the trigger event has occurred; andin response to determining that the trigger event has occurred, controlling wellbore drilling machinery to form the plurality of infill producer wells according to the well criteria in the plurality of sweet spot areas.

9. The computer-readable medium of claim 8, wherein the trigger event is a decrease in production flow rate from the producer wells, wherein receiving the trigger event comprises receiving a threshold production flow rate for a plurality of producer wells drilled in the hydrocarbon field and through which hydrocarbons are produced.

10. The computer-readable medium of claim 9, wherein determining that the trigger event has occurred comprises:receiving a production flow rate value representing the production flow rate through the plurality of producer wells; anddetermining that the received production flow rate value is less than the threshold production flow rate.

11. The computer-readable medium of claim 10, wherein the operations further comprise, after controlling the wellbore drilling machinery to form the plurality of infill producer wells in the plurality of sweet spot areas:monitoring a modified production flow rate value representing the production flow rate through the plurality of producer wells and a production flow rate through one or more of the plurality of infill producer wells through which hydrocarbon production has commenced;in response to the monitoring, determining that the modified production flow rate value is greater than the threshold production flow rate;in response to determining that the modified production flow rate value is greater than the threshold production flow rate, controlling the wellbore drilling machinery to stop forming additional infill producer wells.

12. The computer-readable medium of claim 8, wherein receiving the well criteria comprises, for each infill producer well, receiving a respective well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field and spacing relative to other infill producer wells.

13. The computer-readable medium of claim 8, wherein identifying the plurality of sweet spot areas within the area of interest comprises:determining the plurality of sweet spot areas using a sweet spot formula; andimplementing a clustering algorithm on the plurality of sweet spot areas.

14. The computer-readable medium of claim 13, wherein identifying the area of interest comprises:computationally simulating the hydrocarbon field to generate a computational model of the hydrocarbon field; andidentifying, within the model, the area of interest in the hydrocarbon field.

15. A computer system comprising:one or more processors; anda computer-readable medium storing computer instructions that, when executed by the one or more processors, cause the one or more processors to perform operations comprising:identifying an area of interest in a hydrocarbon field, the area of interest representing a geographical area in which a plurality of infill producer wells are to be formed in a subterranean zone extending from a surface to a hydrocarbon reservoir in the hydrocarbon field, the plurality of infill producer wells to be formed through the subterranean zone to produce hydrocarbons;identifying, within the area of interest, a plurality of sweet spot areas, each sweet spot area residing within the geographical area in which the plurality of infill producer wells are to be formed, each sweet spot area representing a geographical area in which hydrocarbons are entrapped in the hydrocarbon reservoir;receiving well criteria associated with the plurality of infill producer wells;receiving a trigger event to trigger forming the plurality of infill producer wells in the plurality of sweet spot areas;determining that the trigger event has occurred; andin response to determining that the trigger event has occurred, controlling wellbore drilling machinery to form the plurality of infill producer wells according to the well criteria in the plurality of sweet spot areas.

16. The computer-readable medium of claim 15, wherein the trigger event is a decrease in production flow rate from the producer wells, wherein receiving the trigger event comprises receiving a threshold production flow rate for a plurality of producer wells drilled in the hydrocarbon field and through which hydrocarbons are produced.

17. The computer-readable medium of claim 16, wherein determining that the trigger event has occurred comprises:receiving a production flow rate value representing the production flow rate through the plurality of producer wells; anddetermining that the received production flow rate value is less than the threshold production flow rate.

18. The computer-readable medium of claim 17, wherein the operations further comprise, after controlling the wellbore drilling machinery to form the plurality of infill producer wells in the plurality of sweet spot areas:monitoring a modified production flow rate value representing the production flow rate through the plurality of producer wells and a production flow rate through one or more of the plurality of infill producer wells through which hydrocarbon production has commenced;in response to the monitoring, determining that the modified production flow rate value is greater than the threshold production flow rate;in response to determining that the modified production flow rate value is greater than the threshold production flow rate, controlling the wellbore drilling machinery to stop forming additional infill producer wells.

19. The computer-readable medium of claim 15, wherein receiving the well criteria comprises, for each infill producer well, receiving a respective well length, azimuth angle, production constraints, collision distance with existing wells in the hydrocarbon field and spacing relative to other infill producer wells.

20. The computer-readable medium of claim 15, wherein identifying the plurality of sweet spot areas within the area of interest comprises:determining the plurality of sweet spot areas using a sweet spot formula; andimplementing a clustering algorithm on the plurality of sweet spot areas, wherein the clustering algorithm is a density-based spatial clustering of applications with noise (DBSCAN).

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