US20210047903A1

US20210047903A1 - Deploying Fluid Tracer Material with a Perforating Gun

Info

Publication number: US20210047903A1
Application number: US16/947,566
Authority: US
Inventors: Larry Albert
Original assignee: Allied Horizontal Wireline Services
Current assignee: Allied Horizontal Wireline Services
Priority date: 2019-08-14
Filing date: 2020-08-06
Publication date: 2021-02-18

Abstract

Apparatus and methods for deploying fluid tracer material with a perforating gun. An example apparatus may include tracer material shaped to facilitate placement within or in association with a perforating gun, wherein detonation of shaped charges of the perforating gun forms perforation tunnels in a subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnels. An example apparatus may include a perforating gun comprising a plurality of shaped charges and containing tracer material, wherein detonation of the shaped charges forms perforation tunnels in the subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnels. An example method may include deploying tracer material into a subterranean formation via a perforating gun.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS

This application claims priority to and the benefit of U.S. Provisional Application No. 62/886,504, titled “DEPLOYING FLUID TRACERS VIA A SHAPED CHARGE,” filed Aug. 14, 2019, the entire disclosure of which is hereby incorporated herein by reference.
This application also claims priority to and the benefit of U.S. Provisional Application No. 62/979,240, titled “DEPLYING FLUID TRACERS WITH A PERFORATING GUN,” filed Feb. 20, 2020, the entire disclosure of which is hereby incorporated herein by reference.

BACKGROUND OF THE DISCLOSURE

Wells are generally drilled into a land surface or ocean bed to recover natural deposits of oil and gas, and other natural resources that are trapped in subterranean geological formations in the Earth's crust. Testing and evaluation of completed and partially finished wells has become commonplace, such as to increase well production and return on investment. Downhole measurements of formation pressure, formation permeability, and recovery of formation fluid samples may be useful for predicting economic value, production capacity, and production lifetime of the subterranean formations.
Completion and stimulation operations of a well, such as perforating and fracturing operations, may also be performed to optimize well productivity. Plugging and perforating tools may be utilized to set plugs within a wellbore to isolate portions of the wellbore and subterranean formations surrounding the wellbore from each other and to perforate the well in preparation for fracturing. Each fracturing stage interval along the wellbore can be perforated with one or more perforating tools (i.e., perforating guns) forming one or more clusters of perforation tunnels along the wellbore. Typically, less than 80% of the perforation tunnels formed along the wellbore are open and/or fractured as intended and fully contribute to fluid production. Although the oil and gas industry continues to improve perforation and fracturing efficiency, it is significantly less than 100%.
Fluid tracers may be included in fracturing fluid for each fracturing stage interval and transmitted into fractures during each stage of fracturing operations. Such fluid tracers may then be detected at the wellsite surface during fluid flow-back and/or production operations to identify the source of the formation fluid produced at the wellsite surface. Fluid tracers deployed during each fracturing stage may be distinguishable from fluid tracers deployed during another fracturing stage. For example, by measuring concentrations and/or quantities of each distinguishable fluid tracer within the fluid produced at the surface, fluid flow (i.e., production) contribution of each fracturing stage interval, and thus effectiveness of perforation and/or fracturing operations within each fracturing stage interval, can be determined. Such information can be used to evaluate and improve completion plans (e.g., perforation and fracturing plans) to improve hydrocarbon production. However, deploying fluid tracers via fracturing fluid during each stage of fracturing operations permits fracture analysis at a fracturing stage interval level, but not at a fracture cluster level within each fracturing stage interval. Information indicative of fracture cluster efficiency can be utilized to further improve completion plans and hydrocarbon production.

BRIEF DESCRIPTION OF THE DRAWINGS

The present disclosure is best understood from the following detailed description when read with the accompanying figures. It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale. In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.

FIG. 1 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 2 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 3 is a sectional view of at least a portion of example implementations of apparatus according to one or more aspects of the present disclosure.

FIG. 4 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 5 is a sectional view of the apparatus shown in FIG. 4.

FIG. 6 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 7 is a sectional view of the apparatus shown in FIG. 6.

FIG. 8 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 9 is a sectional view of the apparatus shown in FIG. 8.

FIG. 10 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIG. 11 is a sectional view of the apparatus shown in FIG. 10.

FIGS. 12-14 are schematic views of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure during different stages of tracer material deployment operations.

FIGS. 15-17 are schematic views of at least a portion of another example implementation of apparatus according to one or more aspects of the present disclosure during different stages of tracer material deployment operations.

FIG. 18 is a schematic view of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure.

FIGS. 19-30 are sectional views of at least a portion of example implementations of apparatus according to one or more aspects of the present disclosure.

FIGS. 31-33 are schematic views of at least a portion of an example implementation of apparatus according to one or more aspects of the present disclosure during different stages of tracer material deployment operations.

FIGS. 34-36 are schematic views of a subterranean formation during tracer material deployment, fracturing, and flow-back operations, respectively, according to one or more aspects of the present disclosure.

DETAILED DESCRIPTION

It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for simplicity and clarity, and does not in itself dictate a relationship between the various embodiments and/or configurations discussed. Moreover, the formation of a first feature over or on a second feature in the description that follows, may include embodiments in which the first and second features are formed in direct contact, and may also include embodiments in which additional features may be formed interposing the first and second features, such that the first and second features may not be in direct contact.
Terms, such as upper, upward, above, lower, downward, and/or below are utilized herein to indicate relative positions and/or directions between apparatuses, tools, components, parts, portions, members and/or other elements described herein, as shown in the corresponding figures. Such terms do not necessarily indicate relative positions and/or directions when actually implemented. Such terms, however, may indicate relative positions and/or directions with respect to a wellbore when an apparatus according to one or more aspects of the present disclosure is utilized or otherwise disposed within the wellbore.
FIG. 1 is a schematic view of at least a portion of an example implementation of a wellsite system 100 according to one or more aspects of the present disclosure representing an example environment in which one or more aspects of the present disclosure may be implemented. The wellsite system 100 is depicted in relation to a wellbore 102 formed by rotary and/or directional drilling and extending from a wellsite surface 104 into a subterranean formation 106. The wellsite system 100 may be utilized to facilitate the recovery of oil, gas, and/or other materials that are trapped in the formation 106 via the wellbore 102. The wellbore 102 comprises a casing 108 secured by cement 109. It is noted that although the wellsite system 100 is depicted as an onshore implementation, it is to be understood that the aspects described below are also generally applicable or readily adaptable to offshore implementations.
The wellsite system 100 includes surface equipment 130 located at the wellsite surface 104 and a downhole intervention and/or sensor assembly, referred to as a tool string 110, conveyed within the wellbore 102 along or through one or more formations 106 via a conveyance line 120 operably coupled with one or more pieces of the surface equipment 130. The conveyance line 120 may be or comprise a cable, a wireline, a slickline, a multiline, an e-line, coiled tubing, and/or other conveyance means. Although the tool string 110 is shown suspended in a vertical portion of the wellbore 102, it is to be understood that the tool string 110 may also or instead be conveyed within non-vertical, horizontal, and otherwise deviated portions of the wellbore 102.
The conveyance line 120 may be operably connected with a conveyance device 140 operable to apply adjustable downward and/or upward forces to the tool string 110 via the conveyance line 120 to convey the tool string 110 within the wellbore 102. The conveyance device 140 may be, comprise, or form at least a portion of a sheave or pulley, a winch, a drawworks, an injector head, and/or another device coupled to the tool string 110 via the conveyance line 120. The conveyance device 140 may be supported above the wellbore 102 via a mast, a derrick, a crane, and/or another support structure 142. The surface equipment 130 may further comprise a reel or drum 146 configured to store thereon a wound length of the conveyance line 120, which may be selectively wound and unwound by the conveyance device 140 to selectively convey the tool string 110 into, within, and out of the wellbore 102.
Instead of or in addition to the conveyance device 140, the surface equipment 130 may comprise a winch conveyance device 144 comprising or operably connected with the drum 146 and operable to selectively convey the tool string 110 within the wellbore 102. The drum 146 may be rotated by a rotary actuator 148 (e.g., an electric motor) to selectively unwind and wind the conveyance line 120, thereby applying an adjustable tensile force to the tool string 110 to selectively convey the tool string 110 into, within, and out of the wellbore 102.
The conveyance line 120 may comprise metal tubing, support wires, and/or cables configured to support the weight of the downhole tool string 110. The conveyance line 120 may also comprise one or more insulated electrical and/or optical conductors 122 operable to transmit electrical energy (i.e., electrical power) and electrical and/or optical signals (i.e., information or data) between the tool string 110 and one or more components of the surface equipment 130, such as a power and control system 150. The conveyance line 120 may comprise and/or be operable in conjunction with means for communication between the tool string 110, the conveyance device 140, the winch conveyance device 144, and/or one or more other portions of the surface equipment 130, including the power and control system 150.
The wellbore 102 may be capped by a plurality (e.g., a stack) of fluid control devices 132, such as fluid control valves, spools, and fittings individually and/or collectively operable to direct and control the flow of fluid out of the wellbore 102. The fluid control devices 132 may also or instead comprise a blowout preventer (BOP) stack operable to prevent the flow of fluid out of the wellbore 102. The fluid control devices 132 may be mounted on top of a wellhead 134.
A sealing and alignment assembly 136 may be mounted on the fluid control devices 132 to seal the conveyance line 120 during deployment, conveyance, intervention, and other wellsite operations. The sealing and alignment assembly 136 may comprise a lock chamber (e.g., a lubricator, an airlock, a riser, etc.) mounted on the fluid control devices 132, a stuffing box operable to seal around the conveyance line 120 at top of the lock chamber, and return pulleys operable to guide the conveyance line 120 between the stuffing box and the drum 146, although such details are not shown in FIG. 1. The stuffing box may be operable to seal around an outer surface of the conveyance line 120, such as via annular packings applied around the surface of the conveyance line 120 and/or by injecting a fluid between the outer surfaces of the conveyance line 120 and an inner wall of the stuffing box. The tool string 110 may be deployed into or retrieved from the wellbore 102 via the conveyance device 140 and/or winch conveyance device 144 through the sealing and alignment assembly 136, the fluid control devices 132, and/or the wellhead 134.
The power and control system 150 (e.g., a control center) may be utilized to monitor and control various portions of the wellsite system 100 by a human operator (e.g., wellsite personnel). The power and control system 150 may be located at the wellsite surface 104 or on a structure located at the wellsite surface 104. However, the power and control system 150 may instead be located remote from the wellsite surface 104. The power and control system 150 may include a source of electrical power 152, a memory device 154, and a surface controller 156 (e.g., a processing device or computer) operable to receive and process signals or information from the tool string 110 and/or commands from the human operator. The power and control system 150 may be communicatively connected with various equipment of the wellsite system 100, such as may permit the surface controller 156 to monitor operations of one or more portions of the wellsite system 100 and/or to provide control of one or more portions of the wellsite system 100, including the tool string 110, the conveyance device 140, and/or the winch conveyance device 144. The surface controller 156 may include input devices for receiving commands from the human operator and output devices for displaying information to the human operator. The surface controller 156 may store executable programs and/or instructions, including for implementing one or more aspects of methods, processes, and operations described herein.
The tool string 110 may comprise a cable head 112 (i.e., a logging head, a cable termination sub, etc.) operable to physically and/or electrically connect the conveyance line 120 with the tool string 110. The cable head 112 may thus permit the tool string 110 to be suspended and conveyed within the wellbore 102 via the conveyance line 120.
The tool string 110 may further comprise one or more downhole tools 114 (e.g., devices, modules, subs, etc.) operable to perform downhole operations. The tools 114 of the tool string 110 may comprise a telemetry tool, such as may facilitate communication between the tool string 110 and the surface controller 156. The tools 114 may comprise a downhole controller communicatively connected with the surface controller 156 via the conductor 122 and with other portions of the tool string 110. The downhole controller may be operable to store and/or communicate to the tool string control system 150 signals or information generated by one or more sensors or instruments of the tool string 110. The downhole controller may be operable to control one or more portions of the tool string 110. For example, the downhole controller may be operable to receive, store, and/or process control commands from the tool string control system 150 for controlling one or more portions of the tool string 110. The tools 114 may further comprise one or more inclination and/or directional sensors, such as one or more accelerometers, magnetometers, gyroscopic sensors (e.g., micro-electro-mechanical system (MEMS) gyros), and/or other sensors for determining the orientation and/or direction of the tool string 110 within the wellbore 102. The tools 114 may also or instead comprise a depth correlation tool, such as a casing collar locator (CCL) for detecting ends of casing collars by sensing a magnetic irregularity caused by the relatively high mass of an end of a collar of the casing 108. The depth correlation tool may also or instead be or comprise a gamma ray (GR) tool.
The tool string 110 comprises one or more perforating tools 116 (i.e., perforating guns) operable to perforate or form perforations (e.g., holes) though the casing 108, the cement 109, and a portion of the formation 106 surrounding the wellbore 102 to prepare the well for stimulation (e.g., hydraulic fracturing) and production. Each perforating tool 116 may comprise a plurality (e.g., a set or cluster) of perforating devices 117 (e.g., shaped explosive charges). Each perforating device 117 may be operable to perforate the casing 108, the cement 109, and the formation 106 upon detonation. Each perforating tool 116 may thus be operable to form a plurality 111 (e.g., a set or cluster) of perforation tunnels 113 extending through the casing 108 and the cement 109 and into the formation 106. The tool string 110 may also comprise one or more plugs 118 and plug setting tools 119 for setting the plugs 118 at intended (i.e., predetermined) positions within the wellbore 102, such as to isolate or seal portions (e.g., the fracturing stage intervals 103, 105, 107) of the wellbore 102 between successive stages of fracturing operations.
The power and control system 150 (e.g., surface controller 156) may be communicatively and/or electrically connected with the tool string 110 via the conductor 122 extending between the power and control system 150 and the tool string 110. However, the tool string 110 may also or instead be communicatively connected with the power and control system 150 by other means, such as capacitive or inductive coupling. The conductor 122 may extend through or along at least a portion of the tool string 110, such as to communicatively and/or electrically connect one or more portions of the tool string 110 with the power and control system 150. The electrical conductor 122 extending through the tool string 110 may also facilitate electrical communication between two or more portions of the tool string 110. One or more of the cable head 112, the downhole tools 114, the perforating tools 116, and/or the plug setting tool 119 may comprise corresponding electrical conductors, connectors, and/or interfaces forming a portion of the conductor 122 extending through the tool string 110. The conductor 122 may extend through the conveyance line 120 and externally from the conveyance line 120 at the wellsite surface 104 via a rotatable joint or coupling (e.g., a collector) (not shown) carried by the drum 146.
During plugging and perforating (“plug and perf”) operations, a plug 118 may be set (i.e., installed) within the wellbore 102 by the plug setting tool 119 to seal a previously fractured (lower) fracturing stage interval 103 of the wellbore 102 from a subsequent (upper) fracturing stage interval 105 of the wellbore 102. The plug 118 may be permanent or retrievable, facilitating the fracturing stage interval 103 to be permanently or temporarily isolated or sealed from the fracturing stage interval 105. After the plug 118 is set within the wellbore 102, the tool string 110 may be conveyed upward to an intended depth and one or more of the perforating tools 116 may be operated to form an intended quantity of clusters 111 of perforation tunnels 113 through the casing 108 and the cement 109 and into the formation 106 within the fracturing stage interval 105. After the wellbore 102 is perforated at one or more depths within the fracturing stage interval 105, the tool string 110 may be retrieved from the wellbore 102 and the fracturing stage interval 105 may be hydraulically fractured, such as via pressure-pumping operations.
After the fracturing stage interval 105 is fractured, the tool string 110 may be deployed within the wellbore 102 and conveyed to an intended depth. The plug setting tool 119 may then set another plug 118 within the wellbore 102 to fluidly seal the previously fractured (now lower) fracturing stage interval 105 from a subsequent (upper) fracturing stage interval 107. One or more other perforating tools 116 may be operated to perforate the casing 108, the cement 109, and the formation 106 at one or more depths within the fracturing stage interval 107. After an intended quantity of clusters 111 of perforation tunnels 113 are formed along the wellbore 102 within the fracturing stage interval 107, the tool string 110 may be retrieved from the wellbore 102 and the fracturing stage interval 107 may be fractured. Such actions may be repeated for each subsequent fracturing stage interval until the entire wellbore 102 is prepared for production.
FIG. 2 is a schematic side view of at least a portion of an example implementation of a perforating tool 200 (i.e., a perforating gun) according to one or more aspects of the present disclosure. The perforating tool 200 may be an example implementation of, and/or comprise one or more features of, the perforating tools 116 described above and shown in FIG. 1. Accordingly, the following description refers to FIGS. 1 and 2, collectively.
The perforating tool 200 comprises a plurality of perforating devices 210 (e.g., shaped charges, shaped explosives, perforating charges, etc.), each comprising a liner 214, an explosive material 212 on one side of the liner 214, and a case 215 on one side of the explosive material 212. After the perforating tool 200 is conveyed to an intended depth within the wellbore 102, the explosive material 212 of each perforating device 210 can be detonated to propel a corresponding liner 214 at a high speed and pressure into a sidewall of the wellbore 102 to perforate or otherwise create a perforation tunnel 113 through the casing 108 and the cement 109 and into the formation 106 surrounding the wellbore 102. Although the perforating tool 200 is shown comprising sixteen perforating devices 210 (four columns of perforating devices 210 distributed at 90 degrees apart) and thus operable to create a cluster 111 of sixteen perforations 113, it is to be understood that the perforating tool 200 can include other quantities of perforating devices 210.
Each explosive material 212 of the perforating devices 210 may be detonated by a detonating cord 220 connected with or otherwise disposed in association with each perforating device 210 of the perforating tool 200. An electrical detonator 218 may be connected with the detonating cord 220 and operable to detonate the detonating cord 218 to detonate the explosive material 212 of each perforating device 210. The detonator 218 may be connected to an electrical conductor 222, which may extend though the perforating tool 200 between opposing upper and lower ends of the perforating tool 200. The conductor 222 may be connected with or form a portion of the conductor 122 extending through the tool string 110 and the conveyance line 120 to the surface equipment 130. The detonator 218 may also or instead be communicatively connected with a detonator switch (e.g., an addressable switch, a pressure switch, etc.) (not shown) located within the tool string 110. The detonator switch may facilitate selective detonation, from the wellsite surface 104, of the explosive material 212 of the perforating devices 210 of one or more perforating tools 200 coupled along the tool string 110.
The perforating devices 210 may be held in relative position and in an intended direction by a support tube 224 (i.e., a charge tube). For example, the perforating devices 210 may be distributed longitudinally and circumferentially along the support tube 224 and directed radially outward from the support tube 224. Each perforating device 210 may be disposed partially or entirely within a corresponding cavity or opening extending radially within or through the support tube 224. The support tube 224 may be disposed within an outer housing 226 (i.e., a carrier tube) of the perforating tool 200. The outer housing 226 may fluidly isolate internal portions (e.g., each perforating device 210) of the perforating tool 200 from wellbore fluid when the perforating tool 200 is conveyed within the wellbore 102.
The perforating tool 200 may comprise an upper (i.e., uphole) connector 230 operable to mechanically and electrically connect the perforating tool 200 with an upper portion of the tool string 110, such as a downhole tool 114 or another perforating tool 200. The perforating tool 200 may further comprise a lower (i.e., downhole) connector 232 operable to mechanically and electrically connect the perforating tool 200 with a lower portion of the tool string 110, such as a plug setting tool 119 or another perforating tool 200.
FIG. 3 is a sectional side view of at least a portion of an example implementation of a perforating device 300 (i.e., a shaped charge, shaped explosive, a perforating charge, etc.) according to one or more aspects of the present disclosure. The perforating device 300 may be or comprise an example implementation of, and/or comprise one or more features of, the perforating devices 117, 210 described above and shown in FIGS. 1 and 2, respectively. A plurality of perforating devices 300 may be installed or otherwise utilized in association with a perforating tool, such as the perforating tool 116, 200 described above and shown in FIGS. 1 and 2, respectively. Accordingly, the following description refers to FIGS. 1-3, collectively.
The perforating device 300 may comprise a case 310 (i.e., a housing), a main explosive material 312 (i.e., a main explosive load, a secondary explosive, etc.) disposed within the case 310, and a liner 314 partially surrounded by the main explosive material 312. The liner 314 may have a generally conical shape, having an outer surface in contact with the main explosive material 312 and an inner surface defining a conical-shaped hollow (e.g., air-filled) cavity 320 (i.e., a stand-off space). The liner 314 may be or comprise a metal, such as copper, aluminum, lead, and/or tin, among other examples. The liner 314 may be or comprise a powdered metal, such as a metal matrix composite, shaped (e.g., pressed) into an intended form. The cavity 320 may define a front face of the perforating device 300. A primer explosive material 316 (i.e., primer load) may be disposed at the base (or bottom) of the case 310 in contact with the main explosive material 312 and adjacent an opening or hole 318 through the case 310. A detonating cord 317 may extend along the case 310 adjacent to or over the hole 318. The detonating cord 317 may be connected to the case 310 via a guide or holder (not shown) integrally formed with or otherwise connected with the case 310. Upon being detonated by a detonator 218, the detonating cord 317 detonates the primer explosive material 316, which, in turn, detonates the main explosive material 312. The main explosive material 312 may be or comprise, for example, RDX, HMX, or HNS, and a binding agent (i.e., binder), such as wax or a polymer. The primer explosive material 316 may be or comprise, for example, RDX, HMX, or HNS, but without a binding agent. Although the main explosive material 312 of the perforating device 300 may be detonated by the detonating cord 317 and the primer explosive material 316, it is to be understood that the main explosive material 312 may be detonated by other means, such as an electric detonator (i.e., a blasting cap) (not shown) disposed at the base of the case 310 and electrically connected with the conductor 222 or a detonator switch.
The present disclosure is further directed to systems and methods (e.g., steps, operations, processes, etc.) for deploying tracer material into a subterranean formation 106 and then monitoring the tracer material carried by the formation fluid to the wellsite surface 104 to trace the source of the formation fluid. The tracer material may be may be disposed within or otherwise as part of the perforating tool 200. For example, the tracer material may be installed or otherwise disposed in association with the perforating devices 210. The tracer material may also or instead be disposed within the support tube 224. The tracer material may also or instead be disposed within an annular space 228 between the support tube 224 and the outer housing 226. During perforation operations, high pressure gas is released upon detonation and explosion of the explosive material 212 of the perforating devices 210, increasing internal pressure within the perforating tool 200. The high-pressure gas then escapes from the perforating tool 200 at high speed via holes formed (e.g., cut) by the high-speed liner and the force of the exploding explosive material 212. The escaping, high-pressure gas may break up and drawl, propel, discharge, or otherwise force the tracer material out of the perforating tool 200 and into the perforation tunnels 113 in the formation 106 formed by the high-speed liners 214, thereby deploying the tracer material into the formation 106.
After the tracer material is deployed into the formation 106, concentrations or amounts of the tracer material being carried or flowing back to the wellsite surface 104 during flow back and/or production may be detected at the wellsite surface 104 to identify the source of the formation fluid reaching the wellsite surface 104. The tracer material associated with different perforating devices 210 and/or different perforating tools 200 may be different or otherwise distinguishable (i.e., comprising different detectable signatures or characteristics) from each other, thereby permitting identification of the source of formation fluid flowing to the wellsite surface 104. Accordingly, the tracer material may be used to monitor or identify contributions of formation fluids (e.g., hydrocarbons) flowing from different portions (e.g., fracturing stage intervals and/or clusters of perforation tunnels) of the wellbore 102 and the formation 106 to the wellsite surface 104. The tracer material may be or comprise, for example, radioactive tracers, chemical tracers, deoxyribonucleic acid (DNA) tracers, and/or other fluid tracers. Each type of tracer material may be associated with a corresponding means of being detected in the fluid at the wellsite surface 104.
FIG. 4 is a schematic side view of at least a portion of an example implementation of a perforating tool 410 (i.e., a perforating gun) according to one or more aspects of the present disclosure. FIG. 5 is a sectional axial view of the perforating tool 410 shown in FIG. 4. The perforating tool 410 may be an example implementation of, and/or comprise one or more features of, the perforating tool 200 described above and shown in FIG. 2, including where indicated by the same reference numerals. The following description refers to FIGS. 1, 2, 4, and 5, collectively.
The perforating tool 410 may contain tracer material 412 in an annular space 414 between the support tube 224 and the outer housing 226 in front of the perforating devices 210 such that, upon detonation of the perforating devices 210, a high-speed and high-pressure jet of liner particles and gas caused by detonation of the perforating devices 210 draws, propels, discharges, or otherwise forces the tracer material 412 out of the perforating tool 420 and into the perforation tunnels 113 formed by the perforating devices 210 in the formation 106. The tracer material 412 may be inserted or otherwise disposed into the annular space 414 (such as via a radial opening in a sidewall of the outer housing 226, as indicated by arrow 416, or via an axial opening at an end of the outer housing 226, as indicated by arrow 418) after the support tube 224 is inserted into the outer housing 226 and before the outer housing 226 is enclosed by connection of the upper connector 230 with the outer housing 226.
The tracer material 412 may be or comprise tracer material particles (e.g., powder, pellets, etc.) that can be poured, dispensed, or otherwise disposed into the annular space 414. The tracer material 412 may instead be formed or otherwise shaped into one or more solid units or members to facilitate placement within the annular space 414. For example, the tracer material 412 may be formed or otherwise shaped into one or more ring-shaped or annular-shaped members to permit placement within the annular space 414 around the support tube 224. The tracer material 412 may instead be formed or otherwise shaped into a plurality of ring or annular segments to permit placement within the annular space 414 to collectively extend around the support tube 224. Each unit of tracer material 412 may be shaped by compressing or pressing the tracer material particles within a mold having the intended shape of the tracer material 412. The tracer material 412 may also or instead be shaped by mixing tracer material particles with a fluid binder to form a tracer material slurry, which may be poured into a mold having the intended shape of the tracer material 412 and permitted to solidify. The tracer material 412 may also or instead be shaped by melting solid tracer material (e.g., tracer material particles), pouring the molten tracer material into a mold having the intended shape of the tracer material 412, and cooling molten tracer material within the mold.
FIG. 6 is a schematic side view of at least a portion of an example implementation of a perforating tool 420 (i.e., a perforating gun) according to one or more aspects of the present disclosure. FIG. 7 is a sectional axial view of the perforating tool 420 shown in FIG. 6. The perforating tool 420 may be an example implementation of, and/or comprise one or more features of, the perforating tool 200 described above and shown in FIG. 2, including where indicated by the same reference numerals. The following description refers to FIGS. 1, 2, 6, and 7, collectively.
The perforating tool 420 may contain tracer material 422 within an internal space 424 of the support tube 224 adjacent the perforating devices 210 such that, upon detonation of the perforating devices 210, a high-speed and high-pressure jet of liner particles and gas caused by detonation of the perforating devices 210 draws, propels, discharges, or otherwise forces the tracer material 422 out of the perforating tool 420 and into the perforation tunnels 113 formed by the perforating devices 210 in the formation 106. The tracer material 422 may be or comprise tracer material particles (e.g., powder, pellets, etc.) that can be poured, dispensed, or otherwise disposed into the internal space 424, such that the tracer material 422 fills the internal space 424 around and between the perforating devices 210. The tracer material 422 may be inserted or otherwise disposed into the internal space 424 (such as via a radial opening in a sidewall of the support tube 224, as indicated by arrow 426, or via an axial opening at an end of the support tube 224, as indicated by arrow 428) before the support tube 224 is inserted into the outer housing 226 or before the outer housing 226 is enclosed via connection of the upper connector 230 with the outer housing 226.
FIG. 8 is a schematic side view of at least a portion of an example implementation of a perforating tool 430 (i.e., a perforating gun) according to one or more aspects of the present disclosure. FIG. 9 is a sectional axial view of the perforating tool 430 shown in FIG. 8. The perforating tool 430 may be an example implementation of, and/or comprise one or more features of, the perforating tool 200 described above and shown in FIG. 2, including where indicated by the same reference numerals. The following description refers to FIGS. 1, 2, 8, and 9, collectively.
The perforating tool 430 may contain tracer material 432 within an internal space 434 of the support tube 224 between and adjacent the perforating devices 210 such that, upon detonation of the perforating devices 210, a high-speed and high-pressure jet of liner particles and gas caused by detonation of the perforating devices 210 draws, propels, discharges, or otherwise forces the tracer material 432 out of the perforating tool 430 and into the perforation tunnels 113 formed by the perforating devices 210 in the formation 106. The tracer material 432 may be inserted or otherwise disposed into the internal space 434 (such as via an axial opening at an end of the support tube 224, as indicated by arrow 436) before the support tube 224 is inserted into the outer housing 226 or before the outer housing 226 is enclosed via connection of the upper connector 230 with the outer housing 226.
The tracer material 432 may be or comprise tracer material particles (e.g., powder, pellets, etc.) held within one or more containers, which may be disposed axially within the internal space 434 between the perforating devices 210. The containers may be elongated or cylindrical, such that the containers may be inserted within the internal space 434 between the perforating devices 210. The containers may be or comprise, for example, thin-walled paper, aluminum, rubber, polyurethane, polypropylene, polyethylene, and/or other metal or elastomeric materials that can be broken by the detonation of the perforating devices 210.
The tracer material 432 may instead be formed or otherwise shaped into one or more solid units or members to facilitate placement within the internal space 434. For example, the tracer material 432 may be formed or otherwise shaped into one or more cylindrical members or units to permit placement within the internal space 434 between the perforating devices 210. Each unit of tracer material 432 may be shaped by compressing or pressing the tracer material particles within a mold having the intended shape of the tracer material 432. The tracer material 432 may also or instead be shaped by mixing tracer material particles with a fluid binder to form a tracer material slurry, which may be poured into a mold having the intended shape of the tracer material 432 and permitted to solidify. The tracer material 432 may also or instead be shaped by melting solid tracer material (e.g., tracer material particles), pouring the molten tracer material into a mold having the intended shape of the tracer material 432, and cooling molten tracer material within the mold.
FIG. 10 is a schematic side view of at least a portion of an example implementation of a perforating tool 440 (i.e., a perforating gun) according to one or more aspects of the present disclosure. FIG. 11 is a sectional axial view of the perforating tool 440 shown in FIG. 10. The perforating tool 440 may be an example implementation of, and/or comprise one or more features of, the perforating tool 200 described above and shown in FIG. 2, including where indicated by the same reference numerals. The following description refers to FIGS. 1, 2, 10, and 11, collectively.
The perforating tool 440 may contain tracer material 442 within an internal space 444 of the support tube 224 adjacent the perforating devices 210 such that, upon detonation of the perforating devices 210, a high-speed and high-pressure jet of liner particles and gas caused by detonation of the perforating devices 210 draws, propels, discharges, or otherwise forces the tracer material 442 out of the perforating tool 440 and into the perforation tunnels 113 formed by the perforating devices 210 in the formation 106. The tracer material 442 may be disposed within the internal space 444, such as via a plurality of radial openings in a sidewall of the support tube 224, thereby permitting the tracer material 442 to be inserted into the support tube 224 at a plurality of axial locations along the support tube 224, as indicated by arrows 446. The tracer material 442 may be inserted or otherwise disposed into the internal space 444 before the support tube 224 is inserted into the outer housing 226.
The tracer material 442 may be or comprise tracer material particles (e.g., powder, pellets, etc.) held within a plurality of containers, which may be disposed within the internal space 444 between the perforating devices 210. The containers may be disk-shaped or cylindrical, such that the containers may be inserted within the internal space 444 via the radial openings located between the perforating devices 210. The containers may be or comprise, for example, thin-walled paper, aluminum, rubber, polyurethane, polypropylene, polyethylene, and/or other metal or elastomeric materials that can be broken by the detonation of the perforating devices 210.
The tracer material 442 may instead be formed or otherwise shaped into a plurality of solid units or members to facilitate placement within the internal space 444. For example, the tracer material 442 may be formed or otherwise shaped into a plurality of disks, cylinders, or other flat units to permit placement within the internal space 444 via the radial openings located between the perforating devices 210. Each unit of tracer material 442 may be shaped by compressing or pressing tracer material particles (e.g., pellets, powder, etc.) within a mold having the intended shape of the tracer material 442. The tracer material 442 may also or instead be shaped by mixing tracer material particles with a fluid binder to form a tracer material slurry, which may be poured into a mold having the intended shape of the tracer material 442 and permitted to solidify. The tracer material 442 may also or instead be shaped by melting solid tracer material (e.g., tracer material particles), pouring the molten tracer material into a mold having the intended shape of the tracer material 442, and cooling molten tracer material within the mold.
The present disclosure is further directed to methods of deploying tracer material into a subterranean formation via a perforating tool (i.e., a perforating gun). FIGS. 12-14 are schematic sectional views of a portion of the perforating tool 410 shown in FIGS. 4 and 5 comprising the perforating devices 300 shown in FIG. 3 during different stages of tracer deployment operations, during which the tracer material 412 is deployed (e.g., moved, transferred, delivered, etc.) into the perforation tunnels 113 extending into the subterranean formation 106 according to one or more aspects of the present disclosure. The following description refers to FIGS. 1-5 and 12-14, collectively.
Prior to conveying the perforating tool 410 downhole, the perforating tool 410 may be assembled at the wellsite surface 104, including disposing tracer material 412 into the annular space 414 between the support tube 224 and the outer housing 226. The perforating tool 410, along with one or more other perforating tools 410, may then be coupled within or as part of the tool string 110. The tracer material 412 associated with each perforating tool 410 of the tool string 110 may be different or otherwise distinguishable (i.e., comprising different detectable signatures or characteristics) from the tracer material 412 associated with other perforating tools 410 of the tool string 110. The tool string 110 may then be conveyed within the wellbore 102 until an intended one of the perforating tools 410 is at an intended depth. The perforating devices 300 of one or more of the perforating tools 410 may then be operated (detonated) from the wellsite surface 104 or by the downhole controller to perforate the well 102 and deploy the tracer material into the formation 106.
FIG. 12 shows a stage of tracer material deployment operations, shortly after the main explosive material 312 is detonated 350. A pressure wave generated by the exploding 350 main explosive material 312 folds or otherwise collapses the liner 314 within the hollow cavity 320, as indicated by arrows 358, and simultaneously propels the liner 314 along a central axis of the perforating device 300. The pressure wave breaks up the liner 314 into liner particles 352, forming a high-pressure and high-speed jet of liner particles 352 and gas directed toward a sidewall of the wellbore 102, as indicated by arrow 360. Before impacting the sidewall of the wellbore 102, the jet of liner particles 352 may pass through the tracer material 412 and penetrate the outer housing 226 of the perforating tool 410, forming a hole 361 therethrough.
FIG. 13 shows the jet of liner particles 352 perforating the casing 108, the cement 109, and the formation 106, thereby creating a perforation tunnel 113 extending into the formation 106. The exploding 350 explosive material 312 pressurizes the perforating tool 410, increasing pressure within the outer housing 226, the support tube 224, and other portions of the perforating tool 410. The high-pressure and high-speed jet of liner particles 352 and gas caused by the exploding 350 explosive material 312 breaks up the tracer material 412 (if shaped) into tracer material particles 356 and draws, propels, discharges, or otherwise forces the tracer material particles 356 along and behind the liner particles 352, out of the perforating tool 410, and then toward and into the perforation tunnel 113, as indicated by arrows 362.
As shown in FIG. 14, the high-pressure gas formed by the exploding 350 explosive material 312 that is trapped within the outer housing 226, the support tube 224, and other portions of the perforating tool 410 continues to flow out of the perforating tool 410 via the hole 361, and into the perforation tunnel 113, which is at a substantially lower pressure. The high-pressure and high-speed flow of gas continues to break up the tracer material 412 into tracer material particles 356 and discharge the tracer material particles 356 out of the perforating tool 410 (via the hole 361) and into the perforation tunnel 113, as indicated by arrows 364. The tracer material particles 356 may continue to flow into the perforation tunnel 113 until all or substantially all of the tracer material 412 is discharged from the perforating tool 410, or until the gas pressure within the perforating tool 410 equalizes with the pressure within the wellbore 102 and/or the perforation tunnel 113.
FIGS. 15-17 are schematic sectional views of a portion of the perforating tool 420 shown in FIGS. 6 and 7 comprising the perforating devices 300 shown in FIG. 3 during different stages of tracer deployment operations, during which the tracer material 422 is deployed into the perforation tunnels 113 extending into the subterranean formation 106 according to one or more aspects of the present disclosure. The following description refers to FIGS. 1-3, 6, 7, and 15-17, collectively.
Prior to conveying the perforating tool 420 downhole, the perforating tool 420 may be assembled at the wellsite surface 104, including disposing the tracer material 422 into the internal space 424 within the support tube 224. The perforating tool 420, along with one or more other perforating tools 420, may then be coupled within or as part of the tool string 110. The tracer material 422 associated with each perforating tool 420 of the tool string 110 may be different or otherwise distinguishable (i.e., comprising different detectable signatures or characteristics) from the tracer material 422 associated with other perforating tools 420 of the tool string 110. The tool string 110 may then be conveyed within the wellbore 102 until a predetermined one of the perforating tools 420 is at an intended depth. The perforating devices 300 of one or more of the perforating tools 420 may then be operated (detonated) from the wellsite surface 104 or by the downhole controller to perforate the well 102 and deploy the fluid tracers into the formation 106.
FIG. 15 shows a stage of tracer material deployment operations, shortly after the main explosive material 312 is detonated 350. A pressure wave generated by the exploding 350 main explosive material 312 folds or otherwise collapses the liner 314 within the hollow cavity 320, as indicated by arrows 358, and simultaneously propels the liner 314 along a central axis of the perforating device 300. The pressure wave breaks up the liner 314 into liner particles 352, forming a high-pressure and high-speed jet of liner particles 352 and gas directed toward a sidewall of the wellbore 102, as indicated by arrow 360. Before impacting the sidewall of the wellbore 102, the jet of liner particles 352 may penetrate an outer housing 226 of the perforating tool 420, forming a hole 361 therethrough.
FIG. 16 shows the jet of liner particles 352 perforating the casing 108, the cement 109, and the formation 106, thereby creating a perforation tunnel 113 extending into the formation 106. The exploding 350 explosive material 312 pressurizes the perforating tool 420, increasing the pressure within the outer housing 226, the support tube 224, and other portions of the perforating tool 420. The high-pressure and high-speed gas escaping the perforating tool 420 draws, propels, discharges, or otherwise forces the tracer material particles 356 along and behind the liner particles 352, out of the perforating tool 420, and then toward and into the perforation tunnel 113, as indicated by arrows 362. The tracer material particles 356 may be discharged out of the support tube 224 via a radial opening in the support tube 224 accommodating the perforating device 300. The pressure wave generated by the exploding 350 main explosive material 312 and/or the high-pressure and high-speed gas escaping the support tube 224 may enlarge the radial opening in the support tube 224, thereby permitting the tracer material particles 356 to be discharged out of the support tube 224, as indicated by the arrows 362.
As shown in FIG. 17, the high-pressure gas formed by the exploding 350 explosive material 312 that is trapped within the outer housing 226, the support tube 224, and other portions of the perforating tool 420 continues to flow out of the perforating tool 420 (via the hole 361) and into the perforation tunnel 113, which is at a substantially lower pressure. The high-pressure and high-speed flow of gas continues to discharge the tracer material particles 356 out of the support tube 224 and the perforating tool 420 via the hole 361 and into the perforation tunnel 113, as indicated by arrows 364. The tracer material particles 356 may continue to flow into the perforation tunnel 113 until all or substantially all of the tracer material 422 is discharged from the perforation tool 420, or until the gas pressure within the perforating tool 420 equalizes with the pressure within the wellbore 102 and/or the perforation tunnel 113.
Tracer deployment operations via the perforating tools 430, 440 shown in FIGS. 8-11 may be similar to the tracer deployment operations described above in association with the perforating tool 420 shown in FIG. 15-17. For example, during tracer deployment operations via the perforating tools 430, 440, the exploding 350 explosive material 312 pressurizes the perforating tools 430, 440, increasing the pressure within the outer housing 226, the support tube 224, and other portions of the perforating tools 430, 440. Thereafter, high-pressure and high-speed flow of gas escaping from the perforating tools 430, 440 breaks up the tracer material 432, 442 (if shaped) and/or breaks the containers holding particulate tracer material 432, 442, and draws, propels, discharges, or otherwise forces the tracer material particles 356 out of the support tube 224 and the perforating tool 430, 440 via the hole 361 and into the perforation tunnel 113.
FIG. 18 is a schematic view of at least a portion of an example implementation of a perforating tool 500 (i.e., a perforating gun) according to one or more aspects of the present disclosure. The perforating tool 500 may be an example implementation of, and/or comprise one or more features of, the perforating tool 200 described above and shown in FIG. 2, including where indicated by the same reference numerals. The following description refers to FIGS. 1, 2, and 18, collectively.
The perforating tool 500 comprises a plurality of perforating devices 210, each comprising a liner 214, an explosive material 212 on one side of the liner 214, and a case 215 on one side of the explosive material 212. After the perforating tool 500 is conveyed to an intended depth within the wellbore 102, the explosive material 212 of each perforating device 210 can be detonated to propel a corresponding liner 214 at high-speed and high-pressure into a sidewall of the wellbore 102 to perforate or otherwise create a perforation tunnel 113 through the casing 108 and the cement 109 and extending into the formation 106 surrounding the wellbore 102. A batch (e.g., a predetermined weight or volume, number of fluid tracer particles, etc.) of tracer material 502 may be disposed in association with each perforating device 210, such that upon detonation of the explosive material 212, a high-speed jet of liner particles and gas caused by the detonation breaks up and draws, propels, discharges, or otherwise forces the tracer material 502 along a corresponding perforation tunnel 113 into the formation 106. Each batch of the tracer material 502 may be disposed in front of the liner 214 of a corresponding perforating device 210. Although the perforating tool 500 is shown comprising sixteen perforating devices 210 (four columns of perforating devices 210 distributed at 90 degrees apart) and thus operable to create a cluster 111 of sixteen perforations 113, it is to be understood that the perforating tool 500 can include other quantities of perforating devices 210.
Each explosive material 212 of the perforating devices 210 may be detonated by a detonating cord 220 connected with or otherwise disposed in association with each perforating device 210 of the perforating tool 500. An electric detonator 218 may be connected with the detonating cord 220 and operable to detonate the detonating cord 218 to detonate the explosive material 212 of each perforating device 210. The detonator 218 may be connected to an electrical conductor 222, which may extend though the perforating tool 500 between opposing upper and lower ends of the perforating tool 500. The conductor 222 may be or form a portion of the conductor 122 extending through the tool string 110 and the conveyance line 120 to the surface equipment 130. The detonator 218 may also or instead be communicatively connected with a detonator switch (e.g., an addressable switch, a pressure switch, etc.) (not shown) located within a downhole tool 114 of the tool string 110. The detonator switch may permit selective detonation, from the wellsite surface 104, of the perforating devices 210 of one or more perforating tools 500 coupled along the tool string 110.
The perforating devices 210 may be held in relative position by a support tube 224 (i.e., a charge tube). The perforating devices 210 may be distributed longitudinally and circumferentially along the support tube 224 and directed radially outward from the support tube 224. Each perforating device 210 may be disposed partially or entirely within a corresponding cavity or opening extending radially within or through the support tube 224. Similarly, each batch of the tracer material 502 may be disposed partially or entirely within a corresponding cavity or opening in the support tube 224. However, each batch of the tracer material 502 may be disposed outside or extend at least partially out of the corresponding cavity or opening in the support tube 222. For example, each batch of the tracer material 502 may extend radially outward past an outer surface of the support tube 224. The support tube 224 may be disposed within an outer housing 226 (i.e., carrier tube) of the perforating tool 500. The outer housing 226 may fluidly isolate each perforating device 210 and corresponding tracer material 502 from wellbore fluid when the perforating tool 500 is conveyed within the wellbore 102.
The perforating tool 500 may comprise an upper (i.e., uphole) connector 230 operable to mechanically and electrically connect the perforating tool 500 with an upper portion of the tool string 110, such as a downhole tool 114 or another perforating tool 500. The perforating tool 500 may further comprise a lower (i.e., downhole) connector 232 operable to mechanically and electrically connect the perforating tool 500 with a lower portion of the tool string 110, such as a plug setting tool 119 or another perforating tool 500.
FIG. 19 is a schematic sectional view of at least a portion of an example implementation of a perforating and tracer assembly 600 comprising a perforating device 602 (i.e., a shaped charge, shaped explosive, a perforating charge, etc.) and a tracer cap 604 comprising tracer material 622 according to one or more aspects of the present disclosure. The perforating device 602 may comprise one or more features of the perforating device 300 described above and shown in FIG. 3, including where indicated by the same reference numerals. A plurality of the assemblies 600 or just the tracer caps 604 may be installed or otherwise utilized as part of or in association with a perforating tool, such as one or more of the perforating tools 116, 200, 410, 420, 430, 440, 500 described above and show in FIGS. 1, 2, 4-11, and 18. The following description refers to FIGS. 1, 18, and 19, collectively.
The perforating device 602 may comprise a case 310 (i.e., a housing), a main explosive material 312 (i.e., a main explosive load, a secondary explosive) disposed within the case 310, and a liner 314 partially surrounded by the main explosive material 312. The liner 314 may have a generally conical shape, having an outer surface in contact with the main explosive material 312 and an inner surface defining a conical-shaped hollow (e.g., air-filled) cavity 320 (i.e., a stand-off space). The liner 314 may be or comprise metal, such as copper, aluminum, lead, and/or tin, among other examples. The liner 314 may be or comprise powdered metal, such as a metal matrix composite, shaped into an intended form. The cavity 320 may define a front face of the perforating device 602. A primer explosive material 316 (i.e., primer load) may be disposed at the base (bottom) of the case 310 in contact with the main explosive material 312 and adjacent an opening or hole 318 through the case 310. A detonating cord 317 may extend along the case 310 adjacent to or over the hole 318. The detonating cord 317 may be connected to the case 310 via a guide or holder (not shown) integrally formed with or otherwise connected with the case 310. Upon being detonated by the detonator 218, the detonating cord 317 may detonate the primer explosive material 316, which, in turn, may detonate the main explosive material 312. The main explosive material 312 may be or comprise, for example, RDX, HMX, or HNS, and a binding agent (i.e., binder), such as wax or a polymer. The primer explosive material 316 may be or comprise, for example, RDX, HMX, or HNS, but without a binding agent. Although the main explosive material 312 of the perforating device 602 may be detonated by the detonating cord 317 and the primer explosive material 316, it is to be understood that the main explosive material 312 may be detonated by other means, such as an electric detonator (i.e., a blasting cap) (not shown) disposed at the base of the case 310 and electrically connected with the conductor 222 or a detonator switch.
The tracer cap 604 may contain or comprise a batch (e.g., a predetermined weight or volume, number of fluid tracer particles, etc.) of the tracer material 622 connected to or otherwise disposed in association with the perforating device 602. The tracer material 622 may be formed or otherwise shaped to facilitate placement in association with the perforating device 602. For example, the tracer material 622 may be formed or otherwise shaped to facilitate placement in front of the liner 314 of the perforating device 602 such that, upon detonation of the main explosive material 312, a high-speed and high-pressure jet of liner particles and gas breaks up and draws, propels, discharges, or otherwise forces the tracer material 622 into the formation 106. The tracer material 622 may be shaped to define a hollow cavity 624 (i.e., stand-off space). The hollow cavity 624 is disposed against the hollow cavity 320 of the liner 314 when the tracer material 622 is placed in association with the perforating device 602. An inner surface of the tracer material 622 may be conical and thus define a conical hollow cavity 624. The tracer material 622 may comprise a hole, bore, or other opening 626 extending axially therethrough.
The tracer material 622 may be shaped by compressing or pressing tracer material particles (e.g., pellets, powder, etc.) within a mold having the intended shape of the tracer material 622. The tracer material 622 may also or instead be shaped by mixing tracer material particles with a fluid binder to form a tracer material slurry, which may be poured into a mold having the intended shape of the tracer material 622 and permitted to solidify. The tracer material 622 may also or instead be shaped by melting solid tracer material (e.g., tracer material particles), pouring the molten tracer material into a mold having the intended shape of the tracer material 622, and cooling molten tracer material within the mold. Each batch (i.e., shaped unit) of the tracer material 622 associated with a corresponding perforating device 602 may comprise between about seven and about 25 grams of fluid tracers, or more. For example, each shaped unit of tracer material 622 may comprise about 7.0, 8.5, 10.0, 11.0, 12.0, 13.0, 13.5, 14.0, 15.0, 17.5, 20.0, 22.5, or 25.0 grams of fluid tracers.
A case 630 (e.g., a cap, a cover, etc.) may contain, hold, accommodate, cover, and/or be disposed around each batch of the tracer material 622. The case 630 may be configured to connect with the case 310 of the perforating device 602, such as to maintain the tracer material 622 positioned in front of the liner 314 and/or such that the hollow cavities 320, 624 are aligned. For example, an outer edge 632 of the case 630 may be configured to extend over and/or around a portion of the case 310 and connect with the case 310. The outer edge 632 may comprise internal threads configured to engage external threads of the case 310. The outer edge 632 may also or instead comprise a flange 634 configured to engage a corresponding flange 636 of the case 310. Fasteners 638, such as bolts, may be used to couple the corresponding flanges 634, 636.
The case 630 may be formed from or comprise a metal, a ceramic, a polymer, and/or other materials. The case 630 may be bowl-shaped, having a convex outer surface and a concave inner surface. The inner surface may define a void or cavity for accommodating the tracer material 622 therein. The case 630 may comprise semi-spherical outer and inner surfaces. The case 630 may comprise an opening 640 extending axially therethrough. The opening 640 may be axially aligned with the axial opening 626 of the tracer material 622. The tracer material 622 may adhere to the case 630, such that the case 630 and the tracer material 622 may be transported and/or connected with the perforating device 602 as a single unit. For example, the tracer material 622 may be formed within the case 630, such as by pouring tracer material particles into the case 630 and compressing the tracer material particles within the case 630 via a press having an outer shape forming the cavity 624. The compression action may cause the tracer material 622 to be retained within the case 630, such as via friction. The inner surface of the case 630 may be coated with an adhesive, which may cause the tracer material 622 to be retained within the case 630 when compressed within the case 630. The tracer material 622 may also or instead be formed within the case 630, such as by pouring molten tracer material or a tracer material slurry into the case 630 and compressing the tracer material within the case 630 via a press having an outer shape forming the cavity 624. However, the case 630 and the tracer material 622 may be or comprise separate members, which may be assembled prior to or during connection with the perforating device 602.
FIGS. 20-29 are schematic sectional views of example implementations of tracer caps 701-710, respectively, that may be utilized in association with a perforating device, such as the perforating device 602 described above and shown in FIG. 19, instead of the tracer cap 604. The tracer caps 701-710 may comprise one or more features and modes of operation of the tracer cap 604. However, the tracer caps 701-710 may also or instead comprise features and modes of operation that are different from those of the tracer cap 604. Furthermore, although each tracer cap 604, 701-710 comprises a specific combination of features, it is to be understood that other tracer caps comprising a different combination of the features shown in FIGS. 19-29 (among other possible features) are also within the scope of the present disclosure. Accordingly, the following description refers to FIGS. 19-29, collectively.
The tracer cap 701 comprises a case 711 and tracer material 712. The case 711 comprises semi-spherical inner and outer surfaces and an axial opening 713 extending between the inner and outer surfaces. The tracer material 712 comprises a conical hollow cavity 714 having a relatively short height 715, which does not extend to the opening 713, and a relatively small diameter (i.e., narrow) base 716 defining an opening of the cavity 714, which does not extend to an outer edge 717 of the case 711. The tracer material 712 may comprise a relatively long bore 718 extending between the cavity 714 and the opening 713.
The tracer cap 702 comprises a case 721 and tracer material 722. The case 721 comprises semi-spherical inner and outer surfaces and an axial opening 723 extending between the inner and outer surfaces. The tracer material 722 comprises a conical hollow cavity 724 having a relatively short height 725, which does not extend to the opening 723, and a relatively large diameter (i.e., wide) base 726 defining an opening of the cavity 724, which extends to an outer edge 727 of the case 721. The tracer material 722 may comprise a relatively long bore 728 extending between the cavity 724 and the opening 723.
The tracer cap 703 comprises a case 731 and tracer material 732. The case 731 comprises semi-spherical inner and outer surfaces and an axial opening 733 extending between the inner and outer surfaces. The tracer material 732 comprises a relatively small semi-spherical hollow cavity 734 having a relatively small diameter 735 defining an opening of the cavity 734. The tracer material 732 comprises a relatively long bore 738 extending between the cavity 734 and the opening 733.
The tracer cap 704 comprises a case 741 and tracer material 742. The case 741 comprises semi-spherical inner and outer surfaces and an axial opening 743 extending between the inner and outer surfaces. The tracer material 742 comprises a relatively large semi-spherical hollow cavity 744 having a relatively large diameter 745 defining an opening of the cavity 744. The tracer material 742 comprises a relatively short bore 748 extending between the cavity 744 and the opening 743.
The tracer cap 705 comprises a case 751 and tracer material 752. The case 751 comprises semi-spherical inner and outer surfaces and an axial opening 753 extending between the inner and outer surfaces. The tracer material 752 does not comprise a hollow cavity. The tracer material 752 comprises a relatively long bore 758 that extends through the entire tracer material 752 and is aligned with the opening 753.
The tracer cap 706 comprises a case 761 and tracer material 762. The case 761 comprises conical inner and outer surfaces and an axial opening 763 extending between the inner and outer surfaces. The tracer material 762 comprises a conical hollow cavity 764 having a relatively short height 765, which does not extend to the opening 763, and a relatively small diameter (i.e., narrow) base 766 defining an opening of the cavity 764, which does not extend to an outer edge 767 of the case 761. The tracer material 762 may comprise a relatively long bore 768 extending between the cavity 764 and the opening 763.
The tracer cap 707 comprises a case 771 and tracer material 772. The case 771 comprises oval (e.g., ellipsoidal) inner and outer surfaces and an axial opening 773 extending between the inner and outer surfaces. The tracer material 772 comprises a conical hollow cavity 774 having a relatively short height 775, which does not extend to the opening 773, and a relatively small diameter (i.e., narrow) base 776 defining an opening of the cavity 774, which does not extend to an outer edge 777 of the case 771. The tracer material 772 may comprise a relatively long bore 778 extending between the cavity 774 and the opening 773.
The tracer cap 708 comprises a case 781 and tracer material 782. The case 781 comprises semi-spherical inner and outer surfaces and does not comprise an axial opening. The tracer material 782 comprises a relatively small semi-spherical hollow cavity 784 having a relatively small diameter 785 defining an opening of the cavity 784. The tracer material 782 does not have a bore extending therethrough.
The tracer cap 709 comprises a case 791 and tracer material 792. The case 791 comprises semi-spherical inner and outer surfaces and does not comprise an axial opening. The tracer material 792 comprises a conical hollow cavity 793 having a relatively large height 794 extending to the case 791, and a relatively large diameter (i.e., wide) base 795 defining an opening of the cavity 793 extending to an outer edge 796 of the case 791. The tracer material 792 does not comprise a bore extending therethrough.
The tracer cap 710 comprises a case 797 and tracer material 798. The case 797 comprises semi-spherical inner and outer surfaces and does not comprise an axial opening. The tracer material 732 does not comprise a hollow cavity nor a bore extending therethrough.
FIG. 30 is a schematic sectional view of an example implementation of a perforating device 790 (e.g., a shaped explosive charge, a perforating charge, etc.) according to one or more aspects of the present disclosure. The perforating device 790 may comprise one or more features and/or modes of operation of the perforating device 602 shown in FIG. 19, including where indicated by the same reference numerals. A plurality of the perforating devices 790 may be installed or otherwise utilized as part of or in association with a perforating tool, such as one or more of the perforating tools 116, 200, 410, 420, 430, 440, 500 described above and shown in FIGS. 1, 2, 4-11, and 18. The following description refers to FIGS. 1, 19, and 30, collectively.
The perforating device 790 may comprise a case 310 (i.e., a housing), a main explosive material 312 disposed within the case 310, and a liner 799 partially surrounded by the main explosive material 312. The liner 799 may have a generally conical shape, having an outer surface in contact with or otherwise surrounded by the main explosive material 312 and an inner surface defining a conical hollow (e.g., air-filled) cavity 320 (i.e., a stand-off space). The cavity 320 may define a front face of the perforating device 790. A primer explosive material 316 may be disposed at the base of the case 310 in contact with the main explosive material 312 and adjacent an opening or hole 318 through the case 310. The primer explosive material 316 may be detonated by a detonating cord 317 or other means.
However, unlike the perforating device 602, the liner 799 of the perforating device 790 may be formed from or otherwise comprise tracer material. The tracer material liner 799 may be or comprise fluid tracers used to identify source of fluid. The tracer material liner 799 may be or comprise radioactive tracers, chemical tracers, and/or DNA tracers, among other examples. The tracer material liner 799 may comprise fluid tracers combined with particles of metal, such as one or more metals used to form the liner 314.
The tracer material liner 799 may be shaped by compressing or pressing (e.g., hydraulically) tracer material particles (e.g., pellets, powder, etc.), metal particles, and/or binder material within a mold having the intended shape of the tracer material liner 799. The tracer material liner 799 may also or instead be shaped by mixing tracer material particles, metal particles, and/or fluid binder material to form a tracer material slurry, which may be poured into a mold having the intended shape of the tracer material liner 799 and permitted to solidify. The tracer material liner 799 may also or instead be shaped by melting mixed solid tracer material (e.g., tracer material particles), metal particles, and/or binder material, pouring the molten mix into a mold having the intended shape of the tracer material liner 799, and cooling the molten mix within the mold.
If the perforating device 790 comprising the tracer material liner 799 is used as part of a perforating gun, a tracer cap (e.g., the tracer cap 604) and/or the tracer material 622 does not have to be disposed in association with the perforating device 790 (e.g., in front of the liner 799). However, if an additional quantity of tracer material is intended to be deployed into the formation 106, additional tracer material 622 may be disposed in association with the perforating device 790 as described herein and shown in FIGS. 19-29.
The present disclosure is further directed to methods of deploying tracer material into a subterranean formation via the perforating tool 500 (i.e., a perforating gun). FIGS. 31-33 are schematic sectional views of a perforating and tracer assembly 600, shown in FIG. 19, of the perforating tool 500, shown in FIG. 18, during different stages of tracer deployment operations according to one or more aspects of the present disclosure. The perforating tool 500 comprises a plurality of the assemblies 600 collectively operable to form a plurality of perforation tunnels 113 and deploy tracer material 622 into the formation 106 via the perforation tunnels 113. The following description refers to FIGS. 1, 18, 19, and 31-33, collectively.
Prior to conveying the perforating tool 500 downhole, the perforating tool 500 may be assembled at the wellsite surface 104. The tracer caps 604 and the perforating devices 602 may be connected together to form the assemblies 600. If the individual batches of the tracer material 622 are separate from the cases 630, the batches of the tracer material 622 may first be inserted into the corresponding cases 630 and then the cases 630 may be connected with the perforating devices 602 to maintain each batch of the tracer material 622 in front of a corresponding liner 314 of the perforating device 602. The assemblies 600 may then be individually installed within the support tube 224 of the perforating tool 500 and connected with the detonating cord 220. However, the perforating devices 602 may instead be individually installed within the support tube 224 first. After the perforating devices 602 are installed, the tracer caps 604, each comprising the tracer material 622 disposed within the case 630, may be connected with the perforating devices 602. The support tube 224 with the assemblies 600 may then be inserted into the outer housing 226. The tracer material 622 associated with one or more of the assemblies 600 within the perforating tool 500 may be different or otherwise distinguishable (i.e., comprising different detectable signatures or characteristics) from the tracer material 622 associated with one or more other assemblies 600 and within the same perforating tool 500. The perforating tool 500, along with one or more other perforating tools 500, may then be coupled within or as part of a tool string 110. The tracer material 622 associated with each perforating tool 500 of the tool string 110 may be different or otherwise distinguishable from the tracer material 622 associated with other perforating tools 500 of the tool string 110. The tool string 110 may then be conveyed within a wellbore 102 until an intended one of the perforating tools 500 is at an intended depth. The perforating devices 602 of one or more intended perforating tools 500 may then be operated (detonated) from the wellsite surface 104 or by the downhole controller to perforate the well 102 and deploy the tracer material 622 into the formation 106.
FIG. 31 shows a stage of tracer material deployment operations, shortly after the main explosive material is detonated 350. A pressure wave generated by the exploding 350 main explosive material folds or otherwise collapses the liner within the hollow cavity 320, as indicated by arrows 358, and simultaneously propels the liner along a central axis of the perforating device 602. The pressure wave breaks up the liner into liner particles 352, forming a high-pressure and high-speed jet of liner particles 352 and gas directed toward a sidewall of the wellbore 102, as indicated by arrow 360. Before impacting the sidewall of the wellbore 102, the jet of liner particles 352 exits the perforating tool 500 comprising the assembly 600 by penetrating an outer housing 226 of the perforating tool 500.
FIG. 32 shows the jet of liner particles 352 perforating the casing 108, the cement 109, and the formation 106, thereby creating a perforation tunnel 113 through the casing 108 and the cement 109 and into the formation 106. The high-pressure and high-speed jet of liner particles 352 and gas caused by the exploding 350 explosive material breaks up the tracer material 622 (and the case 630) into tracer material particles 356 and draws, propels, discharges, or otherwise forces the tracer material particles 356 along and behind the liner particles 352, out of the perforating tool 500, and then toward and into the perforation tunnel 113, as indicated by arrows 362.
As shown in FIG. 33, high-pressure gas within the hollow cavity 320 caused by the exploding 350 explosive material continues to flow out of the hollow cavity 320 and the perforating tool 500 and into the perforation tunnel 113, which is at a substantially lower pressure. The high-pressure and high-speed flow of gas continues to break up the tracer material 622 into tracer material particles 356 and discharges the liner particles 352 into the perforation tunnel 113, as indicated by arrows 364. The tracer material particles 356 may continue to flow into the perforation tunnel 113 until all or substantially all of the tracer material 622 is broken up and discharged from the tracer cap 604, or until the gas pressure within the hollow cavity 320 and/or the outer housing 226 equalizes with pressure within the wellbore 102 and/or the perforation tunnel 113.
A perforating tool, such as one of the perforating tools 116, 200, 500 shown in FIGS. 1, 2, and 18, respectively, comprising a plurality of the perforating devices 790 shown in FIG. 30 may also or instead be utilized to deliver or deploy fluid tracers into the formation 106. Such deployment operations may be similar to those described above and shown in FIGS. 31 and 32. The following description refers to FIGS. 1, 2, 18, and 30-32.
Prior to conveying the perforating tool downhole, the perforating tool may be assembled at the wellsite surface 104. The perforating devices 790, with or without tracer caps 604 shown in FIG. 19, may be individually installed within a support tube 224 of the perforating tool and connected with a detonating cord 220. The support tube 224 with the perforating devices 790 may then be inserted into an outer housing 226. The tracer material of the liner 799 associated with one or more of the perforating devices 790 within the perforating tool may be different or otherwise distinguishable (i.e., comprising different detectable signatures or characteristics) from the tracer material of the liner 799 associated with one or more other perforating devices 790 within the same perforating tool. The perforating tool, along with one or more other perforating tools, may then be coupled within or as part of a tool string 110. The tool string 110 may then be conveyed within a wellbore 102 until the perforating tool is at an intended depth. The perforating devices 790 of one or more intended perforating tools may then be operated (detonated) from the wellsite surface 104 or by the downhole controller to perforate the well 102 and deploy the tracer material into the formation 106.
Although FIGS. 31 and 32 show deployment of the tracer material 622 located within a tracer cap 604, deployment operations of the tracer material located within the liner 799 may be similar to those shown in FIGS. 31 and 32. Assuming that arrangement shown in FIGS. 31 and 32 utilize the perforating device 790 shown in FIG. 30 in place of the perforating device 602, the exploding 350 explosive material folds or otherwise collapses the fluid tracer liner 799 within the hollow cavity 320, as indicated by arrows 358, and simultaneously propels the liner 799 along a central axis of the perforating device 790. The pressure wave breaks up the liner 799 into liner particles 352, forming a high-pressure and high-speed jet of fluid tracer liner particles 352 and gas directed toward a sidewall of the wellbore 102, as indicated by arrow 360. The jet of fluid tracer liner particles 352 then penetrates the casing 108, the cement 109, and the formation 106 to create the perforation tunnel 113. The fluid tracer liner particles 352 continue to penetrate the formation 106, forming the perforation tunnel 113, while the kinetic energy of the fluid tracer liner particles 352 decrease. When the fluid tracer liner particles 352 stop, the fluid tracer liner particles 352 are embedded and thus deployed within the formation 106. If additional tracer material is intended to be deployed, a tracer cap 604 containing tracer material 622 may be disposed in association with the perforating device 790, which may be operated to deploy the tracer material 622 within the formation 106, as described above and shown in FIGS. 31-33.
The present disclosure is further directed to methods of testing or monitoring the formation fluid produced from the formation for the tracer material (i.e., fluid tracers) to identify contributions (e.g., percentages) of the formation fluids produced from each cluster 111 of perforation tunnels 113, each fracturing stage interval 103, 105, 107, and/or from other predetermined portions or intervals of the formation 106. FIG. 34 is a schematic sectional view of a perforating tool 800 (e.g., one of the perforating tools 116, 200, 410, 420, 430, 440, 500) comprising a perforating device 802 (e.g., one of the perforating devices 117, 210, 300, 600, 790) that was conveyed within a wellbore 102 to an intended depth and operated to form a perforation tunnel 113 and deploy tracer material 804 in a formation 106, such as via the actions described above and shown in FIGS. 12-17 and 31-33. The perforation tunnel 113 formed by the perforating device 802 extends through the casing 108 and cement 109 and into the formation 106 within a fracturing stage interval 105. Tracer material particles 804 are deployed within the perforation tunnel 113 and/or within a crushed formation region 806 surrounding the perforation tunnel 113. The perforating device 802 is one of a plurality of perforating devices 802 and, thus, the perforation tunnel 113 is one of a plurality (e.g., a cluster 111) of perforation tunnels 113 that may be formed in the formation 106 within the fracturing stage interval 105 via one or more perforating tools 800 and into which the tracer material 804 may be deployed via the actions described above. As shown in FIG. 1, a plurality of perforation tunnel clusters 111 may be formed in the formation 106 within the fracturing stage interval 105. Tracer material 804 having different or otherwise differentiable signatures (e.g., indicators, characteristics, markers, etc.) may be deployed within each cluster 111 of perforation tunnels 113 within the same fracturing stage interval (e.g., the fracturing stage interval 105). However, tracer material 804 having the same signatures may be deployed within each cluster 111 of perforation tunnels 113 within the same the same fracturing stage interval. Thus, the detectable signature of the tracer material 804 deployed within each perforation tunnel 113 of a cluster 111 may be the same, but different from the detectable signature of tracer material 804 deployed within the perforation tunnels 113 of another cluster 111 within the same or different fracturing stage interval.
FIG. 35 is a schematic sectional view of the formation 106 within the fracturing stage interval 105 containing the perforation tunnel 113 shown in FIG. 34 during subsequent fracturing operations. During fracturing operations, fracturing fluid 814 may be pumped downhole along the wellbore 102, thus forcing the fracturing fluid 814 into the perforation tunnel 113 (and other perforation tunnels 113 of the same cluster and of other clusters 111 within the fracturing stage interval 105) and pushing the tracer material particles 804 along the perforation tunnel 113. While the pressure of the fracturing fluid 814 increases, fractures 808 extending from the perforation tunnel 113 along the formation 106 within the fracturing stage interval 105 are formed. The fracturing fluid 814 further carries suspended tracer material particles 804 into and along the fractures 808, further disseminating or spreading the tracer material particles 804 within the formation 106, as indicated by the arrows 810.
FIG. 36 is a schematic sectional view of the formation 106 containing the perforation tunnel 113 and the fractures 808 shown in FIG. 35 during subsequent flow-back and/or hydrocarbon production operations (collectively “uphole flow operations”). During uphole flow operations, formation fluid 812 (e.g., hydrocarbons) is expelled from the formation 106 within the fracturing stage interval 105 (and perhaps from other fracturing stage intervals 103, 107) and transmitted via the fractures 808 and the perforation tunnel 113 while carrying suspended tracer material particles 804 therewith. The formation fluid 812 with the tracer material particles 804 is then transmitted into the wellbore 102 via the perforation tunnel 113 (and other perforation tunnels 113), as indicated by arrows 816, and to the wellsite surface 104 via the wellbore 102. The formation fluid 812 may be analyzed at the wellsite surface 104 to determine relative concentrations or amounts of each distinguishable tracer material (i.e., tracer material particles 804) reaching the wellsite surface 104 to determine or identify the contribution (e.g., relative amount or percentage) of the formation fluid 812 produced from each cluster 111 of perforation tunnels 113 and/or from each fracturing stage interval 103, 105, 107 with respect to the total formation fluid produced from the wellbore 102.
Differentiable tracer material 804 may be deployed within each cluster 111 of perforation tunnels 113 within the same fracturing stage interval 103, 105, 107. Thus, after a cluster 111 of perforation tunnels 113 are formed within a selected fracturing stage interval (e.g., the fracturing stage interval 105) and distinguishable tracer material particles 804 are deployed therein, the tool string 110 containing the perforating tools 800 may be conveyed uphole (or downhole) to other intended depth(s) within the same fracturing stage interval 105. Perforating devices 802 of one or more other perforating tools 800 may then be operated to form another cluster 111 of perforation tunnels 113 and deploy other distinguishable tracer material particles 804 therein. The tracer material 804 deployed into each cluster 111 of perforation tunnels 113 within the same fracturing stage interval 105 may be distinguishably different, thereby permitting monitoring of fluid flow contribution of each cluster 111 of perforation tunnels 113 (and corresponding fractures 808) and, thus, monitoring of perforation and/or fracturing efficiency of each cluster 111 of perforation tunnels 113 (and corresponding fractures 808) within the same fracturing stage interval 105.
However, the tracer material 804 deployed into each cluster 111 of perforation tunnels 113 within a selected fracturing stage interval (e.g., the fracturing stage interval 105) may be indistinguishable, but distinguishable from tracer material 804 deployed into each cluster 111 of perforation tunnels 113 within another fracturing stage interval (e.g., the fracturing stage intervals 103, 107), thereby permitting monitoring of fluid flow contribution of each fracturing stage interval 103, 105, 107 and thus monitoring of perforation and/or fracturing efficiency of each fracturing stage interval 103, 105, 107, as a whole. Thus, before each stage of fracturing operations, a tool string 110 may be conveyed downhole to isolate a previous fracturing stage interval and to form perforation tunnels 113 within a subsequent fracturing stage interval and deploy the tracer material 804 therein. For each such conveyance and downhole operations, the tool string 110 may include a perforating tool 800 comprising a different distinguishable tracer material 804 for deployment into the perforation tunnels 113.
In view of the entirety of the present disclosure, including the figures and the claims, a person having ordinary skill in the art will readily recognize that the present disclosure introduces an apparatus comprising tracer material shaped to facilitate placement in association with a perforating gun, wherein detonation of shaped charges of the perforating gun forms perforation tunnels in a subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnels.
The tracer material may be shaped to facilitate placement within the perforating gun.
The tracer material may be shaped to facilitate placement between an outer housing of the perforating gun and an inner tube supporting the shaped charges.
The tracer material may be shaped to facilitate placement within a shaped charge support tube of the perforating gun.
The tracer material may be shaped to facilitate placement in association with each of the shaped charges.
The tracer material may be shaped to facilitate placement in front of each of the shaped charges.
The tracer material may be or comprise distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.
The tracer material may be or comprise at least one of radioactive tracers, chemical tracers, and DNA tracers.
The present disclosure also introduces an apparatus comprising a liner for use as part of a shaped charge for a perforating gun, wherein the liner comprises tracer material.
The liner may have a substantially conical shape.
Detonation of the shaped charge may propel the liner to form a perforation tunnel in a subterranean formation thereby deploying the tracer material into the perforation tunnel.
The liner may further comprise a metal.
The liner may comprise a mixture of particles of the tracer material and particles of a metal held together in a predetermined shape.
The tracer material may be or comprise distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.
The tracer material may be or comprise at least one of radioactive tracers, chemical tracers, and DNA tracers.
The present disclosure also introduces an apparatus comprising tracer material shaped to facilitate placement in front of a shaped charge of a perforating gun, wherein detonation of the shaped charge forms a perforation tunnel in a subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnel.
The tracer material may be shaped to comprise a hollow cavity. The hollow cavity of the tracer material may be disposed against a hollow cavity of a liner of the shaped charge when the tracer material is placed in front of the shaped charge. The hollow cavity of the tracer material may have a substantially semi-spherical shape or a substantially conical shape.
The tracer material may be shaped to comprise a hole extending axially therethrough.
The apparatus may further comprise a case disposed around the tracer material. The case may be configured for connection with the shaped charge. The case may have a substantially semi-spherical shape. The case may be or comprise a metal. The tracer material may adhere to the case.
The tracer material may be or comprise distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.
The tracer material may be or comprise at least one of radioactive tracers, chemical tracers, and DNA tracers.
The present disclosure also introduces an apparatus comprising a perforating gun comprising a plurality of shaped charges and containing tracer material, wherein detonation of the shaped charges: forms perforation tunnels in the subterranean formation; and discharges the tracer material from the perforating gun into the perforation tunnels.
The tracer material may be disposed between an outer housing of the perforating gun and an inner tube supporting the shaped charges.
The tracer material may be disposed within a shaped charge support tube of the perforating gun.
The tracer material may be disposed in association with each of the shaped charges. The tracer material may be disposed in front of each of the shaped charges.
The tracer material may be or comprise distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.
The tracer material may be or comprise at least one of radioactive tracers, chemical tracers, and DNA tracers.
The present disclosure also introduces a method comprising deploying tracer material into a subterranean formation via a perforating gun.
Deploying the tracer material into the subterranean formation via the perforating gun may comprise deploying the tracer material into the subterranean formation via shaped charges of the perforating gun.
Deploying the tracer material into the subterranean formation via the perforating gun may comprise detonating shaped charges of the perforating gun to: form perforation tunnels in the subterranean formation; and discharge the tracer material from the perforating gun into the perforation tunnels.
The method may further comprise, before deploying the tracer material into the subterranean formation via the perforating gun, installing the tracer material as part of the perforating gun.
The tracer material may be or comprise distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.
The tracer material may be or comprise at least one of radioactive tracers, chemical tracers, and DNA tracers.
The tracer material may be a first tracer material, the perforating gun may be a first perforating gun, the method may further comprise deploying second tracer material into the subterranean formation via a second perforating gun, the first tracer materials and the second tracer material may be distinguishable, and the first perforating gun and the second perforating gun may be part of the same downhole tool string.
The tracer material may be a first tracer material, the perforating gun may be a first perforating gun, and deploying the first tracer material into the subterranean formation via the first perforating gun may comprise: conveying to a first wellbore depth a tool string comprising the first perforating gun containing the first tracer material; and operating the first perforating gun to detonate first shaped charges of the first perforating gun thereby forming a first set of perforating tunnels in the subterranean formation and forcing the first tracer material into the first set of perforating tunnels. The method may further comprise: conveying to a second wellbore depth the tool string comprising a second perforating gun containing second tracer material; and operating the second perforating gun to detonate second shaped charges of the second perforating gun thereby forming a second set of perforating tunnels in the subterranean formation and forcing the second tracer material into the second set of perforating tunnels, wherein the first tracer material and the second tracer material are distinguishable. The method may further comprise: fracturing the subterranean formation via the first and second sets of perforation tunnels; producing formation fluid from the fractured subterranean formation to the wellsite surface; and analyzing the formation fluid at the wellsite surface to determine relative amounts of the first and second tracer material in the formation fluid to determine relative amount of the formation fluid produced via each of the first and second sets of perforation tunnels.
The foregoing outlines features of several embodiments so that a person having ordinary skill in the art may better understand the aspects of the present disclosure. A person having ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. A person having ordinary skill in the art should also realize that such equivalent constructions do not depart from the scope of the present disclosure, and that they may make various changes, substitutions and alterations herein without departing from the scope of the present disclosure.

Claims

What is claimed is:

1. An apparatus comprising:

tracer material shaped to facilitate placement in association with a perforating gun, wherein detonation of shaped charges of the perforating gun forms perforation tunnels in a subterranean formation and discharges the tracer material from the perforating gun into the perforation tunnels.

2. The apparatus of claim 1 wherein the tracer material is shaped to facilitate placement within the perforating gun.

3. The apparatus of claim 1 wherein the tracer material is shaped to facilitate placement in association with each of the shaped charges.

4. The apparatus of claim 1 wherein the tracer material is shaped to facilitate placement in front of each of the shaped charges.

5. The apparatus of claim 1 wherein the tracer material is or comprises distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.

6. The apparatus of claim 1 wherein the tracer material is or comprises at least one of:

radioactive tracers;

chemical tracers; and

DNA tracers.

7. An apparatus comprising:

a perforating gun comprising a plurality of shaped charges and containing tracer material, wherein detonation of the shaped charges:

forms perforation tunnels in the subterranean formation; and

discharges the tracer material from the perforating gun into the perforation tunnels.

8. The apparatus of claim 7 wherein the tracer material is disposed within an outer housing of the perforating gun.

9. The apparatus of claim 7 wherein the tracer material is disposed in association with each of the shaped charges.

10. The apparatus of claim 7 wherein the tracer material is or comprises distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.

11. The apparatus of claim 7 wherein the tracer material is or comprises at least one of:

radioactive tracers;

chemical tracers; and

DNA tracers.

12. A method comprising:

deploying tracer material into a subterranean formation via a perforating gun.

13. The method of claim 12 wherein deploying the tracer material into the subterranean formation via the perforating gun comprises deploying the tracer material into the subterranean formation via shaped charges of the perforating gun.

14. The method of claim 12 wherein deploying the tracer material into the subterranean formation via the perforating gun comprises detonating shaped charges of the perforating gun to:

form perforation tunnels in the subterranean formation; and

discharge the tracer material from the perforating gun into the perforation tunnels.

15. The method of claim 12 further comprising, before deploying the tracer material into the subterranean formation via the perforating gun, installing the tracer material as part of the perforating gun.

16. The method of claim 12 wherein the tracer material is or comprises distinguishable fluid tracers configured to be carried by formation fluid and used to identify a source of the formation fluid.

17. The method of claim 12 wherein the tracer material is or comprises at least one of:

radioactive tracers;

chemical tracers; and

DNA tracers.

18. The method of claim 12 wherein:

the tracer material is a first tracer material;

the perforating gun is a first perforating gun;

the method further comprises deploying second tracer material into the subterranean formation via a second perforating gun;

the first tracer materials and the second tracer material are distinguishable; and

the first perforating gun and the second perforating gun are part of the same downhole tool string.

19. The method of claim 12 wherein:

the tracer material is a first tracer material;

the perforating gun is a first perforating gun;

deploying the first tracer material into the subterranean formation via the first perforating gun comprises:

conveying to a first wellbore depth a tool string comprising the first perforating gun containing the first tracer material; and

operating the first perforating gun to detonate first shaped charges of the first perforating gun thereby forming a first set of perforating tunnels in the subterranean formation and forcing the first tracer material into the first set of perforating tunnels;

the method further comprises:

conveying to a second wellbore depth the tool string comprising a second perforating gun containing second tracer material; and

operating the second perforating gun to detonate second shaped charges of the second perforating gun thereby forming a second set of perforating tunnels in the subterranean formation and forcing the second tracer material into the second set of perforating tunnels, wherein the first tracer material and the second tracer material are distinguishable.

20. The method of claim 19 further comprising:

fracturing the subterranean formation via the first and second sets of perforation tunnels;

producing formation fluid from the fractured subterranean formation to the wellsite surface; and

analyzing the formation fluid at the wellsite surface to determine relative amounts of the first and second tracer material in the formation fluid to determine relative amount of the formation fluid produced via each of the first and second sets of perforation tunnels.