SYSTEM AND METHOD FOR CONTROLLING WELL OPERATIONS

TECHNICAL FIELD

This disclosure generally relates to production of oil and/or gas. In particular, the present disclosure relates to a system and method for monitoring and controlling operations that are performed on an oil and/or gas well.

BACKGROUND

Hydraulic fracturing, also referred to as fracking, is a known operation for stimulating production of oil and/or gas from a subterranean formation through a well. Briefly, when a wellbore of the well has been drilled, cased and/or lined and optionally cemented, a perforation apparatus that includes a bridge-plug assembly and a perforation-gun unit can be introduced into the wellbore by a wireline system.

The bridge-plug assembly includes one or more bridge plugs that, when deployed in the well, can form a fluid tight seal across the inner surface of the wellbore. The perforation-gun unit includes one or more individual guns, each of which may carry multiple, shaped-charges, chemical perforating assemblies and/or mechanical perforating assemblies. When a gun is activated it can detonate one or more charges to perforate the casing (or liner as the case may be) and any surrounding cement. These perforations establish fluid communication between the surface and the formation adjacent the perforated section of the well, uphole of the deployed bridge plug. Once fluid communication is established, high-pressure fluids can be pumped down the wellbore from the surface and into the formation to create cracks therein. A material, referred to as proppant, is often carried by the high-pressure fluids to the formation from the surface. The proppant can travel into the cracks to hold them open so that oil and/or gas trapped within the formation can flow therethrough and into the wellbore for production up to the surface.

In order to set the bridge plug and cause perforations at multiple desired locations, the perforation apparatus can be moved into and through different well sections. Some well sections may be substantially vertical and some well sections may deviate towards substantially horizontal. The wireline system facilitates moving the perforation apparatus to a desired location in the well. Often times, fluids are also pumped into the wellbore at the surface to facilitate further moving of the perforation apparatus to a desired location within the well. The fluid are pumped into the well by a pump-down system.

For example, during a fracking operation the perforation apparatus is moved within the well so that a bridge plug can be deployed at a desired location within the well. Once the bridge plug is set, the perforation apparatus can be moved again so that perforation-gun unit can cause perforations at a further desired location within the well. Each time the perforation apparatus is: deployed into the well, moved to a desired location within the well, activated (to deploy a bridge plug and/or to fire a gun) and returned to surface, it can be referred to as a run.

A fracking operation often includes multiple runs of the perforation apparatus so the steps of deploying a bridge plug and activating the perforation-gun unit can repeated at different desired-locations within the wellbore. Typically, the steps are performed furthest from the surface first and then sequentially performed advancing closer to the surface. This allows for a number of desired locations of the well to establish fluid communication with different parts of the formation, which ultimately may increase the production of oil and/or gas from the formation as a whole.

In order for the perforation apparatus to be moved to each desired location within the well the wireline system operator and the pump-down system operator can work together.

A fracking operation is a complicated operation that requires multiple operators, such as wireline system operators and pump-down system operators, to work together in order to complete the fracking operation in a safe and efficient manner. The fracking operation can be further complicated when the pump-down system includes more than one pump-down trucks. For example, multiple pump-down trucks require further personnel be present at the wellsite, which can increase costs. Communication between the wireline system operators and the multiple pump-down operators is important to achieve an efficient operational balance between the wireline system parameters (such as wireline speed, tension and depth) and the pump down system parameters (such as pump-down rate, pressure and volume). If such operational balance is not achieved, then operational issues can arise including, but not limited to: deploying a bridge plug at the wrong location, perforating the well at the wrong location, damaging the wireline system, damaging the bridge plugs, damaging components of the perforation apparatus, damaging the well, using unnecessary or excessive amounts of pump-down fluid, damaging components of the pump-down system, over pressuring of wellsite pumping infrastructure or combinations thereof.

SUMMARY

The embodiments of the present disclosure provide for monitoring and supervising of operations that are being performed on a well. Some embodiments of the present disclosure relate a system and a method for controlling operations that are being performed on a well. Some embodiments of the present disclosure relate to one or more systems and methods that allow a wellsite supervisor to monitor and supervise and to control the well operation from a location that is physically distanced from where the well operation is being conducted. Some embodiments of the present disclosure

Some embodiments of the present disclosure relate to a computerized method for optimizing a pump-down wireline operation that is being performed on a well. The method comprising the steps of: collecting operational data of the operation from a wireline data acquisition system (WDAS) and/or from a pump-down data acquisition system (PDAS); defining a wireline speed-and-tension threshold value; defining a pump-down rate threshold value; analyzing the collected operational data with the defined wireline speed-and-tension threshold value(s) and/or the defined pump-down rate threshold value in real time; determining in real time if an adjustment of the operation is suitable for optimizing the well operation based on the step of analyzing. The adjustment comprises: changing a speed of the wireline and/or changing a pump-down rate. The method further comprises a step of displaying on a client-computing device the operational data and the adjustment.

Some embodiments of the present disclosure relate to a system for optimizing a pump-down wireline operation that is being performed on a well. The system comprising: a memory; a networking interface configured for communicating with a wireline data acquisition system (WDAS), a pump-down data acquisition system (PDAS), at least one computing device; and at least one processing structure functionally coupled to the memory and the networking interface. The at least one processing structure is configured for: collecting operational data in real time from the WDAS and/or the PDAS and determining in real time if an adjustment of the operation is suitable for optimizing the well operation based on analyzing the collected operational data, a wireline speed-and-tension threshold value(s) and a pump-down rate threshold value. The adjustment comprises: changing the wireline speed or changing a pump-down rate of a pump-down pumping system or both. The at least one processing structure may also be configured to transmit the operational data and the adjustment to a client-computing device for viewing by a user.

Without being bound to any particular theory, embodiments of the present disclosure can reduce the number of personnel that are required to attend a wellsite in order to operate the wireline system, the pump-down system or both. Some embodiments of the present disclosure may provide control of the wireline system, the pump-down system or both. Some embodiments of the present disclosure relate to systems and methods that provide control of the wireline system, the pump-down system or both that employs a feedback system so that the control is at least partially automated. These embodiments of the present disclosure may increase an operational balance between the wireline system and the pump-down system, which may increase the overall efficiency of the well operation and reduce the incidence of operational issues.

BRIEF DESCRIPTION OF THE DRAWINGS

These and other features of the present disclosure will become more apparent in the following detailed description in which reference is made to the appended drawings.

FIG. 1 is a schematic diagram of a system, according to embodiments of this disclosure, for monitoring and/or controlling an operation being performed on an oil and/or gas well;

FIG. 2 is a schematic diagram of a hardware structure of a computing device of the system of FIG. 1;

FIG. 3 is a schematic diagram of operational hardware components of a computing device of the system of FIG. 1, wherein FIG. 3A shows operational hardware components of a wireline data acquisition system; and, FIG. 3B shows operational hardware components of a pump down data acquisition system;

FIG. 4 is a schematic diagram of a simplified software architecture of a computing device of the system shown in FIG. 1;

FIG. 5 is a block diagram illustrating a functional structure of the system shown in FIG. 1;

FIG. 6 is a flowchart illustrating a method, according to embodiments of the present disclosure, for monitoring and controlling an operation being performed on an oil and/or gas well, wherein FIG. 6A illustrates a first embodiment of the method; and, FIG. 6B illustrates a second embodiments of the method; and

FIG. 7 is shows further embodiments of the present disclosure, wherein FIG. 7A shows a block diagram illustrating a functional structure of the system shown in FIG. 1 with a further perforation automation module, according to embodiments of the present disclosure; and, FIG. 7B is flow chart illustrating a method for automatically setting a plug and/or firing a gun upon a downhole perforation assembly.

DETAILED DESCRIPTION

Embodiments of the present disclosure relate to systems and methods for monitoring, controlling and/or and supervising an operation that is being performed on an oil and/or gas well. In some embodiments of the present disclosure the operation is one or more of a completion operation, a workover operation or a stimulating operation. In some embodiments of the present disclosure the operation is a stimulating operation that includes one or more fracturing steps. In some embodiments of the present disclosure, the one or more fracturing steps include a step of perforating and plugging a wellbore. The step of perforating and plugging the wellbore includes the steps of introducing a perforation apparatus into the well. The perforation apparatus may also be referred to as a downhole apparatus or a tool string. The perforation apparatus includes a bridge-plug assembly and a perforation-gun unit. The one or more fracturing steps includes the steps of deploying a bridge plug within the well at or proximal to a first desired location, positioning the perforation-gun unit at a first desired location within the wellbore, and detonating one or more charges upon the perforation-gun unit at the first desired location.

The perforation apparatus is introduced, positioned and operated within the wellbore by a wireline system and a pump-down system.

Typically, the wireline system includes a wireline truck with a spool for introducing (and retrieving) wireline into a well. The wireline system delivers the perforation apparatus into and out of the well and it can include a wireline data acquisition system (WDAS) that receives data from one or more operational hardware units, such as sensors, that are part of the wireline system. Typical WDAS receive at least the following operational wireline data from one or more sensors: the amount of wireline that has been deployed (depth), the speed at which the wireline was deployed (speed), the tension on the wireline (tension), downhole positional data provided by a casing collar location (CCL) system or combinations thereof.

The wireline system can include further sub-systems by which the perforation apparatus is activated and the actions of the bridge-plug assembly and the perforation-gun unit are controlled and monitored. For example, a fire computer system is managed by a user who is in charge of activating the perforation apparatus. The fire computer system sends electrical signals from surface to the bridge plug assembly for setting a bridge plug and to the perforation-gun unit for activating one or more of the guns at a time. The fire computer system can apply a digital time-stamp to each time that an electrical signal is sent to the perforation-gun unit, or not. Typical fire computer systems do not provide any further specific data, such as the position of the perforation-gun unit when it is activated. The fire computer system may share data with the WDAS including but not limited to: voltage, current, whether a charge was detonated, whether a plug was set, pressure, gamma ray log data, caliper log data, or combinations thereof.

The perforation apparatus is also positioned within the wellbore with the assistance of the pump-down system. The pump-down system includes one or more mobile pumping units that are configured to deliver pump-down fluids into the wellbore at desired volume rates and pressures. The pump-down fluids exert several forces on the perforation apparatus, when in the well, to convey the perforation apparatus down hole. The pump-down fluids can generate a pressure differential between a portion of the wellbore that is uphole (i.e. between the surface and an upper surface of the perforation apparatus) from the perforation apparatus and a portion of the wellbore that is downhole (i.e. between a lower surface of the perforation apparatus and towards the end of the well that is furthest from the surface) from the perforation apparatus. When the pressure differential is higher uphole from the perforation apparatus than downhole, that will assist with moving the perforation apparatus further downhole. When the pressure differential is lower uphole from the perforation apparatus than downhole, that may assist with moving the perforation apparatus uphole to wards the surface. The pump-down system can help move the perforation apparatus when moving through a substantially vertical-section of the well in order to move the perforation apparatus faster than gravity alone will allow. The pump-down system can also move the perforation apparatus through one or more sections of the well that deviate from substantially vertical, including substantially horizontal-sections of the well and sections of the well that are positioned between the substantially vertical-section and the substantially horizontal-sections.

The pump-down system further includes a pump-down data acquisition system (PDAS). A typical PDAS receives at least the following operational pump-down data from one or more operational hardware units, such as one or more sensors, regarding the active pumping units, such data including but not limited to: the pumping rate, the discharge pressure, the inlet pressure, the revolutions per minute (RPM), the gear selection, the engine temperature, the engine oil pressure, the pump oil pressure, the pump temperature, the valve position, the exhaust gas temperature or combinations thereof.

Currently, the WDAS and the PDAS do not share their respective operational data with each other or to any other common system. The implications of this lack of sharing of operational data is that effective and safe movement of the perforation apparatus within the well relies entirely upon human interaction, which is fallible. For example, in order to use both the wireline system and the pump-down system to move the perforation tool through the well requires that there is a balance of the forces exerted by these two systems. As but one example, bridge plug manufacturers provide various recommended operational parameters, including but not limited to: a recommended wireline speed, a recommended pump-down volume rate, a maximum wireline speed, a maximum pump-down volume rate, a maximum bypass rate (the maximum pump-down rate that is allowable while the plug is stationary in the well) for their respective bridge-plug products, which can be determined from both WDAS and PDAS operational data. The embodiments of the present disclosure relate to methods and systems that provide real-time operational data from one or both of the WDAS and PDAS allowing for computer-derived management of well operation in an effort to adhere to a bridge-plug manufacturer's recommendations operational parameters.

Furthermore, once the fracturing operation is completed, typically, the plugs must be drilled out. It is important for the rig performing the drill-out work to know the location of the set plugs within the well. If the plug was set higher than actually recorded then the drill-out rig may inadvertently crash into a set plug causing damage to the drilling tool string. If a set plug is set lower than recorded then there will be a loss of time and reduction in efficiency as the drill-out rig will slow down long before encountering the expected position of the set plug.

When performing analysis of a well site operation, for example after completion, if the incorrect plug and perforation information is provided then the analysis will result in incorrect findings that can have larger implications on designing future plug-and-perforation operations and future fracturing operations.

Prior to the embodiments of the present disclosure, to verify that the plugs are being set at the correct location and that shots are begin fired at the correct location an oil company would require a company representative to be present to confirm all of the plug and shot depths are correct. This company representative would then have to spend time manually entering that information into a well database repository—an inefficient use of a high-skilled person's time. Oftentimes, such data is not entered correctly, which can result in operational decisions being made based upon incorrect well database information.

As will be appreciated by those skilled in the art, the typical approach for monitoring and supervising well operations requires a wellsite supervisor to be present at each well site where operations are occurring. Because the well sites are often in very remote locations, a great deal of resources must be utilized to transport these individuals to each well site, house them near the well site and to provide a safe well site for all of the individuals to work at. Furthermore, because operations often run twenty-four hours, multiple individuals are required at the well site to cover all shifts. In contrast, the embodiments of the present disclosure relate to methods and systems that provide real-time operational data to a wireline supervisor and other authorized users that can be remote from the geographic location where the well operation is being performed. This allows a single supervisor to monitor and supervise multiple well operations that may be occurring at different and geographically spaced apart locations.

Embodiments of the present disclosure will be described further below with reference to the figures, which show representations of a system and method according to the present disclosure.

FIG. 1 shows one embodiment of a system 100 for monitoring and controlling a pump down and wireline operation that is being performed on an oil and/or gas well 108. The system 100 includes various hardware components, including not limited to: one or more server computers 102 (also referred to herein as a server), one or more client-computing devices 104, and one or more operation devices 106, such as a wireline system 106A and a pump-down system 107. The one or more server computers 102 and the one or more client-computing devices may collectively be referred to herein as computing devices. The system 100 is configured to allow one or more users, each with a client-computing device 104, to monitor and control the progression of the pump down and wireline operation that is being performed on the well 108. In some embodiments of the present disclosure, one or more of the server computers 102 or one or more of the client-computing devices 104 can receive, in real time, sensory information regarding the operation, such as information about operational parameters of the wireline system 106A and the pump down system 107. The one or more server computers 102 or one or more of the client-computing devices 104 can then analyze the received sensory information, execute one or more instructions and, optionally, automatically change an operational parameter of the wireline system 106A and/or the pump-down system 107 with minimal or no further input from the one or more users.

The one or more users can include one or more operators, such as but not limited to: a wireline system operator, a pump-down pump operator, a wellhead valve operator, a fracturing system operator, a provider of another well service that is being provided in conjunction with the operation or combinations thereof. Typically, the one or more operators are physically present at the site where the well 108 is located in order to perform the operation or to provide any other applicable well service.

The one or more users also includes a wellsite supervisor, also referred to herein as a supervisor. A supervisor is an individual who is responsible for the operation being performed on the well 108 according to the operational plan and, often times, the safety and efficiency of all other operations being performed on the 108, the well site and/or well pad. In some instances, the supervisor is responsible for multiple operations being performed on multiple wells that may be at the same well site/pad or not. As such, the supervisor can be physically present at the wellsite of the well 108, or not. If the supervisor is physically present at the well site, they can be physically located at a different location than the components that are at the wellsite to perform the operation. For example, when using the system 100 the supervisor need not be physically present within a wireline truck or a pump-down truck when the operation is being performed on the well 108. For clarity, when the supervisor is not physically present within a wireline truck or a pump-down truck, they are considered to be located remotely from the operation.

The one or more server computers 102, one or more client-computing devices 104, and one or more operation devices 106 (such as 106A, 106B) are functionally interconnected by a network 110, such as the Internet, a local area network (LAN), a wide area network (WAN), a metropolitan area network (MAN), or combinations thereof via suitable wired and wireless networking connections.

Each server computer 102 executes one or more server programs. The server computer 102 may be a dedicated server and/or a general-purpose computing device which may be used by a user while acting as a server.

All users of the system 100 can receive and transmit information and data, such as operational data generated by one or more sensors regarding the operation being performed on the well through the system 100 via one or more client-computing devices 104. The client-computing devices 104 may each be a desktop computer, a laptop computer, a tablet, a smartphone, a Personal Digital Assistant (PDA) or combinations thereof. Each client-computing device 104 executes one or more client application programs for use by each user.

The computing devices 102/104 may each have a general hardware structure 120 such as is shown in FIG. 2. Generally, computing devices 102/104 includes a processing structure 122, a controlling structure 124, memory or storage 126, a networking interface 128, a coordinate input 130, a display output 132, and other input and output modules 134 and 136, all of which are operatively connected by a system bus 138.

The processing structure 122 may be one or more single-core or multiple-core computing processors and are preferably microprocessors such as INTEL®, ARM®, AMD® architectures or combinations thereof.

The controlling structure 124 includes a plurality of controllers such as graphic controllers, input/output chipsets or combinations thereof, for coordinating operations of various hardware components and modules of the computing device 102/104.

The memory 126 includes a plurality of memory units. The processing structure 122 and the controlling structure 124 may read and/or store data, including input data and data generated by the processing structure 122 and the controlling structure 124, within these memory units. The memory 126 may be volatile and/or non-volatile, non-removable or removable memory such as RAM, ROM, EEPROM, solid-state memory, hard disks, CD, DVD, flash memory or combinations thereof. In use, the memory 126 is generally divided into different sections for different purposes. For example, a section of the memory 126 (denoted as storage memory herein) is for long-term data storing, such as storing databases or files. Another section of the memory 126 is for storing data during processing, which can also be referred to as working memory. The networking interface 128 includes one or more networking modules for connecting to other computing devices or networks through the network 110 by using wired or wireless communication technologies such as Ethernet, BLUETOOTH®, ZIGBEE®, 3G, 4G, 5G, 6G, other wireless mobile telecommunications technologies/protocols, or combinations thereof. In some embodiments of the present disclosure, parallel ports, serial ports, USB connections, optical connections, or combinations thereof can be used for connecting with other computing devices or networks; however, these connections can also be considered as input/output interfaces for connecting input/output devices.

The display output 132 includes one or more display modules for displaying images to a user. Display modules include but are not limited to: monitors, LCD displays, LED displays, projectors or combinations thereof. The display output 132 may be a physically integrated part of the computing device 102/104 (for example, the display of a laptop computer or tablet), or the display output 132 may be a display device that is physically separate from but functionally coupled to other components of the computing device 102/104. For example, display output 132 can be the monitor of a desktop computer. The display output 132 is configured to display graphic and/or text reports from the system 100 for the user to receive operational display information, including warnings, as described further below.

The coordinate input 130 includes one or more input modules for one or more users to input coordinate data, such as touch-sensitive screen, touch-sensitive whiteboard, trackball, computer mouse, touch-pad, or combinations thereof. The coordinate input 130 may be a physically integrated part of the computing device 102/104 (for example, the touch-pad of a laptop computer, the touch-sensitive screen of a tablet or combinations thereof), or the coordinate input 130 may be a display device that is physically separated from but functionally coupled to other components of the computing device 102/104 (for example, a computer mouse). The coordinate input 130 in some implementations may be integrated with the display output 132 to form a touch-sensitive screen or a touch-sensitive writing board.

The computing devices 102/104 may also include other input devices 134 such as keyboards, microphones, scanners, cameras, speakers, printers, or combinations thereof. In some embodiments of the present disclosure, at least one client-computing device 104 may also include a positioning component such as a Global Positioning System (GPS) component for determining the position thereof. Optionally, at least one client-computing device 104 is functionally coupled to an external GPS device for determining the position of the client-computing device 104.

The system bus 138 interconnects various of the components 122 to 136 and the system bus 138 is configured to enable these components to transmit and receive data and control signals to and from each other.

In some embodiments of the present disclosure, the pump down and wireline operation is part of a stimulating operation that is performed on one or more oil and/or gas wells. The operation can include one or more fracturing steps. In some embodiments of the present disclosure, the one or more fracturing steps include a step of perforating and plugging the well 108. The perforating and plugging step includes the steps of deploying a bridge plug within the well 108 proximal to a first desired location, positioning the perforation-gun unit at a first desired location within the wellbore, and detonating one or more charges upon the perforating gun at the first desired location. In some embodiments of the present disclosure, the perforation apparatus is introduced into, positioned and operated within the well 108 by a wireline system 106A. The positioning of the perforation apparatus within the well further includes a step of pumping down fluids from the surface into the well to assist in moving the perforation apparatus within the well 108. The wireline system 106A includes a wireline truck with a spool for introducing (and retrieving) wireline into (and from) the well 108. The perforation apparatus is functionally coupled to an end of the wireline that enters the well 108.

The well 108 can have a substantially vertical wellbore with or without non-vertical sections. The step of pumping down fluids from the surface can assist in moving the perforation apparatus downhole through substantially vertical sections of the well and along non-vertical sections of the well.

FIG. 3 shows a non-limiting example of systems and hardware that form operational components that contribute to a wireline data acquisition system (WDAS) 400 of the wireline system 106A (see FIG. 3A) and a pump down data acquisition system (PDAS) 500 of the pump down system 107 (see FIG. 3B).

As shown in the non-limiting example of FIG. 3A, the operational components of the WDAS 400 provide operational data, also referred to herein as operational sensory information, that includes sensory information, regarding one or more operational parameters of the wireline system 106A. This sensory information includes one or more of, but is not limited to: one or more sensors 404 of the wireline system 106A, a casing collar locator system 406, a fire control system 408 and other systems 410.

The wireline system 106A includes the one or more sensors 404 that provide operational information regarding the wireline operational parameters including, but not limited to: depth that the wireline has reached based upon the amount of wireline that has been unspooled (or respooled), speed at which the wireline is moving (either into or out of the well), tension of the wireline or combinations thereof.

The casing collar locator system 406 provides operational information regarding the position of the perforation apparatus within the well 108.

In some embodiments of the present disclosure, the fire control system 408 includes a client-computing device 104, as described above. The fire control system 106D is configured to send operational information regarding the parameters of electrical signals that are conducted along the wireline to the perforation apparatus to set plugs and detonate charges. The fire control system 106D can provide a variety of operational information and data to the system 100, including a digital time-stamp as to when an electrical signal was sent to set a plug or detonate a charge, the specific plug that was intended to be set, the specific charge that was intended to be fired, the total number of charges that were detonated, the voltage of the electrical signal, the current of the electrical signal or combinations thereof.

The other systems 410 can provide operational information regarding pressure within the wellbore, gamma ray log information, caliper log information, well identity, impression block information or combinations thereof. As will be appreciated by those skilled in the art, each of these operational components of the WDAS 400 are typically separate from each other and not configured to be interconnected with each other as they are in the embodiments of the present disclosure.

As shown in the non-limiting example of FIG. 3B, the operational components of the PDAS 500 provide operational sensory information regarding one or more operational parameters of the pump down system 107. This operational sensory information may include information from one or more of, but is not limited to: one or more sensors 504 of the pump down system 107, one or more engine sensors 506, one or more oil sensors 508, one or more valve sensors 510, one or more temperature sensors 512 or combinations thereof.

The one or more sensors 504 provide information regarding operational parameters of the pump-down fluids that the pump down system 107 is forcing down into the well 108. These one or more sensors 504 may comprise a volumetric rate sensor, a pump down pressure sensor or combinations thereof.

The one or more engine sensors 506 provide information regarding operational parameters of the engine that is driving the pump-down pump. These one or more engine sensors 506 may comprise an RPM sensor, a gear selection sensor or combinations thereof.

The one or more oil sensors 508 provide information regarding operational parameters of the oil within the engine that is driving the pump-down pump and the oil within the pump. These one or more engine oil sensors 508 may comprise an oil temperature sensor, an engine oil pressure sensor, a pump oil temperature sensor, a pump oil pressure sensor or combinations thereof.

The one or more valve sensors 510 provide information regarding operational parameters of one or more valves through which the pump-down pump is pumping (or not). The one or more valve sensors 510 can be positional sensors that indicate whether a given valve is open or closed.

The one or more temperature sensors 512 provide information regarding operational parameters of various other temperatures relating to the pump-down system 107, such as but not limited to information detected and provided by an exhaust-gas temperature sensor.

FIG. 4 shows a simplified software architecture 200 of the computing device 102/104. The software architecture 200 includes an operating system 202, one or more application programs 204, logic memory 206, an input interface 208, an output interface 210, and a network interface 212.

The operating system 202 manages various hardware components of the computing device 102/104 via the input interface 208 and the output interface 210, manages logic memory 206, manages network communications via the network interface 212, and manages and supports the application programs 204, which are executed or run by the processing structure 122 for performing various tasks.

As will be appreciated by those skilled in the art, the operating system 202 may be any suitable operating system such as MICROSOFT® WINDOWS®, APPLE® OS X, APPLE® iOS, Linux, ANDROID®, or combinations thereof. The computing devices 102/104 in the system 100 may all have the same operating system, or may have different operating systems.

The input interface 208 includes one or more input-device drivers managed by the operating system 202 for communicating with respective input devices including the coordinate input 130 and the other input 134. The output interface 210 includes one or more output-device drivers managed by the operating system 202 for communicating with respective output devices including the display output 132 and other output 136. Input data received from the input devices via the input interface 208 may be sent to one or more application programs 204 for processing. The output generated by the application programs 204 may be sent to respective output devices via the output interface 210.

The logical memory 206 is a logical mapping of the physical memory 126 for facilitating access by the application programs 204. In this embodiment, the logical memory 206 includes a storage memory area that is usually mapped to non-volatile physical memory, such as hard disks, solid state disks, flash drives, or combinations thereof, for generally long-term storage of data therein. The logical memory 206 also includes a working memory area that is generally mapped to high-speed, and in some implementations volatile, physical memory such as RAM, for the operating system 202 and/or application programs 204 to generally temporarily store data during program execution. For example, an application program 204 may load data from the storage memory area into the working memory area, and may store data generated during its execution into the working memory area. The application program 204 may also store some data into the storage memory area as required or in response to a user's command.

A server computer 102 or a client-computing device 104 when acting as a server computer 102 generally includes one or more server application programs 204, which provide server-side functions for managing the system 100.

In general, a client-computing device 104 includes one or more client application programs 204. A client application programs 204 provides client-side functions for communicating with the server application programs 204, displaying information and data on the graphic user interface (GUI) thereof, receiving user's instructions, and collaborating with the server application programs 204 for managing the system 100.

FIG. 5 is a block diagram showing a functional structure 700 of the system 100. The functional structure 700 may be implemented by one or more server application programs and/or one or more client application programs.

The functional structure 700 comprises the WDAS 400 and the PDAS 500 both of which are operatively connected to a processing device 300. For clarity, the processing device 300 can be the processing structure 122 of the computing device 102/104. The processing device 300 is operatively connected to a pump-down wireline operation interface 302. The interface 302 may be displayed on a computing device 102/104 so that a user can view the operational information provided by the WDAS 400 and the PDAS 500, optionally in real time. The operational information may be provided to the interface 302 on a periodic basis, upon request by a user through the interface 302 or both.

The functional structure 700 further includes a wireline controller 312 and a pump-down controller 314. The wireline controller 312 is operatively connected to a wireline system controller 402. The wireline system controller 402 is operatively coupled to the WDAS 400 and to the components that control the wireline system 106A. For example, the wireline system controller 402 can regulate a wireline brake system and/or a wireline spool motor system. In some embodiments of the present disclosure, the wireline system controller 402 can change or maintain: the braking force applied by the wireline drum brake, functionality of a wireline drum motor controller, functionality of a wireline drum guide position, engine speed of the wireline truck, gear selection of the wireline truck engine, PTO engagement, generator output, sensor output filtering, offsets and adjustments or combinations thereof. In some embodiments, the wireline controller 312 provides automated control of the wireline system controller 402 so that the depth of the wireline within the well can be changed, at constant or variable rates. The wireline controller 312 may also provide automated control over the operations of the perforation apparatus, via the automated control over the wireline system controller 402. For example, when a command is initiated in the interface 302 to change the speed at which the perforation apparatus is moving within the well 108, one or more operational parameters of the wireline system 106A can be changed to change the speed at which the perforation apparatus is actually moving within the well 108.

In some embodiments, the wireline system controller 402 is also controllable via a remote wireline controller (not shown). The remote wireline controller can provide a user the ability to control the position of the perforation apparatus in the well 108 and the operations of the perforation apparatus. This user can be physically located at a location that is remote from where the wireline system 106A is positioned and operating. For example, in some embodiments of the present disclosure, the remote wireline controller can change or maintain, via the wireline system controller 402 or directly: the braking force applied by the wireline drum brake, functionality of a wireline drum motor controller, functionality of a wireline drum guide position, engine speed of the wireline truck, gear selection of the wireline truck engine, PTO engagement, generator output, sensor output filtering, offsets and adjustments or combinations thereof. The remote wireline controller may also regulate functionalities of pressure-control equipment such as a wireline blow-out preventer, a tool trap, the pumping rate and pressure of a grease head, and functionalities of greaseless pressure-containment equipment. The interface between the remote wireline controller, the wireline system controller 402 and these systems can be achieved via a combination of electronic, pneumatic and hydraulic systems.

The pump-down controller 314 is operatively connected to a pump down system controller 502. The pump down system controller 502 is operatively coupled to the PDAS 500 and to the components of that control the pump down system 107. For example, the pump-down controller 314 can change the volumetric rate at which the pump-down pump is operating and this will either increase or decrease the pump-down rate, which in turn can influence the rate at which the perforation apparatus is moving within the well 108. The pump-down controller 314 may change: the position of one or more valves, such as inlet vales, discharge valves and bleed-off valves, pumping rates and pressures of a supply pump, engine speed and pressure, pump-down truck engine or motor speed, gear selection, pumping rate, pumping pressure, lubrication systems, greasing systems or combinations thereof. The pump-down controller 314 may achieve this control through a combination of electronic, pneumatic or hydraulic systems. Such that, when a command is initiated in the interface 302 to change the speed at which the perforation apparatus is moving within the well 108, and therefore the position of the perforation apparatus within the well 108, one or more operational parameters of the wireline system 106A can be changed as can one or more operational parameters of the pump down system 107. As discussed further below, the embodiments of the present disclosure may relate to two general categories of commands, a user-generated adjustment command and an automated adjustment command.

In some embodiments of the present disclosure, the pump down system controller 502 is also controllable via a remote pump-down controller (not shown). The remote pump-down controller can provide a user the ability to control one or more operational parameters of the pump down system 107 and this user can be physically located at a location that is remote from where the pump down system 107 is positioned and operating.

The interface 302 allows a user to receive and view the operational sensor information provided by the WDAS 400 and the PDAS 500. In some embodiments of the present disclosure, the interface 302 can allow a user to change an operational parameter by making an adjustment of one or both of the wireline system 106A and the pump-down system 107. For example, a user may initiate a user adjustment command via the interface 302 that is sent to the wireline controller 312 to cause the wireline system controller 402 to apply more or less of a brake force via the wireline brake system and/or to increase or decrease the speed of the wireline spool motor system to change the rate or direction that the wireline spool is rotating. Additionally, or alternatively, the user may initiate a different user adjustment command via the interface 302 that is sent to the pump-down controller 314 to cause the pump down system controller 502 to increase or decrease the volumetric rate at which pump-down fluids are pumped into the well 108.

In some embodiments of the present disclosure, the processing device 300 may be operatively coupled to an automation controller 304. For example, the automation controller 304 may be an application program 204 that is in a computer understandable format that can be executed by the general hardware 120 of the processing deice 300. The automation controller 304 can receive the operational information provided by the WDAS 400 and the PDAS 500 via the processor device 300. The automation controller 304 can analyze the operational information, determine if an adjustment is required and automatically generate an automated adjustment command that is sent to either or both of the wireline controller 312 and the pump-down controller 314.

Upon receipt of the automated adjustment command, the wireline controller 312 may change the speed at which the wireline is being moved downhole or pulled uphole by changing the operational parameters of the wireline brake system and/or the wireline spool motor system. For example, upon receiving an automated adjustment instruction, the wireline controller 312 may increase or decrease the speed at which the wireline spool is rotating, change the direction that the wireline spool is rotating, stop the wireline spool from rotating or combinations thereof.

Upon receipt of an automated adjustment instruction, the pump-down controller 314 may change the rate at which the pump-down pump is delivering fluids into the well 108. For example, upon receiving an automated adjustment instruction, the pump-down controller 314 may increase the volume of fluids delivered over time, decrease the volume of fluids delivered over time or stop the delivery of fluids into the well 108.

In some embodiments of the present disclosure, the automation controller 304 comprises a wireline speed and tension controller 306. The controller 306 may be populated with predetermined thresholds for the tension along the wireline, as detected by one or more tension sensors of the wireline sensors 404. The predetermined tension thresholds can include an upper tension threshold, which is indicative of the maximum tension under which the wireline system 106A can safely operate. Operating the wireline system 106A above the upper tension threshold increases the risk that the wireline may break. The predetermined tension thresholds can also include a lower threshold, which is indicative of the minimum tension under which the wireline system 106A can safely and effectively operate. Operating the wireline system 106 below the minimum tension threshold may cause unravelling of the wireline off the wireline spool and other problems with the perforation apparatus. There are a number of factors that influence the tension of the wireline, including but not limited to: the operational parameters of the wireline braking system, the operational parameters of the wireline spool motor system, the weight of the unspooled wireline and the tools (including the perforation apparatus) connected thereto, the conditions within the well 108 such as any features within the well 108. Well features can include a change in direction of the well 108, a narrowing of the well's 108 inner diameter, an enlargement of the well's 108 inner diameter, debris within the well 108 or combinations thereof. The pump-down rate can also influence the tension of the wireline. For example, the outer diameter of the tools (including the perforation apparatus) connected to the wireline, the wellbore inner diameter and the viscosity of the pump-down fluids can each, or in combination, influence the tension of the wireline.

In some embodiments of the present disclosure, the automation controller 304 comprises a wireline speed and pump-down rate controller 308. The pump-down controller 308 can be populated with predetermined thresholds for the pump-down rate. In some embodiments of the present disclosure, a set of predetermined rate thresholds are based upon the specifications of the tools (including the perforation apparatus) that are connected to the wireline. For example, a plug manufacturer can provide specifications for individual plugs regarding the upper rate threshold. If the upper rate threshold is exceeded then the plug may become damaged, set improperly or combinations thereof. The controller 308 may also be populated with predetermined flush-by rates, as provided by the plug manufacturer or otherwise. If the upper rate threshold and/or an upper flush-by rate threshold are exceeded, then the plug may become damaged, set improperly, experience other malfunctions or combinations thereof. Based upon the predetermined thresholds, the controller 308 may calculate an optimal pump-down rate and wireline speed relationship. For example, the controller 308 may employ the following equation:

Wireline speed=((sin θ(Fg)/m)+((4/pi)×Q/D²))×T) (Eqn. 1)

where:

- (sin θ(Fg)/m) is the acceleration of the tool string
- sin θ=angle deviation of a section of the well from vertical
- Fg=acceleration due to gravity
- m=mass of the plug and perforation tool string
- (4/pi)×Q/D²) calculates the fluid velocity
- Q=flow (m³/s)—pump-down rate
- D=diameter (m²)—wellbore inner diameter/area
- T=tension friction factor, which accounts for the tension of the wireline, outer diameter of the tool string and the extent to which the pump-down fluid is influencing the movement of the tool string within the well.

Based upon the calculated optimal pump-down rate and wireline speed and tension relationship and the received operational sensory information received from the WDAS 400 and the PDAS 500, the controller 308 can generate an automated adjustment command that is sent via the processor 300 (optionally with the command displayed on the interface 302 for a user to view) to either or both of the wireline controller 312 and the pump-down controller 314 to cause an adjustment to be made in the speed at which the wireline is moving in the well and/or the volumetric rate at which the pump down system 107 is introducing pump-down fluids into the well 108. The wireline speed and tension controller 306 and the pump-down controller 308 may work together based off controller 308's determinations using Eqn. 1, where wireline speed may be set as a desired outcome, the pump-down controller 308 contributes to the wireline speed by implementing certain predetermined limitations (for example, the maximum allowable pump rate and the maximum allowable tension) and the tension and drum speed are controlled by the wireline speed and tension controller 306 but these aspects may also impacted by many other factors—as such a feedback control system may be useful. For example, the feedback control system may be a proportional integral derivative controller (PID controller) may be used to establish a control loop that continuously calculates an error value (for example the difference between a current wireline speed and target wireline speed) and then the PID controller may generate a command to apply a change to some controlled variable (such as pump-down rate or tension) to reduce the error value.

In some embodiments of the present disclosure, the system 100 further comprises a well identifier module 600. The well identifier module 600 provides well identity information to the processor 300 and it may also be displayed on the interface 302. The well identity information relates to the specific well that is receiving the pump down and wireline operation. For example, the well 108 may be located on a well pad with multiple wells that are each receiving different operations at different times. The well identity information allows the system 100 to identify which well is receiving given pump down and wireline operation.

In some embodiments of the present disclosure, the well identifier module 600 can receive the well identity information from a well identifier device 106B that is physically connected to the well 108 that is receiving (or is about to receive) the operation. The well identifier device 106B can be a variety of devices that generate a signal that is receivable by the system 100 for identifying which well 108 is receiving the operation. Examples of such well identifier devices 106B include sensors that identify if a well: has a wireline lubricator connected thereto, has other components that relate to other well operations connected thereto; or combinations thereof including one or more of a real-time locator system, a global positioning locator system; a proximity sensory system; an acoustic sensory system; a radio frequency identifier system; a light detection and ranging (LIDAR) system; a machine vision system; the well identifier devices and the magnetic sensor perforation apparatus described in PCT/CA2019/050890, the entire contents of which are incorporated herein by reference, or combinations thereof. In some embodiments of the present disclosure, the well identifier module 600 can receive a manual input by a user to update or change the identity information of the well 108 that is receiving the operation. In some embodiments of the present disclosure, the well identity information can be automatically updated or changed as the well identity device 106B is moved to a new well, changed by a user or a combination thereof.

In some embodiments of the present disclosure, the system 100 further comprises an operational plan module 602. The operational plan module 602 can be populated with the pump down and wireline plan for the well 108 that will receive the pump down and wireline operation. This operational plan may include the specific configuration of the perforation apparatus that will be used, the specifications of the one or more plugs deployed thereupon and the specifications of the charges deployed thereupon. The operational plan may also include the predetermined locations within the well 108 where an operational event, such as deploying a plug or detonating one or more charges, is desired to occur. For example, the well 108 can be divided into a number of specific stages and the operational plan will establish which operational events are desired to occur within each stage of the well 108. The operational plan may also include a schematic of the well 108 itself that identifies any known well features that could influence the pump down and wireline operation, such as the kick off point, changes in the inner diameter of the well 108, further changes in the direction of the well 108 and the like.

The well identifier module 600 and the operational plan module 602 can share their respective operational information with the processing device 300 and with a depth controller 310. The depth controller 310 receives the well identity information in order to cross reference the received operational plan information to determine what depth the perforation apparatus should be pumped down to in the well 108. The depth controller 310 will also identify sections of the well 108 that include one or more well features and it will analyze how those features within the identified well section could influence the pump-down rate. The depth controller 310 can also receive operational sensor information from the WDAS 400 and/or the PDAS 500 to assess the location of the perforation apparatus within the well 108. Based upon the depth controller's 310 analysis of the well identity information, the operational plan information and the well location information, the depth controller 310 can generate an automated adjustment command that is sent to the processing device 300 and the wireline controller 312 and/or the pump-down controller 314 to adjust one or more parameters of the wireline system 106A or the pump down system 107. For example the depth controller 310 can automatically adjust the position of the perforation apparatus by controlling the relationship between the wireline speed, the wireline tension and the pump-down rate to accommodate real time changes in any of these operational parameters to deliver the perforation apparatus to the desired location within the well 108 according to the operational plan.

Some embodiments of the present disclosure relate to a computerized method 800 for optimizing a pump-down wireline operation that is being performed on a well 108 (FIG. 6A). The method 800 comprises a step of collecting 802 operational data of the operation from a wireline data acquisition system (WDAS) and/or from a pump-down data acquisition system (PDAS). The method 800 also includes a step of defining 804 a wireline speed-and-tension threshold value and defining 806 a pump-down rate threshold value. The method further includes a step of analyzing 808 the collected operational data with the defined wireline speed and tension threshold value and the defined pump-down rate threshold value in real-time. Next, the method 800 includes a step of determining 810 in real time if an adjustment of the operation is suitable for optimizing the well operation based on the step of analyzing 808. The adjustment may comprise a step of changing 812 a speed or direction of the wireline or changing 814 a pump-down rate (see FIG. 6B). The method 800 further includes a step of displaying 816 on a client-computing device the operational data and the determined adjustment. In some embodiments of the present disclosure, concurrent with, before or after the step of displaying 816 occurs, a user may engage the processing device 300 via an interface 302 in order to take steps in order to effect the determined adjustment. In some embodiments of the present disclosure, concurrent with, before or after the step of displaying 816 occurs, the automation controller 304 may take steps in order to effect the determined adjustment.

In some embodiments of the present disclosure, the method 800 can further include a step of receiving 818 well identification information and/or an operational plan and a step of determining 820 a position of the tool string within the well by analyzing the WDAS operational data with the identification information and the operational plan.

The method 800 may further include a step of determining 822 in real time whether the perforation apparatus is approaching a wellbore feature in such a fashion that is suitable for making a further adjustment of the operation based on analyzing the position of the perforation apparatus relative to the wellbore feature. The further adjustment can be effected by a step of changing 824 the speed of the wireline and/or changing 826 the pump-down rate. The further adjustment can also include a step of adjusting sensor information, for example if CCL information indicates a discrepancy between the detected depth of a wellbore feature, such as a casing collar or marker joint, and the expected depth then an offset value may be applied to adjust the sensor derived depth information. The method 800 can further include a step of displaying 828 the further adjustment upon the client-computing device. In some embodiments of the present disclosure, concurrent with, before or after the step of displaying 828 occurs, a user may engage the processing device 300 via the interface 302 in order to take steps in order to effect the further adjustment. In some embodiments of the present disclosure, concurrent with, before or after the step of displaying 828 occurs, the automation controller 304 may take steps in order to effect the further adjustment.

In some embodiments of the present disclosure, the steps of displaying 816 and displaying 828 can on a client-computing device that is remote from a location where the operational data is collected.

In some embodiments of the present disclosure, the system 100 further comprises the functionality required to automatically control operation of a perforation assembly, optionally in conjunction with the determined adjustments and further adjustments described herein above.

In some embodiments of the present disclosure, the system 100 may further comprise a stage identifier module 901, which in conjunction with the well identifier module 600 can determine what predetermined information should be used in order to automate operation of the perforation assembly, via a perforation automation controller 900 (see FIG. 7A). The stage identifier module 901 can receive information from the operational plan module 602 regarding the operational plan that is predetermined to be performed on a given stage of the well, including the specifications of any plug that is predetermined to be set within a given stage and the associated operational limits of the plugs. The perforation automation controller 900 comprises software and hardware that is in operational communication, either directly or through the processing device 300, with a firing panel 902 for the purposes of setting a plug or firing shots at the correct depth under the correct operating limits and requirements which are determined by the wireline system controller 402 and the toolstring location controller 410, discussed further below. The perforation automation controller 900 can receive information from the well identifier module 600 and the stage identifier module 901 in order to determine how to adjust the wireline system and/or the pump-down system so that a given plug can be set in the predetermined fashion. For example, each plug's operational limits can determine the recommended wireline speed and the pump-down rate for the plug's size and for the inner diameter of the tubular within the stage where the plug is moving or predetermined to be set. As such, the perforation automation controller 900 may be operationally coupled to the wireline system controller 402, via the processing device 300, in order to ensure that the wireline is not moving at too high of a rate. Because the pump-down system fluids can also influence the rate at which the plug, upon the perforation assembly, is moving within the well the perforation automation controller 900 may also be operationally coupled to the pump-down controller 502, for example via the processing device 300.

The perforation automation controller 900 may also receive further information regarding the charges upon the perforation assembly, such as but not limited to: the number of guns upon the perforation assembly, the number of charges of each gun, the type of each gun and the minimum distance from the casing collar for safe firing of a given gun or setting a plug. For example, if the operational plan module 602 indicates to the perforation automation controller 900 that within a given well and a given stage, a plug is to be set or a gun is to be fired at a predetermined depth, the perforation automation controller 900 can receive sensory information from the WDAS 400 and the perforation automation controller 900 can then determine if the plug or gun is too close to a casing collar. In some embodiments of the present disclosure, the perforation automation controller 900 is configured to perform various analytical tasks in order to make this step of determining, including but not limited to: comparing the actual depth of the perforation assembly with the planned depth (provided by the operational plan module 602 or otherwise) and the actual distance of a given plug or gun upon the perforation assembly to determine if the actual position of the given plug or gun falls within an acceptable minimum and maximum distance from the casing collar. In some embodiments of the present disclosure, the perforation automation controller 900 may be equipped with pattern recognition software features in order to assess sensory information from the WDAS 400 to further determine if there is a casing collar located where the operational plan module 602 or the casing collar locator 406 indicates there should be a casing collar.

If the perforation automation controller 900 determines that the plug or gun are too close to a casing collar, the perforation automation controller 900 can send instructions to the wireline controller 402 and/or the pump down controller 502 in order to move the perforation assembly further away from the casing collar. In some embodiments of the present disclosure, the distance from the casing collar is determined by using the measured distance of the wireline trucks depth indicator (which measures the location of the casing collar locator) plus the distance upon the perforation assembly from the casing collar locator tool to the plug or gun that is supposed to be set/fired. This distance may change depending on the number of guns, length of each gun and other toolstring components between the casing collar locator tool and the gun or plug in question.

The perforation automation controller 900 may comprise predetermined minimum and maximum safe distances from the predetermined planned depth at which the operational plan module 602 indicates that a plug should be set or a gun should be fired. The minimum and maximum distances from the predetermined distance may be calculated to ensure that the stage spacing and cluster spacing of the predetermined operational plan are substantially maintained. Stage spacing refers to the distance between the last shot fired on a previous stage and the first shot fired on the next stage in the sequence. Maintaining the stage spacing determines the actual number and/or distribution of perforated stages within the well. If the stage spacing is too large, then the well may have unperforated portions that do not get stimulated as per the predetermined operational plan. If the stage spacing is too small, then there may be portions of the well that are over perforated and, therefore, overstimulated—as compared to the predetermined operational plan. The cluster spacing refers to the spacing between shots fired within a given stage. As such, the cluster and stage spacing can be determined by an acceptable variance from the predetermined operational plan based upon the planned depth, for example +/−X feet from the predetermined depth or dynamically by +/−Y feet from the last shot fired. In some embodiments of the present disclosure, X feet may be between 1 and 20 feet and Y feet may be between 1 and 20 feet.

The operational limits of a given plug may also influence a desired minimum, maximum and target speed and a minimum, maximum and target tension at which the perforation assembly is moving through the well and these may be stored within the automation perforation module 900. For example, a target speed may be set at 800 ft/min with a minimum speed of 500 feet/minute and a maximum speed of 1000 ft/min. A target tension may be set at 1000 lbs, but the minimum tension may be 800 lbs and the maximum tension may be 1500 lbs.

In some embodiments of the present disclosure, the WDAS 400 may provide positional information regarding the perforation assembly within the well. In some embodiments of the present disclosure, the WDAS 400 may provide sensory information to the toolstring location controller 410. The toolstring location controller 410 may send more precise location information to the wireline 402 and the perforation automation controller 900 to indicate what speed the wireline controller 402 should be retrieving the toolstring and when conditions have been met for the perforation automation controller 900 to send a command to the firing panel 902 to set a plug or fire a gun. The toolstring location controller 410 receives the predetermined operational plan from the operational plan module 602 to determine where to place the perforation assembly within the well and at what speed the wireline truck must be retrieving the perforation assembly before providing a signal to the perforation automation controller 900 that the perforation assembly is in an allowable position for a given plug to be set or a given gun to be fired. For example, the toolstring location controller 410 can have a set of operating conditions that must be met before a plug can be set including that the plug is in the correct location with in the well and that the perforation assembly is stationary. Similarly, the toolstring location controller 410 can have a set of operating conditions that must be met before a gun can be fired including that the perforation assembly must be stationary, and or, that the perforation assembly can be moving up to a maximum speed of Z ft/minute where Z can be between 1 and

Some embodiments of the present disclosure relate to a further method 850 of automatically deploying a tool upon a perforation assembly toolstring, such as setting a specific plug or firing a specific gun (see FIG. 7B). The method comprising the steps of: receiving operational information 852 regarding the well and stage in which a plug or gun is to be utilized, receiving sensory information 854 regarding the wireline system, including one or more of the rate at which the wireline is moving into or out of the well, depth that the perforation assembly is in the well, the tension along the wireline and casing collar locator information. A step of determining 856 whether or not a specific plug or gun is located within a predetermined distance from a casing collar is then performed in order to determine if it is safe to set the specific plug or fire the specific gun. For example, the predetermined distance may be 6 feet from the casing collar, on either side, so that a plug is not set or a gun is not fired within the predetermined distance. In some embodiments of the present disclosure, this step of determining 856 may further include a step of assessing patterns 858 in the wireline system sensory information to estimate whether a casing collar is located where it is considered to be located. The step of determining 856 may also include a step of assessing 860 whether the operational status of the perforation assembly meets predetermined conditions, such as but not limited to: the perforation assembly is stationary or the perforation assembly is moving within a predetermined and acceptable rate and/or wireline tension being within an allowable range. For example, the allowable tension must be within about +/−25% of a predetermined tension value. In the event that upon completing the determining step 856 it is determined that specific plug can be set or a specific gun can be fired, the method further includes a step of instructing 862 a firing panel to set the specific plug or fire the specific gun. In the event that the step of determining 856 does not result in determining that it is the correct position within the well for setting a specific plug or firing a specific gun, then a step of moving 864 the perforation assembly to a different location occurs and the method 850 can start again from the step of receiving the operational information 852 and/or the step of receiving the sensory information 854.

SYSTEM AND METHOD FOR CONTROLLING WELL OPERATIONS

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