CONTROL FOR A SIMULATED BOREHOLE FOR TESTING WITH DYNAMIC VACUUM

Abstract

Simulation method for a perforating tool system, comprising: Placing a perforating tool system in a simulated borehole of a simulated borehole casing, wherein the perforating tool system comprises one or more explosive charges; Placing a formation sample adjacent to the perforating tool system in the simulated wellbore casing; Introducing one or more filler disks into a cavity of the simulated borehole, wherein the one or more filler disks are based at least in part on at least one of a predetermined dynamic underpressure (DUB), a size of the simulated borehole, and a size of the cavity; pressurizing the simulated borehole; Detonating the one or more explosive charges to create a perforation in the formation sample; generating at least one of data associated with a performance of the perforating tool system and one or more images; determining an actual DUB; and Modifying the perforating tool system based at least in part on the DUB, the data, and the one or more generated shots.

Description

TECHNICAL FIELD

[0001] The present disclosure relates generally to the evaluation of equipment used in the context of a subterranean wellbore and operations performed in the same context, particularly to controlling dynamic negative pressure in testing and simulating a perforating tool system. BACKGROUND

[0002] Hydrocarbons such as oil and gas are typically extracted from subterranean formations, which can be located on land or offshore. The design of subterranean operations and the processes required to obtain hydrocarbons from a subterranean formation are complex. Typically, subterranean operations involve several different steps, such as drilling a wellbore at a desired well location, treating the wellbore to optimize hydrocarbon production, and performing the necessary steps to produce and process the hydrocarbons from the subterranean formation. Measurements of the subterranean formation can be taken from the operations to characterize the formation and support operational decision-making.In certain cases, a downhole tool's communication interface may be used to transmit data related to formation measurements or other downhole parameters.

[0003] A perforating tool system is commonly used to maximize the potential recovery of such hydrocarbons. However, the perforating tool system for a particular operation may be selected based on little to no knowledge of the likely load behavior downhole. For example, a perforating tool system selection may be based on test data according to American Petroleum Institute Recommended Practices (API RP) 19B Section 1, which only evaluates a specific strength or penetration depth of formulated cement among competing perforating tool systems and different cement compositions. However, cement penetration depth does not always correlate with the penetration depth in a subsurface environment or the inflow potential.Additional data is needed to more accurately select and design the appropriate perforating tool system for a specific operation.

[0004] US 2016 / 0 138 394 A1 relates to a perforation test target. The perforation test target comprises a metal plate and a core sample adhered to the metal plate at one end. The perforation test target further comprises a first sleeve adhered to the core sample, wherein a flow impedance of each of a plurality of portions of the first sleeve is based on a predetermined impedance map.

[0005] CN 105 350 946 A relates to the field of oil and gas well logging and concerns a combined well-target device for perforation flow testing. The combined well-target device consists of a simulated well, a simulated perforator unit, a simulated target device, a fluid supply line, and a pressure vessel end cover. The upper and lower ends of the simulated well are threadedly connected to the pressure vessel end cover and the simulated target device, the simulated perforator unit is arranged inside the simulated well, and the fluid supply line is threadedly connected to the simulated target device and the pressure vessel end cover.

[0006] US 2009 / 0 217 739 A1 refers to an improved test facility known as the "Quick Development Cell" (QDC), which enables rapid testing with valuable feedback for the development engineer. Because the QDC enables fast and efficient testing at sufficient frequency, QDC testing is compatible with quality control in production. QDC testing not only promotes the improvement of API Section 2 testing, which uses contaminated natural rock for benchmark experiments, but also enables progress in the development of flow-optimized mold filling and improved wellbore performance.

[0007] US 4,932,239 A relates to a method for testing an explosive charge using a uniformly shaped charge test standard modeled on naturally occurring Berea sandstone test specimens. A quantity of zircon sand is mixed with 3 to 8 wt.% of the total mixture of a phenolic resin and then stirred to achieve the desired density of the mixture. The mass is then subjected to controlled heating to form it into a shape suitable for explosive testing. An explosive shaped charge is detonated near the standard, and the penetration of the shaped charge on the standard is measured.

[0008] US 2009 / 0 241 700 A1 relates to a device for producing a target core to enable tests under simulated borehole conditions. The device comprises a support core having a target core receiving area. A flexible sheath can receive the support core and exert a confining stress on the support core. A quantity of unconsolidated sand is arranged in the target core receiving area of ​​the support core. The support core can transfer at least part of the confining stress to the unconsolidated sand, thereby forming the target core. The device simulates the conditions in the borehole so that flow tests can be performed on the target core before and after perforating the target core. FIGURES

[0009] Some specific exemplary embodiments of the disclosure may be understood by considering, in part, the following description and the accompanying drawings. Fig. 1 is a diagram showing an illustrative drilling system with a perforating tool system according to aspects of the present disclosure. Fig. 2 is a diagram showing an illustrative cross-sectional view of a perforating tool inspection system according to aspects of the present disclosure. Fig. 3 is a diagram of a perforating tool inspection system according to aspects of the present disclosure. Fig. 4 is a diagram of an information handling system according to one or more aspects of the present invention. Fig. 5 is a flow diagram of a method for testing and simulating a perforating tool system according to aspects of the present disclosure. Fig. 6A and Fig. 6B illustrate exemplary tunnels created by a perforating tool inspection system according to aspects of the present disclosure.

[0010] While embodiments of this disclosure have been illustrated, described, and defined with reference to exemplary embodiments of the disclosure, such references do not imply, and no such limitation should be inferred. Considerable modifications, changes, and equivalents in form and function are possible in the disclosed subject matter, as will be apparent to those skilled in the relevant art and those having the benefit of this disclosure.

[0011] The illustrated and described embodiments of this disclosure are merely examples and do not exhaust the scope of the disclosure. DETAILED DESCRIPTION

[0012] For the purposes of this disclosure, an information handling system may include any device or set of devices operable to compute, classify, process, transmit, receive, track, generate, exchange, convey, store, display, communicate, detect, record, reproduce, process, or exploit any form of information, intelligence, or data for business, scientific, management, or other purposes. An information handling system may be, for example, a personal computer, a network storage device, or any other suitable device, and may vary in size, shape, performance, functionality, and price.The information handling system may include random access memory (RAM), one or more processing resources such as a central processing unit (CPU) or hardware or software control logic, ROM, and / or other types of non-volatile memory. Additional components of the information handling system may include one or more disk drives, one or more network ports for communication with external devices, and various input / output (I / O) devices such as a keyboard, a mouse, and a video display. The information handling system may also include one or more buses operable to transmit communications between the various hardware components. It may also include one or more interface units capable of transmitting one or more signals to a controller, actuator, or similar device.

[0013] For the purposes of this disclosure, computer-readable media may include any device or set of devices capable of retaining data and / or instructions for a period of time. Computer-readable media may include, for example, without limitation, storage media such as a random access storage device (e.g., a hard disk drive or floppy disk drive), a sequential access storage device (e.g., a tape drive), a compact disk, a CD-ROM, DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), and / or flash memory; as well as communication media such as wires, fiber optics, microwaves, radio waves, and other electromagnetic and / or optical media; and / or any combination of the foregoing.

[0014] Illustrative embodiments of the present disclosure are described in detail herein. For clarity, not all features of an actual implementation may be described in this specification. Of course, it is understood that in developing each such actual embodiment, numerous implementation-specific decisions will be made to achieve the specific objectives of the implementation, which will vary from one implementation to another. Furthermore, it is understood that such a development effort may be complex and time-consuming, but should nevertheless be within the skill of the art, given the benefit of the present disclosure.

[0015] To better understand the present disclosure, the following examples of specific embodiments are provided. The following examples should not be construed in any way to limit or define the scope of the invention. Embodiments of the present disclosure may be applicable to horizontal, vertical, deviated, or otherwise non-linear wells in any type of subterranean formation. Embodiments may be applicable to injection wells as well as production wells, including hydrocarbon wells.

[0016] In a downhole tool, copper wires can be used to communicate between electrical components and electrical tools. However, copper wires, along with the connectors used to connect multiple tools together, tend to wear out over time. Providing an optical projection communication system that is independent of any cables or fibers reduces enclosure or tool failures due to breakage or connector failure. Furthermore, optical projection communications may not be affected by the presence of electric or magnetic fields that typically cause interference with signals sent over copper cables. Effectively, using optical projection signals for communication makes the optical projection communication system immune to mutual induction, electromagnetic interference, and ground loops.In some embodiments, visible light is used to communicate data between electrical components in a borehole, minimizing the risk of data detection by unauthorized or unintended users. One or more embodiments of the present disclosure enable downhole communications that are reliable and capable of withstanding the subsurface environment.

[0017] Dynamic underbalance (DUB) in a perforating tool test system, such as a test system compliant with Section 2 or Section 4 of American Petroleum Institute Recommended Practices (API RP) 19B, can be controlled by adjusting the drilling chamber volume in conjunction with adjusting the free perforator volume in a simulated downhole perforator. DUB control can ensure that a given drilling operation achieves maximum production or injection by creating a clear, open perforation tunnel. DUB control can also be used to prevent perforation tunnel collapse or unwanted sand inflow into the wellbore by reducing the magnitude or mitigating the pressure drop that occurs during a perforating operation.

[0018] Various aspects of the present disclosure may be implemented in different environments. For example, Fig. 1 is a diagram showing an illustrative drilling system 100 with a perforating tool system according to aspects of the present disclosure. The drilling system 100 includes a drilling rig 102 positioned at a surface 104. The drilling rig 102 may support components of the drilling system 100, including a tubing string 106. The tubing string 106 may include segmented tubing that may extend below the surface 10 and into a borehole 108. The borehole 108 may extend through subterranean formations 110 in the earth in the area surrounding the borehole 108. The subterranean formations 110 may include a perforation, breach, or fracture 112, generally referred to herein as fracture 112.In some aspects, the fracture 112 may be a splitting of the subterranean formations 110, creating a fracture or crack in the subterranean formations 110. In additional aspects, the fracture 112 may be created by a fracturing process in which highly pressurized gas is forced into the formations 110 via the perforating tool system or perforating assembly 120. A pump 114 is positioned at the surface 104 near the wellbore 108 to pump a fluid into the wellbore. The fluid may be pumped into the wellbore at a rate to expand the fracture 112 or fill a perforation or fracture 112. The fracture 112 may serve as a route for producing hydrocarbons from subterranean reservoirs.A slow injection pumping device 116 may be included to inject additional fluid into the fracture 112 to further open or widen the fracture 112 in the subterranean formation 110. In one or more aspects, the slow injection pumping device 116 may be positioned at the surface, as illustrated by box 116A in FIG. Fig. 1. In alternative aspects, the slow injection pumping device 116 can be positioned on the tubing string 106, as shown by box 116B. 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 the fracture 112 after the fracturing process is complete to prevent the fracture 112 from completely closing. While the slow injection pumping device 116 is shown positioned on a tubing string 106 downhole in the wellbore 108, all or part of the slow injection pumping device 116 can also be positioned at the surface 104. For example, the slow injection pumping device 116 can be positioned at the surface 104 downstream of the pump 114.

[0019] The perforating tool system 120, designed or calibrated according to one or more aspects of the present disclosure, may also be positioned or placed downhole. In one or more embodiments, the perforating tool system 120 may be positioned along, integrated with, or coupled to the tubing string 106, a drilling string, or any other suitable downhole placement device or tool. The perforating tool system 120 may include shaped charges or explosive charges that, when detonated, create a tunnel (e.g., fracture 112) through the casing or liner located within the wellbore 108 in the formation 110. The perforating tool system 120 may be coupled to a control unit 118 at the surface 104 via an electrical connection 122.

[0020] In one or more embodiments, the control unit 118 may be positioned downhole or remote from the downhole environment 100. The control unit 118 may transmit a signal to the perforating tool system 120 to detonate the explosive charges (not shown) located within the perforating tool system 120. In one or more embodiments, the electrical connection 122 may be made of any material suitable for transmitting an electrical signal, including a wireline, one or more cables (such as a blasting cable), or any other suitable conductive conduit or connection. The perforating tool system 120 may be configured in accordance with any one or more aspects of the present disclosure.

[0021] Fig. Figure 2 is a diagram showing an illustrative cross-sectional view of a perforating tool testing system 200 according to aspects of the present disclosure. The perforating tool testing system 200 includes a simulated borehole casing 260. The simulated borehole casing 260 may be formed as shown in Fig. 2, have a cylindrical shape. In one or more embodiments, the simulated wellbore casing 260 may have any suitable shape that allows for the simulation of a perforating tool system 120 according to one or more aspects of the present disclosure. A simulated wellbore 250 is disposed within the simulated wellbore casing 260 and coupled to a formation sample 220. The simulated wellbore 250 is pressurized to apply a pressure approximating a downhole pressure to the perforating tool system 120. The simulated wellbore 250 may meet the requirements for wellbore excavations of Section 2 and Section 4 of API RP 19.

[0022] A perforating tool system 120 is disposed within the simulated borehole 250 of the simulated borehole casing 260. The perforating tool system 120 includes an explosive charge 210. The perforating tool system 120 may be disposed on or include any one or more components required for a particular operation. A detonating cord 270 may be connected to the explosive charge 210 of the perforating tool system 120. The detonating cord 270 may pass through an opening (not shown) at one end of the perforating tool system 120 or at any other location on the perforating tool system 120. The detonating cord 270 may be coupled directly or indirectly, or electrically or communicatively, to a power source or information processing system such that an electrical signal causes the explosive charge 210 to detonate.The detonation of the explosive charge 210 can be controlled manually or by executing one or more instructions of a software program stored in a non-transitory memory of an information handling system. While only one explosive charge 210 is illustrated, the present disclosure contemplates any number of explosive charges 210 in any number of configurations.

[0023] One or more filler plates 240 may be disposed within the cavity of the simulated borehole 250 between a simulated borehole attachment 280 of the simulated borehole 250 and the perforating tool system 120. The one or more filler discs 240 may be form-fitting against the inner wall 290 of the simulated borehole 250 or may have any other suitable dimensions according to a wellbore operation. The filler discs 240 may comprise aluminum or any other suitable material. The filler discs 240 reduce the volume or void space of the cavity of the simulated borehole 250. The more volume consumed by the filler discs 240, the deeper and more extensive the pressure reduction following detonation of the explosive charge 210 (DUB effect). The filler disc 240 may comprise any size, dimension, or thickness suitable for a particular operation.A faceplate 282, disposed within the simulated wellbore 250 between the perforating tool system 120 and the formation sample 220, includes, for example, a simulated casing or cement. The faceplate 282 may comprise steel and be backed by a layer of cement. In one or more embodiments, the perforating tool system 120 and the formation sample 220 are directly or indirectly connected to the faceplate 282. In one or more embodiments, the perforating tool system is disposed or positioned within the faceplate 282; for example, it sits within one or more notches (not shown) of the faceplate 282.

[0024] The perforating tool testing system 200 may include one or more rock-loading fluid chambers 230 disposed surrounding the formation sample 220. The rock-loading fluid chambers 230 may contain rock-loading fluid used to apply lithostatic pressure during a simulation to simulate the lithostatic stress of the formation sample 220.

[0025] Fig. 3 is a diagram of a perforating tool inspection system 300 according to one or more aspects of the present disclosure. The perforating tool inspection system 300 may be the same as that shown in Fig. 2 shown perforation tool testing system 200. Fig. Figure 3 illustrates a simulated wellbore 250 including one or more fill disks 240 and a perforating tool system 120, a sample formation 220, a flow distributor 330, and a flow line 320 disposed within a pressure vessel 310. The perforating tool system 120 is disposed adjacent to a sample formation 220 to simulate a perforating or fracturing operation. A flow distributor 330 is connected to or engaged with the sample formation 220 to evenly distribute pressurized fluid from the flow line 320 to create or expand a perforation in the sample formation 200. This even distribution of pressurized fluid to a perforation enables an evaluation of DUB performance.

[0026] The perforating tool system 300 may include a borehole collector 360 and a pore collector 370. The pore collector 370 may include a fluid chamber 374. The fluid chamber 374 may be filled with a pressurized fluid, such as aroma-free white spirit (OMS), formulated brine, mud, kill pill, sealing fluid, stimulation fluid, or any other fluid suitable for a particular operation or simulation. Each type of fluid in the fluid chamber 374 may affect the DUB differently due to the properties (e.g., viscosity and flow behavior) of the particular fluid. The pore collector 370 may include a gas reservoir 376. The gas reservoir 376 may be filled with a nitrogen gas. The pore collector 370 may include a piston 372 that exerts a force on the fluid chamber 374 to cause fluid to flow via the flow line 320 to the flow distributor 330.The pore collector 370 may include a bypass valve 378 to regulate the pressure of the pore collector 370. A pressure transducer 340 may be connected to the flow line 320 to measure the pressure of the fluid flowing from the pore collector 370 to the flow distributor 330.

[0027] The wellbore collector 360 may include a fluid chamber 364. The fluid chamber 364 may be filled with a pressurized fluid, such as aroma-free white spirit (OMS), formulated saline, mud, kill pill, sealing fluid, stimulation fluid, or any other fluid suitable for a particular operation or simulation. Each type of fluid in the fluid chamber 364 may affect the DUB differently due to the properties (e.g., viscosity and flow behavior) of the particular fluid. The wellbore collector 360 may include a gas reservoir 366. The gas reservoir 366 may be filled with a nitrogen gas. The wellbore collector 360 may include a piston 362 to isolate and regulate a force acting on the fluid chamber 364 to cause fluid to flow out of the simulated wellbore 250 via the flowline 380.The pore collector 370 may include a bypass valve 368 to regulate the pressure of the downhole collector 370. A pressure transducer 342 may be connected to the flow line 380 to measure the pressure of the fluid flowing from the wellbore 250 to the downhole collector 360. A bypass valve 350 may be connected to the flow line 320 and the flow line 380 to equalize the pressure between the pore collector 370 and the downhole collector 360. Equalizing the pressure stops the flow of fluid.

[0028] Fig. 4 is a diagram illustrating an exemplary information handling system 400 according to aspects of the present disclosure. The control unit 118 may 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 communicatively coupled to a memory controller node or northbridge 402. The processor 401 may include, for example, a microprocessor, a microcontroller, a digital signal processor (DSP), an application-specific integrated circuit (ASIC), or any other digital or analog circuit configured to interpret and / or execute program instructions and / or process data.Processor 401 may be configured to interpret and / or execute program instructions or other data retrieved and stored in any memory, such as memory 403 or a hard disk drive 407. Program instructions or other data may represent pieces of software or an application for performing one or more methods described herein. Memory 403 may include read-only memory (ROM), random access memory (RAM), read-only memory, or disk-based storage. Each storage module may include any system, apparatus, or device configured to retain program instructions and / or data for a period of time (e.g., computer-readable non-transitory media). For example, instructions may be retrieved from a software application and stored in memory 403 for execution by processor 401.

[0029] With reference to Fig. 4, modifications, additions, or omissions may be made without departing from the scope of the present disclosure. For example, Fig. 4 illustrates a particular configuration of components of information handling system 400. However, any suitable configuration of components may be used. For example, components of information handling system 400 may be implemented as either physical or logical components. Furthermore, in some embodiments, functionality associated with components of information handling system 400 may be implemented in special-purpose circuits or components. In other embodiments, functionality associated with components of information handling system 400 may be implemented in configurable general-purpose circuits or components. For example, components of information handling system 400 may be implemented using configured computer program instructions.

[0030] The storage controller node 402 may include a storage controller for routing information to or from various system storage components within the information handling system 400, such as the memory 403, the storage element 406, and the hard drive 407. The storage controller node 402 may be coupled to the memory 403 and a graphics processing unit 404. The storage controller node 402 may also be coupled to an I / O control node or south bridge 405. The I / O node 405 is coupled to storage elements of the information handling system 400, including a storage element 406, which may include a flash ROM containing a basic input / output system (BIOS) of the computer system. The I / O node 405 is also coupled to the hard drive 407 of the information handling system 400.The I / O node 405 may also be coupled to a super I / O chip 408, which in turn is coupled to several of the computer system's I / O ports, including the keyboard 409 and mouse 410.

[0031] Fig. 5 is a flow diagram of a method for testing and simulating a perforating tool system according to aspects of the present disclosure. At step 502, a predetermined DUB is selected for a respective wellbore or wellbore operation. The predetermined DUB is the target DUB for the perforating tool testing system. For example, a wellbore 108 may have a known (predetermined or target) DUB. To perform operations using a respective perforating tool system 120 (of Fig. 1), simulations may be performed that simulate conditions prevailing in the wellbore 108, the formation 110, and the known DUB to determine the optimal design of a perforating tool system 120.

[0032] At step 504, the perforating tool system 120 is selected. For example, an operator of the drilling system 100 may use a specific type of perforating tool system 120 and select the perforating tool system 120 for simulation. In one or more embodiments, the selected perforating tool system 120 may be selected based on any number of factors, including, but not limited to, the type of formation 110, the wellbore 108, the type of wellbore fluids, the current inventory, or any other factor, or a combination thereof. At step 506, the design for one or more explosive charges 210 is selected for the selected perforating tool system 120. The same factors applicable to selecting the perforating tool system 120 may be selectable for selecting a design for one or more explosive charges 210.

[0033] At step 508, the formation sample 220 is selected. The formation sample is selected based on the known formation type or based on expected formation types for a particular region. At step 510, the pressurized fluids for each of the pore sampler 370 and the well sampler 360 are selected. The type of pressurized fluid may be selected based at least in part on the formation type, the selected perforating tool system 120, the selected design of the one or more explosive charges 210, the wellbore 108, the predetermined DUB, or any other factor or combination.

[0034] At step 512, the selected perforating tool system 120 with the selected configuration of one or more explosive charges 210 is introduced into the simulated borehole 150 of a perforating tool testing system 200. The perforating tool testing system 200 includes the selected formation sample 220, which includes the selected configuration of one or more explosive charges 210, and the selected pressurized fluid.

[0035] At step 514, a simulation is performed using the selected components as explained above. The simulated borehole casing 260 of the perforating tool testing system 200 is pressurized by setting a lithostatic pressure of the rock loading chamber 230 and selecting a pore pressure of the selected formation sample 220 via the pore collector 370. An explosive charge 210 of the perforating tool system 120 is detonated. The DUB process occurs instantaneously, and the resulting effect of the DUB process on the perforation tunnel can be assessed by removing the formation sample 220, splitting the formation sample 220 to expose the perforation tunnel, or by scanning the formation sample 220 using computed tomography (CT).A flow test may be conducted to measure the flowability of fluid into or out of the newly created perforation tunnel. The pressure in the simulated borehole casing 260 is reduced using the borehole collector 360 to allow fluid to flow out of the perforation tunnel or fracture. Any one or more of permeability and flow velocity may be measured, recorded, stored, or any combination thereof. The borehole pressure is increased to equal the pore pressure to stop fluid flow. The formation sample is removed, and measurements are taken of the perforation tunnel or fracture in the sample formation 220. Any one or more other measurements and images, for example, computed tomography (CT) scans, may be generated or created, as explained with reference to steps 522 and 524.

[0036] In one or more embodiments, step 514 is not necessary because no baseline measurements or recordings are required, and the method proceeds to step 516. At 516, one or more filler disks 240 are selected based at least in part on any one or more of the predetermined DUB, the size of the simulated wellbore 250, the amount of void space or residual volume (cavity) in the simulated wellbore 250 between the simulated downhole attachment 280 and the perforating tool system 120, or any other criteria. The number of filler disks 240 is selected to reduce the volume or void space of the simulated wellbore 250 to calibrate the perforating tool verification system 200 to the selected predetermined or target DUB.At step 518, the one or more filler disks 240 are disposed between a simulated wellbore cap 280 of the simulated wellbore 250 and the perforating tool system 120.

[0037] At step 520, a simulation is performed as above with respect to step 514. The specific DUB associated with the simulation is determined or measured, for example, using a high-speed ballistic measurement device (not shown), and compared to the predetermined DUB. In one or more embodiments, the specific or actual DUB is compared to the predetermined DUB. For example, if the specific or actual DUB and the predetermined DUB are within a predetermined range or threshold of each other, then the method proceeds to step 524; otherwise, the method proceeds to step 516. At step 524, one or more flow tests are performed to determine the yield of the one or more generated images (such as a computed tomography (CT) scan), and data associated with the performance of the perforating tool system 120 is generated.Data related to the performance of the perforating tool system 120 may include the depth, magnitude, or dimensions of the perforation tunnel created in the formation sample 220 (the simulated fracture site), the geometry of the borehole, the amount of fill or loose material remaining in the simulated borehole casing 260, and the depth of the last fault trace. By controlling the dynamic vacuum, the perforation tunnel can be widened to generate better flow behavior.

[0038] At step 526, one or more modifications are determined based at least in part on any one or more of the generated images, the specific DUB, the amount of perforation tunnel or borehole that remains and can potentially be eliminated, and data associated with the performance of the perforating tool system 120. For example, an optimal DUB is achieved when the tunnel created in the formation sample 220 is empty, and a minimum DUB is achieved when material first appears in the tunnel; at step 528, the perforating tool system 120 is modified. The method may continue or end at step 512. In one or more embodiments, the modified perforating tool system 120 is placed downhole in the wellbore 108 of the drilling system 100.

[0039] Fig. 6A and Fig. 6B illustrate exemplary tunnels that may be inspected by a perforating tool inspection system, for example, the perforating tool inspection system 200 of Fig. 2 or the perforation tool inspection system 300 from Fig. 3, were created. Fig. Figure 6A illustrates a tunnel 610 created due to DUB effects, but prior to any determination of an optimal DUB in the formation sample 220. Fig. Figure 6B illustrates an enlarged tunnel 610 created due to DUB effects after modifications to the perforating tool system 120 to achieve optimal DUB in the formation sample 220. Once the flow of fluid through the tunnel 610 is Fig. 6B, any loose material that may be present in the tunnel 610 of Fig. 6B, and optimal production is achieved. The simulation results of Fig. 6B (and any one or more embodiments of the present disclosure) may be applied to any formation, for example, to the subterranean formation 110 in Fig. 1, be applicable to achieve optimal production of fluid, hydrocarbons or any other subterranean materials.

[0040] By performing testing and simulating a perforating tool system 120 in the controlled environment of the perforating tool testing systems 200 and 300, the performance of a perforating tool system selected for use downhole, for example, the perforating tool system 120 of Fig. 1, can be determined above ground and optimized before placement underground, which reduces the cost of each operation.

[0041] In one or more embodiments, a simulation method for a perforating tool system comprises disposing a perforating tool system in a simulated wellbore of a simulated wellbore casing, the perforating tool system comprising one or more explosive charges, disposing a formation sample adjacent to the perforating tool system in the simulated wellbore casing, introducing one or more filler disks into a cavity of the simulated wellbore, the one or more filler disks 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, pressurizing the simulated wellbore, detonating the one or more explosive charges to create a perforation in the formation sample, generating at least one of data,associated with a performance of the perforating tool system, and one or more images, determining an actual DUB, and modifying the perforating tool system based at least in part on the DUB, the data, and the one or more generated images. In one or more embodiments, the method further comprises flowing a pressurized fluid through the perforating tool system into the perforation. In one or more embodiments, the method further comprises evenly distributing the pressurized fluid using a flow distributor coupled to the formation 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 actual DUB. In one or more embodiments, the method further comprises changing the actual DUB by selecting a different pressurized fluid. In one or more embodiments, the method further comprises changing the DUB by adding a filler disc to the one or more filler discs or removing a filler disc from the one or more filler discs. In one or more embodiments, the method further comprises determining whether the predetermined DUB and the actual DUB are within a predetermined threshold. In one or more embodiments, the method further comprises performing one or more flow tests to measure the yield of the one or more generated shots.

[0042] In one or more embodiments, a simulation drilling system comprises a simulated borehole casing, a simulated borehole disposed within the simulated borehole casing, a faceplate disposed at a first end of the simulated borehole, a perforating tool system disposed within the borehole between a second end and the first end of the simulated borehole, a formation sample disposed within the simulated borehole casing, the formation sample being connected to the faceplate, one or more explosive charges disposed within the perforating tool system, the one or more explosive charges being arranged such that detonation of the explosive charges creates a perforation in the formation sample, and one or more filler disks disposed within the simulated borehole between the second end of the simulated borehole and the perforating tool system.wherein the one or more filler disks affect a dynamic negative pressure of the perforating tool testing system. In one or more embodiments, the simulation drilling system further comprises a pore collector disposed within the wellbore casing, a borehole collector disposed within the wellbore casing, and a bypass valve coupled to the pore collector and the borehole collector, wherein the bypass valve equalizes the pressure between the pore collector and the borehole collector to stop the flow of a pressurized fluid into the formation sample. In one or more embodiments, the simulation drilling system further comprises a flow distributor coupled to the formation sample, wherein the flow distributor evenly distributes a pressurized fluid to the formation sample. In one or more embodiments, the simulation drilling system further comprises an information processing system,wherein the information processing system comprises a processor and a memory coupled to the processor, the memory containing one or more instructions that, when executed by the processor, cause the processor to generate one or more images associated with a perforation of the formation sample. In one or more embodiments, the one or more instructions further cause the processor to determine an actual DUB and to determine a modification of the simulation drilling system based at least in part on the actual DUB.

[0043] One or more embodiments provide a non-transitory computer-readable medium having stored therein one or more instructions that, when executed, cause a processor to determine a target dynamic underpressure (DUB) for a simulation of a drilling operation, determine a perforating tool system for the simulation, determine a design for one or more explosive charges for the simulation, determine a formation sample for the simulation, determine a design of one or more filler disks based at least in part on the target DUB, and perform a simulation, wherein performing the simulation includes pressurizing a simulated wellbore casing, detonating at least one of the one or more explosive charges, determining an actual DUB,generating one or more images of the perforation and determining a modification of the simulation based at least in part on at least one of the actual DUB and the one or more generated images. In one or more embodiments, performing the simulation further comprises flowing a pressurized fluid through the perforating tool system into 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, wherein the one or more properties affect the actual DUB. In one or more embodiments, the one or more instructions, when executed, further cause the processor to determinewhether the predetermined DUB and the actual DUB are within a predetermined threshold. In one or more embodiments, the one or more instructions, when executed, further cause the processor to perform one or more flow tests to determine the yield of the one or more generated images. In one or more embodiments, performing the simulation further comprises reducing the pressure in the simulated wellbore casing to allow flow of a fluid out of the perforation. In one or more embodiments, the one or more instructions, when executed, further cause the processor to measure the flow velocity of the fluid out of the perforation.

[0044] Accordingly, the present disclosure is well adapted to attain the objects and advantages set forth, as well as those attendant thereon. The particular embodiments disclosed above are merely illustrative, since the present disclosure may be modified and practiced in various but equivalent ways that will be apparent to those skilled in the art having the benefit of the teachings contained herein. Furthermore, no limitations are intended with respect to the details of construction or design shown herein except as described in the following claims. Accordingly, it is to be understood that the particular illustrative embodiments disclosed above may be altered or modified, and all such variations are intended to be within the scope and spirit of the present disclosure.In addition, the terms used in the claims have their ordinary, conventional meaning unless they are expressly and unambiguously defined otherwise by the patent proprietor.

Claims

[1] Simulation method for a perforating tool system, comprising: Placing a perforating tool system in a simulated borehole of a simulated borehole casing, wherein the perforating tool system comprises one or more explosive charges; Placing a formation sample adjacent to the perforating tool system in the simulated wellbore casing; Introducing one or more filler disks into a cavity of the simulated borehole, wherein the one or more filler disks are based at least in part on at least one of a predetermined dynamic underpressure (DUB), a size of the simulated borehole, and a size of the cavity; pressurizing the simulated borehole; Detonating the one or more explosive charges to create a perforation in the formation sample; generating at least one of data associated with a performance of the perforating tool system and one or more images; determining an actual DUB; and Modifying the perforating tool system based at least in part on the DUB, the data, and the one or more generated shots. [2] A simulation method for the perforating tool system according to claim 1, further comprising flowing a pressurized fluid through the perforating tool system into the perforation. [3] A simulation method for the perforating tool system of claim 2, further comprising uniformly distributing the pressurized fluid using a flow distributor coupled to the formation sample. [4] A simulation method for the perforating tool system of any one of claims 1 and 2, further comprising 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 actual DUB. [5] A simulation method for the perforating tool system according to any one of claims 1 and 2, further comprising changing the actual DUB by selecting a different pressurized fluid. [6] A simulation method for the perforating tool system according to any one of claims 1 and 2, further comprising changing the DUB by adding a filler disk to the one or more filler disks or removing a filler disk from the one or more filler disks. [7] A simulation method for the perforating tool system according to any one of claims 1, 2 and 6, further comprising determining whether the predetermined DUB and the actual DUB are within a predetermined threshold. [8] A simulation method for the perforating tool system according to any one of claims 1, 2, 6 and 7, further comprising performing one or more flow tests to determine the yield of the one or more generated shots. [9] Simulation borehole system comprising: a simulated borehole casing; a simulated borehole located inside the simulated borehole casing; a front plate disposed at a first end of the simulated borehole; a perforating tool system disposed within the borehole between a second end and the first end of the simulated borehole; a formation sample disposed within the simulated borehole casing, the formation sample being connected to the face plate; one or more explosive charges disposed within the perforating tool system, the one or more explosive charges being arranged such that detonation of the explosive charges creates a perforation in the formation sample; and one or more filler discs disposed within the simulated borehole between the second end of the simulated borehole and the perforating tool system, wherein the one or more filler discs act upon a dynamic negative pressure of the perforating tool testing system. [10] A simulation well system according to claim 9, further comprising: a pore collector arranged inside the simulated borehole casing; a borehole collector arranged inside the simulated borehole casing; and a bypass valve coupled to the pore collector and the wellbore collector, the bypass valve equalizing the pressure between the pore collector and the wellbore collector to stop the flow of a pressurized fluid into the formation sample. [11] A simulation well system according to any one of claims 9 and 10, further comprising a flow distributor coupled to the formation sample, the flow distributor distributing a pressurized fluid evenly to the formation sample. [12] A simulation wellbore system according to any one of claims 9-11, further comprising an information processing system, the information processing system comprising a processor and a memory coupled to the processor, the memory containing one or more instructions that, when executed by the processor, cause the processor to generate one or more images associated with a perforation of the formation sample. [13] The simulation well system of any one of claims 12, wherein the one or more instructions further cause the processor to: to determine an actual DUB; and to determine a modification of the simulation well system at least partly based on the actual DUB.

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