• 专利附录
  • 专利说明
  • 权利要求
  • 类似技术
  • 同族专利
  • 引用文献
  • 法律状态
  • 优先权
    • 专利摘要:
    To maximize the efficiency of a perforator tool system, downhole conditions can be simulated to determine the optimum configuration for the perforator tool system. A simulated wellbore is disposed in a simulated wellbore casing and coupled to a formation sample. The simulated wellbore includes the perforator tool system and one or more filler discs that consume a simulated wellbore volume. Filling disks are used to control dynamic underpressure for a given simulation of a punch tool system. One or more measurements associated with the perforator tool system and one or more images may be generated after explosive charges of the perforator tool system are initiated. The perforator tool system may be modified based, at least in part, on one or more measurements and one or more images for the specific dynamic underpressure of the simulation.
    公开号:FR3061926A1
    申请号:FR1761743
    申请日:2017-12-07
    公开日:2018-07-20
    发明作者:Dennis J. HAGGERTY；John Douglas Manning；Jacob Andrew McGregor
    申请人:Halliburton Energy Services Inc；
    IPC主号:
    专利说明:

    Agent (s):
    Holder (s):
    INC ..
    HALLIBURTON ENERGY SERVICES,
    GEVERS & ORES Public limited company.
    © CONTROL OF SIMULATED WELLBORE FOR A DYNAMIC UNDER-PRESSURE TEST.
    FR 3,061,926 - A1
    ©) To optimize the efficiency of a hole punch system, downhole conditions can be simulated to determine the optimal configuration for the hole punch system. A simulated wellbore is disposed in casing of a simulated wellbore and coupled to a training sample. The simulated wellbore includes the punch tool system and one or more filling discs that consume a volume of the simulated wellbore. The filling discs are used to control the dynamic underpressure for a given simulation of a perforating tool system. One or more measurements associated with the punch tool system as well as one or more images can be generated after explosive charges from the punch tool system are initiated. The punch tool system can be modified based, at least in part, on one or more measurements and one or more images for the specific dynamic underpressure of the simulation.

    SIMULATED WELLBORE CONTROL FOR DYNAMIC UNDERPRESSURE TEST
    TECHNICAL AREA
    This disclosure generally relates to an evaluation of the equipment used and of operations carried out in conjunction with an underground well, more particularly, for a control of the dynamic underpressure during a test and a simulation of a system of perforator tool.
    BACKGROUND OF THE INVENTION
    Hydrocarbons, such as gas and petroleum, are generally obtained from underground formations which can be on land or offshore. The development of underground operations and the processes involved in the removal of hydrocarbons from an underground formation are complex. Typically, underground operations involve a number of different steps such as, for example, drilling a wellbore at a desired wellsite, treating the wellbore to optimize production of hydrocarbons , and carrying out the steps necessary to produce and process the hydrocarbons from the underground formation. Measurements of the underground formation can be made throughout the operations to characterize the formation and assist in making operational decisions. In some cases, a communication interface of a downhole tool can be used to communicate data associated with measurements of formation or other downhole parameters.
    A perforator tool system is commonly used to maximize the potential recovery of such hydrocarbons. However, for a given operation, the drill tool system can be chosen based on little or no knowledge of any downhole load performance. For example, a selection of a drill tool system may be based on test data from section 1 of the American Petroleum Institute (API RP) 19B Recommended Practices that assess only specific strength or cement penetration. formulated among competing perforator tool systems and various cement compositions. Penetration of cement, on the other hand, is not always reconcilable with penetration into a downhole environment or an influx potential. Additional data is required to more accurately select and configure the appropriate hole punch system for a given operation.
    FIGURES
    Some examples of specific embodiments of the disclosure can be understood with reference, in part, to the following description and the accompanying drawings.
    FIG. 1 is a diagram showing an example of a well system having a perforating tool system, according to aspects of this disclosure.
    Figure 2 is a diagram showing an example of a sectional view of a hole punch test system, in accordance with aspects of this disclosure.
    Figure 3 is a diagram of a hole punch test system, in accordance with aspects of this disclosure.
    Figure 4 is a diagram of an information manipulation system, according to one or more aspects of the present invention.
    FIG. 5 is a flow diagram of a method of testing and simulating a punch tool system, according to aspects of this disclosure.
    Figure 6A and Figure 6B illustrate examples of tunnels created by a hole punch test system, in accordance with aspects of this disclosure.
    Although embodiments of the present disclosure have been presented and described and are defined by reference to exemplary embodiments of the disclosure, these references do not limit the disclosure and no limitation should be inferred. The object disclosed admits considerable modifications, transformations and equivalents of form and function, as will be understood by a specialist in the field and who benefits from this disclosure. The presented and described embodiments of this disclosure are only examples, and are not exhaustive of the scope of the disclosure.
    DETAILED DESCRIPTION
    In the context of this disclosure, an information manipulation system can include any instrumentality or any aggregate of instrumentalities making it possible to calculate, classify, process, transmit, receive, retrieve, produce, switch, store, display, manifest, detect, record, reproduce, manipulate or use any form of information, intelligence or data for any purpose commercial, scientific, control, or other. For example, an information manipulation system can be a personal computer, a network storage device, or any other suitable device, and can vary in size, shape, performance, functionality, and price. The information handling system may include a random access memory (RAM), one or more processing resources such as a central processing unit (CPU) or a hardware or software control logic, a ROM, and / or other types of non-volatile memory. Additional components of the information manipulation system may include one or more disk drives, one or more network ports for communicating with external devices, as well as various input and output (I / O) devices, such as a keyboard, mouse and video display. The information manipulation system may also include one or more buses for transmitting communications between the various hardware components. It can also include one or more interface units capable of transmitting one or more signals to a control device, an actuator or an equivalent device.
    For the purposes of this disclosure, computer-readable media includes any instrumentality or aggregation of instrumentalities that may retain data and / or instructions for a period of time. Computer-readable media may include, for example, but not limited to, storage media such as a direct access storage device (for example, a hard disk drive or a floppy drive), a device sequential access storage (eg, tape drive), compact disc, CD-ROM, DVD, RAM, ROM, erasable and electrically programmable read-only memory (EEPROM) and / or flash memory; as well as communication media such as wires, optical fibers, microwaves, radio waves, and other electromagnetic and / or optical carriers; and / or any combination of the above.
    Illustrative embodiments of the present disclosure are described in detail here. For the sake of clarity, all the characteristics of an actual implementation may not be described in the present specification. It will of course be understood that in the development of one of these real embodiments, many specific decisions related to the implementation are taken to achieve the specific objectives of the implementation, which may vary from one implementation to another. In addition, it will be appreciated that such a development effort may be complex and time consuming, but will only be a routine endeavor for an ordinary specialist in the field who benefits from this disclosure.
    In order to facilitate a better understanding of the present disclosure, the following examples of certain embodiments are given. It should not be interpreted in any way as the following examples limit or define the scope of the invention. The embodiments of this disclosure can be applied to horizontal, vertical, deviated or otherwise non-linear wells in any type of underground formation. The embodiments can be applied to injection wells, as well as to production wells, in particular hydrocarbon wells.
    Copper wires can be used inside a downhole tool to communicate between electrical components and power tools. However, copper wires are subject to degradation over time just like the connectors used to connect several tools together. Providing an optical projection communication system that is independent of any cable or fiber reduces casing or tool failures due to breakage or connector failures. In addition, optical projection communications may not be affected by the presence of electric or magnetic fields which typically cause interference with signals sent over copper wiring. The use of optical projection signals for communication effectively immunizes the optical projection communication system against inductive coupling, electromagnetic interference, and underground loops. In some embodiments, visible light is used to communicate data between downhole electrical components that minimize the risk of data detection by unauthorized users or for whom it is not intended. One or more embodiments of this disclosure provide downhole communications that are reliable and capable of supporting the downhole environment.
    Dynamic underpressure (DUB) in a hole punch test system, for example, in a section 2 or section 4 test system of the American Petroleum Institute (API RP) 19B, can be controlled by adjusting the volume of the wellbore chamber in conjunction with an adjustment of the free barrel volume in a simulated perforator. A DUB order can guarantee that a given well operation achieves maximum production or injection by creating a clean, open perforation tunnel. A DUB control can also be used to prevent a perforation tunnel collapse or unwanted sand flow into the well by reducing the amplitude or mitigating a pressure drop in the wellbore during an event or d 'a perforation operation.
    Various aspects of this disclosure may be implemented in various environments. For example, Figure 1 is a diagram showing an example of a well system 100 having a perforator tool system, in accordance with aspects of this disclosure. The well system 100 includes a derrick 102 positioned at a surface 104. The derrick 102 can support components of the well system 100, including a drill string 106. The drill string 106 may include segmented pipes which extend below the surface 10 and into a wellbore 108. The wellbore 108 may extend through underground formations 110 into the soil adjacent to the wellbore 108. The underground formations 110 may include a perforation, an orifice or fracture 112, generally referred to herein as a fracture 112. In some aspects, the fracture 112 may be a separation of the underground formations 110 forming a crack or crevice in the underground formations 110. In additional aspects, the fracture 112 can be created by a fracturing process in which high pressure gas is forced into formations 110 via a system or a set of perforating tool 120. A po mpe 114 is positioned at the surface 104 near the wellbore 108 to pump fluid into the wellbore. Fluid can be pumped into the wellbore at a rate to expand the fracture 112 or to fill a hole or fracture 112. The fracture 112 can be used as a path for the production of hydrocarbons from underground reservoirs. A slow injection pumping device 116 can be included to inject additional fluid into the fracture 112 to further open or expand the fracture 112 in the underground formation 110. In one or more aspects, the slow injection pumping device 116 can be positioned at the surface as shown by a block 116A in Figure 1. In alternative aspects, the slow injection pumping device 116 can be positioned on the drill string 106 as shown by a block 116B. A proppant and other additives can be added to the fluid during or before the fluid passes through the pump 114. The proppant can remain in fracture 112 after the completion of the fracturing process to prevent fracture 112 from close completely. Although the slow injection pumping device 116 is shown as positioned on a drill string 106 at the bottom of the well in the wellbore 108, the whole, or a portion, of the slow injection pumping device 116 can be positioned on the surface 104. For example, the slow injection pumping device 116 can be positioned on the surface 104 downstream of the pump 114.
    A perforator tool system 120, configured or calibrated according to one or more aspects of this disclosure, can also be positioned or deployed at the bottom of the well. In one or more embodiments, a perforator tool system 120 may be positioned along, included in, or coupled to the drill string 106, a downhole assembly, or any other deployment device or tool adapted downhole. A perforator tool system 120 may include shaped charges or explosive charges which when primed create a tunnel (e.g., a fracture 112) through the casing or liner disposed within the wellbore 108 in the training 110. The perforating tool system 120 can be coupled via an electrical connection 122 to a control unit 118 at the surface 104.
    In one or more embodiments, a control unit 118 can be positioned at the bottom of the well or at a distance from the downhole environment 100. A control unit 118 can transmit a signal to a drilling tool system 120 for initiating the explosive charges (not shown) disposed within the perforator tool system 120. In one or more embodiments, an electrical connection 122 may be any material suitable for carrying an electrical signal including but not limited to '' limit a wired line, one or more cables (such as a detonator cable), or any other suitable conductor or connection. A punch tool system 120 can be configured according to any one or more aspects of this disclosure.
    Figure 2 is a diagram showing an example of a sectional view of a hole punch test system 200, according to aspects of this disclosure. The perforator tool test system 200 includes casing of simulated wellbore 260. A simulated wellbore tubing 260 can be cylindrical in shape as shown in Figure 2. In one or more embodiments a simulated wellbore tubing 260 can be of any suitable shape which allows a simulation of a Punch tool system 120 in accordance with one or more aspects of this disclosure. A simulated wellbore 250 is disposed within the simulated wellbore tubing 260 and coupled to a training sample 220. The simulated wellbore 250 is pressurized to apply pressure which approximates a wellbore pressure to the hole punch tool system 120. The simulated wellbore 250 may meet the requirements for wellbore cavities in section 2 and section 4 of API RP 19.
    A perforator tool system 120 is disposed within the simulated wellbore 250 of the simulated wellbore casing 260. The perforator tool system 120 includes an explosive charge 210. The perforator tool system 120 may be arranged or include any one or more components required for a given operation. A detonating cord 270 can couple to the explosive charge 210 of the perforating tool system 120. The detonating cord 270 can pass through an opening (not shown) at one end of the perforating tool system 120 or any other location of the perforator tool system 120. The detonating cord 270 may be directly or indirectly coupled to or electrically or communicatively coupled to a power source or an information manipulation system such that an electrical signal causes the initiation of the explosive charge 210. The initiation of an explosive charge 210 can be controlled manually or by executing one or more instructions of a software program stored in a non-transient memory on a manipulation system. information. Although only one explosive charge 210 is illustrated, the present disclosure contemplates any number of explosive charges 210 in any number of configurations.
    One or more filling discs 240 may be disposed inside a cavity of the simulated wellbore 250 between a wellbore cap 280 simulated of the simulated wellbore 250 and the perforator tool system 120. The one or several filling discs 240 can fit flush with the interior wall 290 of the simulated wellbore 250 or be of any other dimensions adapted according to a wellbore operation. The filling discs 240 may include aluminum or any other suitable material. Filler discs 240 reduce the volume or empty the cavity space of the simulated wellbore 250. The more volume is consumed by the filling discs 240, the deeper and greater the reduction in pressure undergone (DUB effect) after ignition of the explosive charge 210. A filling disc 240 can include any size, dimension or thickness adapted to a given operation. A faceplate 282 may be disposed within the simulated wellbore 250 between the perforator tool system 120 and the training sample 220 includes, for example, casing or simulated cement. The faceplate 282 may include steel and may be supported by a layer of cement. In one or more embodiments, the perforator tool system 120 and the training sample 220 couple directly or indirectly to the faceplate 282. In one or more embodiments, the perforator tool system is arranged or positioned inside the front plate 282, for example, installed in one or more grooves (not shown) of the front plate 282.
    The perforator tool test system 200 may include one or more chambers of supercharged fluid 230 disposed around the training sample 220. The chambers of supercharged fluid 230 may include supercharged fluid used to apply supercharging pressure during 'a simulation to simulate an overcompression constraint on training sample 220.
    Figure 3 is a diagram of a hole punch test system 300, in accordance with one or more aspects of this disclosure. A perforator tool test system 300 may be the same as or similar to a perforator tool test system 200 in Figure 2. Figure 3 illustrates a simulated wellbore 250 which includes one or more filling discs 240 and a perforator tool system 120, a sample formation 220, a flow distributor 330 and a flow line 320 disposed inside a pressure vessel 310. The perforator tool system 120 is disposed adjacent to * sample training 220 to simulate a perforation or fracturing operation. A flow distributor 330 couples to or engages a sample formation 220 to regularly distribute a pressurized fluid from a flow line 320 to create or extend a perforation in the sample formation 200. This distribution regular pressurized fluid to a perforation allows DUB performance evaluation.
    The perforator tool system 300 may include a wellbore accumulator 360 and a pore accumulator 370. The pore accumulator 370 may include a fluid chamber 374. The fluid chamber 374 may be filled with a fluid pressurization, for example, odorless mineral alcohols (WHO), formulated brine, mud, a killer pill, a completion fluid, a stimulation fluid, or any other fluid suitable for a given operation or simulation. Each type of fluid in fluid chamber 374 can affect DUB differently due to the intrinsic properties (e.g., viscosity and rheological properties) of the fluid. The pore accumulator 370 can include a gas tank 376. The gas tank 376 can be filled with nitrogen gas. The pore accumulator 370 may include a piston 372 which applies a force to the fluid chamber 374 to cause fluid to flow through a flow line 320 to the flow distributor 330. The pore accumulator 370 may include a bypass valve 378 to control the pressure of the pore accumulator 370. A pressure transducer 340 may couple to the flow line 320 to measure the pressure of the fluid flowing from the pore accumulator 370 to the flow distributor 330.
    The wellbore accumulator 360 may include a fluid chamber 364. The fluid chamber 364 may be filled with a pressurizing fluid, for example, odorless mineral alcohols (OMS), formulated brine, mud , a killer pill, a completion fluid, a stimulation fluid, or any other fluid suitable for a given operation or simulation. Each type of fluid in fluid chamber 364 can affect DUB differently due to the intrinsic properties (e.g., viscosity and rheological properties) of the fluid. The wellbore accumulator 360 can include a gas tank 366. The gas tank 366 can be filled with nitrogen gas. The wellbore accumulator 360 may include a piston 362 to isolate and control a force on the fluid chamber 364 to cause fluid to flow through a flow line 380 from the simulated wellbore 250. The pore accumulator 370 may include a bypass valve 368 for controlling the pressure of the wellbore accumulator 370. A pressure transducer 342 may couple to the flow line 380 to measure the pressure of the fluid s' flowing from wellbore 250 to wellbore accumulator 360. A bypass valve 350 can couple to flow line 320 and flow line 380 to equalize pressure between the pore accumulator 370 and the wellbore accumulator 360. Equalization of this pressure stops the flow of fluid.
    FIG. 4 is a diagram illustrating an example of an information handling system 400, according to aspects of the present disclosure. The control unit 118 can take a form similar to the information handling system 400. A processor or central processing unit (CPU) 401 of the information handling system 400 is coupled in communication with a data control center. memory or memory controller 402. The processor 401 may include, for example, a microprocessor, a microcontroller, a digital signal processor (DSP), a specific application integrated circuit (ASIC), or any other digital circuit or analog configured to interpret and / or execute program instructions and / or process data. The processor 401 can be configured to interpret and / or execute the instructions of a program or other data retrieved and stored in any memory, such as memory 403 or the hard disk 407. Instructions of program or d Other data may constitute portions of software or an application to perform one or more of the procedures described in this document. The memory 403 can include a read only memory (ROM), a random access memory (RAM), a solid state memory, or a memory based on a disc. Each memory module can include any system, device or apparatus configured to retain program instructions and / or data for a period of time (for example, computer readable non-transient media). For example, instructions from software or an application can be retrieved and stored in memory 403 for execution by the processor 401.
    Modifications, additions or omissions can be made to Figure 4 without departing from the scope of this disclosure. For example, Figure 4 shows a particular configuration of components of the information handling system 400. However, any suitable configuration of components can be used. For example, the components of the information manipulation system 400 can be implemented by physical or logical components. In addition, in certain embodiments, the functionality associated with the components of the information handling system 400 can be implemented in specialized circuits or components. In other embodiments, the functionality associated with the components of the information handling system 400 can be implemented in a configurable circuit or universal components. For example, the components of the information manipulation system 400 can be implemented by configured computer program instructions.
    The memory control center 402 may include a memory controller for directing information to or from various system memory components within the information handling system 400, such as a memory 403, a storage element 406 and a hard disk 407. The memory control center 402 can be coupled to a memory 403 and to a graphics processing unit 404. The memory control center 402 can be coupled to an input / output control center or controller input and output 405. The input and output controller 405 is coupled to storage elements of the information manipulation system 400, in particular a storage element 406, which can include a flash ROM which includes a system basic input / output (BIOS) of the computer system. The input and output controller 405 is also coupled to the hard drive 407 of the information manipulation system 400. The input and output controller 405 can also be coupled to a super I / O chip 408, which is it - even coupled to several I / O ports of the computer system, in particular the keyboard 409 and the mouse 410.
    FIG. 5 is a flow diagram of a method of testing and simulating a punch tool system, according to aspects of this disclosure. In step 502, a predetermined DUB for a wellbore or a given wellbore operation is selected. This predetermined DUB is the target DUB for the hole punch test system. For example, a wellbore 108 may have a known DUB (predetermined or target). To optimize operations using a given perforator tool system 120 (of Figure 1), simulations can be performed which simulate the conditions of the wellbore 108, the formation 110 and the known DUB to determine the optimal configuration for a hole punch tool system 120.
    In step 504, the perforator tool system 120 is selected. For example, an operator of a well system 100 may use a specific type of perforator tool system 120 and may select that perforator tool system 120 for simulation. In one or more embodiments, the selected perforator tool system 120 can be selected based on any number of factors including, but not limited to, a type of formation 110, a wellbore 108 , a type of downhole fluid, current inventory, or any other factor or combination thereof. In step 506, the configuration for one or more explosive charges 210 for the selected perforator tool system 120 is selected. The same factors applicable to a selection of the perforator tool system 120 can be applied to a selection of a configuration for one or more explosive charges 210.
    In a step 508, the training sample 220 is selected. The training sample can be selected based on the known type of training or on the basis of expected types of training for a given region. In a step 510, the pressurization fluids for each of the pore accumulator 370 and the wellbore accumulator 360 are selected. The type of pressurizing fluid can be selected on the basis, at least in part, of the type of formation, of the perforating tool system 120 selected, of the selected configuration of the one or more explosive charges 210, of the wellbore 108, predetermined DUB, or any other factor or combination.
    In step 512, the perforator tool system 120 selected with the selected configuration of one or more explosive charges 210 is inserted into the simulated wellbore 150 of a perforator tool test system 200. The test system d the perforating tool 200 includes the selected training sample 220 which includes the selected configuration of the one or more explosive charges 210 and the selected pressurizing fluid.
    In a step 514 a simulation is carried out using the selected components as discussed above. The simulated wellbore tubing 260 of the perforator tool test system 200 is pressurized by defining a supercharging pressure of the supercharged fluid chambers 230 and defining a pore pressure of the training sample 220 selected via the accumulator of pores 370. An explosive charge 210 of the perforating tool system 120 is initiated. The DUB event occurs instantly and the impact resulting from the DUB event on the perforation tunnel can be assessed by removing the training sample 220, separating the training sample 220 to expose the tunnel of perforation or a computerized tomographic (CT) scan of training sample 220. A flow test can be performed to measure the ease with which fluid flows into or out of the newly created perforation tunnel. The pressure in the simulated wellbore tubing 260 is reduced through the wellbore accumulator 360 to allow fluid flow from the perforation tunnel or a crevice. Any one or more of a permeability and a flow rate can be measured, collected, stored, or any combination thereof. The borehole pressure is increased to match the pore pressure to stop the flow of fluid. The training sample is retrieved and measurements are made of the perforation tunnel or crevices in sample training 220. Any one or more other measurements and images, for example, computerized tomographic (CT) scans, can be generated or created as discussed with reference to steps 522 and 524.
    In one or more embodiments a step 514 is not necessary since no baseline or image measurement is required and the method continues to a step 516. In a step 516, one or more disks of 240 fill are selected based, at least in part, on any one or more of a predetermined DUB, a simulated wellbore size 250, an amount of void space, or a volume remaining (cavity) in the 250 simulated wellbore between the simulated wellbore 280 cap and the perforator tool system 120, or any other criteria. The number of filling discs 240 is selected to decrease the volume or empty space of the simulated wellbore 250 for calibrating the hole punch test system 200 to the selected or target predetermined DUB. In a step 518 the one or more selected filling discs 240 are disposed between a simulated wellbore cap 280 of the simulated wellbore 250 and the perforator tool system 120.
    In a step 520, a simulation is carried out as described above with reference to a step 514. The specific DUB associated with the simulation is determined or measured, for example, using a gauge at high ballistic speed (not shown) and compared at the predetermined DUB. In one or more embodiments, the specific or current DUB is compared to the predetermined DUB. For example, if the specific or current DUB and the predetermined DUB are within a predetermined range or a threshold of one another, then the method continues towards a step 524 and otherwise the method continues to step 516. In step 524, one or more flow tests are executed to measure a productivity of the one or more images created or generated (such as a computerized tomographic scan “CT”) and one or more associated data. to the performance of the perforator tool system 120 are generated. The one or more data associated with the performance of the perforator tool system 120 may include a depth or amplitude or dimensions of the perforation tunnel (a simulated fracture) created in the training sample 220, a hole geometry, a quantity of filling or scattered material remaining inside the casing of simulated wellbore 260, and a depth of a last trace of disturbance. By controlling dynamic underpressure, the perforation tunnel created can be extended to generate better flow performance.
    In step 526, one or more modifications are determined based, at least in part, on any one or more generated images, the specific DUB, an amount of punch tunnel or hole that remains and can potentially be removed, and the one or more data associated with the performance of the perforator tool system 120. For example, an optimal DUB is reached when the tunnel created in the training sample 220 is empty, and a minimum DUB is reached on a first appearance of material in the tunnel, in a step 528, the perforating tool system 120 is modified. The process can continue to step 512 or can end. In one or more embodiments, the modified perforator tool system 120 is deployed at the bottom of a well in a wellbore 108 of a well system 100.
    FIG. 6A and FIG. 6B illustrate an example of tunnels created by a perforator tool test system, for example, a perforator tool test system 200 of FIG. 2 or a perforator tool test system 300 of Figure 3. Figure 6A illustrates a tunnel 610 created in a training sample 220 due to DUB effects but before any determination of an optimal DUB. Figure 6B illustrates an enlarged tunnel 610 created in a training sample 220 as a result of DUB effects after modifications to the perforator tool system 120 to obtain optimal DUB. Once a flow of fluid through the tunnel 610 of Figure 6B is initiated, any scattered material contained inside the tunnel 610 of Figure 6B will be removed and optimal production will be achieved. The simulation results of Figure 6B (and any one or more embodiments of this disclosure) may be applicable to any formation, for example, an underground formation 110 in Figure 1, to achieve production optimal fluid, hydrocarbons or any other underground material.
    By performing a test and simulation of a perforator tool system 120 in the controlled environment of perforator tool test systems 200 and 300, the performance of a perforator tool system selected for background use well, for example, a perforator tool system 120 of FIG. 1, can be determined at the surface and optimized before deployment at the bottom of the well which reduces the costs of a given operation.
    In one or more embodiments, a simulation method for a drill tool system includes an arrangement of a drill tool system in a simulated wellbore of a simulated wellbore casing, wherein the system of a perforating tool comprises one or more explosive charges, an arrangement of a training sample adjacent to the perforating tool system in the casing of simulated wellbore, an insertion of one or more filling discs inside a simulated wellbore cavity, in which the one or more filling discs are based, at least in part, on at least one of a predetermined dynamic underpressure (DUB), a size of the simulated wellbore , and a size of the cavity, pressurization of the simulated wellbore, initiation of one or more explosive charges to create a perforation in the training sample, generation of at least one of one or more data associated with a performance of the punch tool system and one or more images, a determination of a current DUB, and a modification of the punch tool system based, at least in part, on the at least one of the DUB, one or more data and one or more images generated. In one or more embodiments, the method further includes flowing pressurized fluid through the perforator tool system in the perforation. In one or more embodiments, the method further comprises distributing the pressurized fluid on a regular basis via a flow distributor coupled to the training sample. In one or more embodiments, the method further comprises selecting the pressurized fluid based, at least in part, on one or more properties of the pressurized fluid, wherein the one or more properties affect the current DUB. In one or more embodiments the method further includes changing the current DUB by selecting a different pressurized fluid. In one or more embodiments, the method further comprises changing the DUB by adding a filling disc to the one or more filling discs or removing a filling disc from the one or more filling discs. In one or more embodiments, the method further comprises determining that the predetermined DUB and the current DUB are within a predetermined threshold. In one or more embodiments, the method further includes performing one or more flow tests to measure productivity of the one or more images generated.
    In one or more embodiments, a simulated wellbore system includes simulated wellbore tubing, a simulated wellbore disposed within the simulated wellbore casing, a front plate disposed at a first end of the simulated wellbore, a perforator tool system disposed within the wellbore between a second end and the first end of the simulated wellbore, a training sample disposed within the wellbore casing simulated, in which the training sample couples to the faceplate, one or more explosive charges disposed within the perforator tool system, in which the one or more explosive charges are arranged such that an initiation explosive charges creates a perforation in the training sample and one or more filling discs arranged inside the simulated wellbore between the second end of the wellbore simulated age and the perforator tool system, in which the one or more filling discs affect dynamic underpressure of the perforator tool test system. In one or more embodiments, the simulated wellbore system further includes a pore accumulator disposed within the simulated wellbore casing, a wellbore accumulator disposed within the wellbore casing simulated drilling and a bypass valve coupled to the pore accumulator and the wellbore accumulator, wherein the bypass valve equalizes a pressure between the pore accumulator and the wellbore accumulator to stop a flow of pressurized fluid through the training sample. In one or more embodiments, the simulated wellbore system further includes a flow distributor coupled to the training sample, wherein the flow distributor distributes pressurized fluid evenly over the sample. training. In one or more embodiments, the simulated wellbore system further includes an information manipulation system, wherein the information manipulation system includes a processor and a memory coupled to the processor, the memory contains one or more several instructions which, when executed by the processor, cause the processor to generate one or more images associated with a perforation of the training sample. In one or more embodiments, the one or more instructions further cause the processor to determine a current DUB and to determine a modification of the simulated wellbore system based, at least in part, on the current DUB.
    In one or more embodiments, a non-transient computer-readable medium storing one or more instructions which, when executed, cause a processor to determine a target dynamic underpressure (DUB) for a simulation of a well operation drilling, determining a perforator tool system for simulation, determining a configuration for one or more explosive charges for simulation, determining a training sample for simulation, determining a configuration of one or more discs filling based, at least in part, on the target DUB and performing a simulation, in which an embodiment of the simulation comprises pressurizing casing of simulated wellbore, priming at least one of the or more explosive charges to create a perforation in the training sample, a determination of a current DUB, generation of one or more images of the perforation and u determination of a modification of the simulation based, at least in part, on at least one of the current DUB and the one or more images generated. In one or more embodiments, an embodiment of the simulation further comprises flowing a pressurized fluid through the perforator tool system in the perforation. In one or more embodiments, the one or more instructions, when executed, further cause the processor to select a pressurized fluid based, at least in part, on one or more properties of the pressurized fluid, in which one or more properties affect the current DUB. In one or more embodiments, the one or more instructions, when executed, further cause the processor to determine whether the predetermined DUB and the current DUB are within a predetermined threshold. In one or more embodiments, the one or more instructions, when executed, further cause the processor to execute one or more flow tests to measure productivity of the one or more generated images. In one or more embodiments, one embodiment of the simulation further includes reducing pressure in the casing of the simulated wellbore to allow fluid to flow from the perforation. In one or more embodiments, the one or more instructions, when executed, further cause the processor to measure a flow of fluid from the perforation.
    Therefore, this disclosure is well suited to achieve the purposes and advantages mentioned as well as those inherent here. The particular embodiments disclosed above are for illustrative purposes only, since this disclosure may be varied and practiced in different but equivalent ways evident to a specialist in the field and who benefits from these teachings. In addition, there is no limitation to the construction or design details described herein, other than those described in the claims below. It is therefore obvious that the particular illustrative embodiments disclosed above may be altered or modified and all of these variations are considered within the scope and spirit of this disclosure. In addition, the terms in the claims have their clear and ordinary meaning, unless explicitly stated otherwise clearly defined by the patent owner.
    权利要求:
    Claims (12)
    [1]
    1. Simulation method for a perforator tool system, comprising:
    an arrangement (512), by a processor, of a perforator tool system (120) in a simulated wellbore (250) of a simulated wellbore casing (260), wherein the tool system perforator includes one or more explosive charges (210);
    an arrangement (512), by the processor, of a training sample (220) adjacent to the perforator tool system in the simulated well casing;
    an insertion (518), by the processor, of one or more filling discs (240) inside a cavity of the simulated wellbore, in which the one or more filling discs are based, at least in part, on at least one of a predetermined dynamic underpressure (DUB), a size of the simulated wellbore, and a size of the cavity;
    pressurization (514) by the processor of the simulated wellbore;
    an initiation (514), by the processor, of one or more explosive charges to create a perforation in the training sample;
    a generation (524), by the processor, of at least one of one or more data associated with a performance of the perforating tool system and one or more images;
    a determination, by the processor, of a current DUB; and a modification (528), by the processor, of the hole punch tool system based, at least in part, on the at least one of the DUB, one or more data and the one or more generated images .
    [2]
    2. Simulation method for the perforator tool system according to claim
    1, further comprising a flow, by the processor, of a pressurized fluid through the perforator tool system (120) into the perforation.
    [3]
    3. Simulation method for the perforator tool system according to claim
    2, further comprising a distribution by the processor of the pressurized fluid on a regular basis via a flow distributor coupled to the training sample (220).
    [4]
    4. Simulation method for the perforator tool system according to any one of claims 1 and 2, further comprising a selection (510), by the processor, of the pressurized fluid on the basis, at least in part, of one or more properties of the pressurized fluid, in which the one or more properties affect the current DUB.
    [5]
    5. A simulation method for the perforator tool system according to any one of claims 1 and 2, further comprising a change, by the processor, of the current DUB by selecting a different pressurized fluid.
    [6]
    6. A simulation method for the perforator tool system according to any one of claims 1 and 2, further comprising a change, by the processor, of the DUB by adding a filling disc (240) to the one or more discs filling or by removing a filling disc from the one or more filling discs.
    Ί. A simulation method for the punch tool system according to any of claims 1, 2 and 6, further comprising determining (522), by the processor, that the predetermined DUB and the current DUB are at within a predetermined threshold.
    [7]
    8. Simulation method for the perforating tool system according to any one of claims 1, 2, 6 and 7, further comprising an execution (524), by the processor, of one or more flow tests to measure the productivity of one or more generated images.
    [8]
    9. Simulated wellbore system, comprising:
    simulated well casing (260);
    a simulated wellbore (250) disposed within the casing of the simulated wellbore;
    a front plate (282) disposed at a first end of the simulated wellbore;
    a perforator tool system (120) disposed within the wellbore between a second end and the first end of the simulated wellbore;
    a training sample (220) disposed within the casing of the simulated wellbore, wherein the training sample couples to the faceplate;
    one or more explosive charges (210) disposed within the perforator tool system, wherein the one or more explosive charges are arranged such that an initiation of the explosive charges creates a perforation in the training sample; and one or more filler discs (240) disposed within the simulated wellbore between the second end of the simulated wellbore and the punch tool system, wherein the one or more filler discs affect dynamic underpressure of the hole punch test system.
    [9]
    The simulated wellbore system of claim 9, further comprising: a pore accumulator (370) disposed within the simulated wellbore tubing (260);
    a wellbore accumulator (360) disposed inside the simulated wellbore casing; and a bypass valve (378) coupled to the pore accumulator and the wellbore accumulator, wherein the bypass valve equalizes a pressure between the pore accumulator and the wellbore accumulator to stop a flow of pressurized fluid through the training sample (220).
    [10]
    11. simulated wellbore system according to any one of claims 9 and
    10, further comprising a flow distributor (330) coupled to the training sample (220), wherein the flow distributor distributes pressurized fluid regularly to the training sample.
    [11]
    12. simulated wellbore system according to any one of claims 9 to
    11, further comprising an information manipulation system (400), in which the information manipulation system comprises a processor (401) and a memory (403) coupled to the processor, the memory containing one or more instructions which, when executed by the processor, cause the processor to generate one or more images associated with a perforation of the training sample (220).
    [12]
    13. simulated wellbore system according to any one of claims 9 to
    12, wherein the one or more instructions further cause the processor (401) to:
    determine a current DUB; and determining a modification of the simulated wellbore system based, at least in part, on the current DUB.
    1/6
    2/6
    3/6
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    同族专利:
    公开号 | 公开日
    DE112017005584T5|2019-09-26|
    US10781669B2|2020-09-22|
    US20180298732A1|2018-10-18|
    WO2018132105A1|2018-07-19|
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    法律状态:
    2018-09-28| PLFP| Fee payment|Year of fee payment: 2 |
    2019-12-30| PLFP| Fee payment|Year of fee payment: 3 |
    2020-04-17| PLSC| Search report ready|Effective date: 20200417 |
    2021-05-07| RX| Complete rejection|Effective date: 20210330 |
    优先权:
    申请号 | 申请日 | 专利标题
    PCT/US2017/013491|WO2018132105A1|2017-01-13|2017-01-13|Simulated wellbore control for dynamic underbalance testing|
    IBWOUS2017013491|2017-01-13|
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