US20220268150A1

US20220268150A1 - Automated Modular Wellhead Mounted Wireline For Unmanned Extended Real Time Data Monitoring

Info

Publication number: US20220268150A1
Application number: US16/968,958
Authority: US
Inventors: James Robert Longbottom
Original assignee: Halliburton Energy Services Inc
Current assignee: Halliburton Energy Services Inc
Priority date: 2019-11-13
Filing date: 2019-11-13
Publication date: 2022-08-25
Also published as: WO2021096493A1

Abstract

A system for communicating downhole measurements may comprise a remote wireline system connected to a wellhead. The remote wirelines system may further comprise a base support, a spool frame attached to the base support, a spool attached to the spool frame and a conveyance attached to the spool, an acoustic receiver node attached at a second end of the conveyance, a control box attached to the base support and connected to the spool, and a communication device disposed in the control box. A method for communicating downhole measurements may comprise attaching a remote wireline system to a wellhead, lowering the acoustic receiver node through one or more production tubing sections to a heel of a wellbore, communicating with one or more nodes, and transmitting one or more data packets uphole from the one or more nodes to the acoustic receiver node.

Description

BACKGROUND

Boreholes drilled into subterranean formations may enable recovery of desirable fluids (e.g., hydrocarbons) using a number of different techniques. Currently after the conclusion of drilling operations, production operations may begin. Generally, production operations may include fracturing the subterranean formation. When fracturing the subterranean formation, it may be beneficial to measure the characteristics, properties, and/or movement of fracturing fluid between production tubing and the subterranean formation. Currently, to measure downhole data may take a wireline operation that includes the use of personnel and semi-permanent structures and support that may need to be setup for obtaining measurements for downhole operations. This may increase cost, slow production operations, and increase the number of personnel at a well site.

BRIEF DESCRIPTION OF THE DRAWINGS

These drawings illustrate certain aspects of some examples of the present disclosure and should not be used to limit or define the disclosure.

FIG. 1 illustrates an example of a remote wireline system disposed on a wellhead;

FIG. 2 illustrates an example of the remote wireline system;

FIG. 3 illustrates an example of an acoustic receiver node communicating with one or more nodes in a production tubing; and

FIG. 4 illustrates another example of the acoustic receiver node connected to the production tubing.

DETAILED DESCRIPTION

Provided are systems and methods for taking downhole measurement during production operations. Specifically, communicating measurements uphole to a permanent or temporary remote wireline system that may transmit the measurements to an offsite location. For example, during production operations for fracturing a subterranean formation, measurements of fracturing fluids may be taken to determine fracture efficiency. Wireless nodes in production tubing may measure the data at each fracture cluster, store the data on the node and relay the data from node to node to an acoustic receiver node at the heel of a wellbore. The acoustic receiver node may pick up the data and relays from the other nodes and transmit the information to the surface for analysis.
Additionally, the remote wireline system may be a modular automated wireline unit that is adapted to the wellhead, so the acoustic receiver node is deployed automatically on a predetermined schedule or it is anchored in place to retrieve data from the nodes. The acoustic receiver node may be retracted and out of flow while not in use and be isolated above a barrier, temporarily suspended in the well, or anchored near the top node to talk to downhole tools in the horizontal section.
FIG. 1 illustrates an example of wellhead system 100 capping a wellbore 102, where wellhead system 100 is disposed at a surface 104. In examples, wellhead system 100 may include a wellhead 106, a stuffing box 108, one or more valves 110, and a remote wireline system 112. In examples, wellhead 106 may control the outflow of desirable fluids from wellbore 102 and may also control in the input of tools, fluids, implements, and/or the like to into wellbore 102 for production operations, measurement operations, stimulation operations, and/or the like. For example, FIG. 1 illustrates a remote measurement operation which may utilize remote wireline system 112.
During measurement operations, remote wireline system 112 may operate to move a conveyance 114 up and down production tubing 116 disposed in wellbore 102. Stuffing box 108 may be provided at the top of wellhead 106 in order to seal the interior of production tubing 116 and prevent foreign matter from entering. Stuffing box 108 may be a packing gland or chamber to hold packing material (not shown) compressed around conveyance 114 to prevent the escape of gas and/or liquid.
Conveyance 114 may include, but not limited to, wireline, slickline, pipe, drill pipe, downhole tractor, or the like. In some examples, the conveyance may provide mechanical suspension, as well as electrical connectivity, for an acoustic receiver node, discussed further below. Conveyance 114 may comprise, in some instances, a plurality of electrical conductors extending from surface 104. Additionally, conveyance 114 may comprise an inner core of one to seven electrical conductors covered by an insulating wrap. An inner and outer steel armor sheath may be wrapped in a helix in opposite directions around the conductors. The electrical conductors may be used for communicating power and telemetry to and from surface 104. In examples, conveyance 114 may be a fiber optic cable deployed independently or in a distributed acoustic system. Information from the acoustic receiver node may be gathered and/or processed at a surface 104, discussed below. Conveyance 114 may be a part of remote wireline system 112.
FIG. 2 illustrates an example of remote wireline system 112. Remote wireline system 112 may include a spool 118 in which conveyance 114 may be wound around. Additionally, spool 118 may be supported by structural support 120. Structural support 120 may connect spool 118 to wellhead 106 as illustrated in FIG. 1. In examples, structural support 120 may not be connected to wellhead 106 and may be connected to surface 104, providing a base for spool 118 to operate. Without limitation, structural support 120 may include a base support 200. Base support 200 may connect to wellhead 106 or surface 104 through connection devices 201. Without limitation, connection devices 201 may be latches, quick connects, a cutout for nuts and bolts, pegs, and/or the like. Connection devices 201 may support the weight of remote wirelines system 112 when attached to wellhead 106 or surface 104 through base support 200.
Base support 200 may include one or more frames or may be a sheet of metal. Base support 200 may form a foundation for which spool frame 202 may attach. Without limitation, spool frame 202, as illustrated in FIG. 2, may include bars or sheets of metal. Spool frame 202 may function and operate to support spool 118. Additionally, it may allow spool 118 to rotate during operations. A lock bar 204 may span between spool frame 202. Lock bar 204 may operate and function to prevent the movement of spool 118. In examples, lock bar 204 may be controlled by control box 206. Control box 206 may connect to base support 200 and/or spool frame 202. Without limitation, control box 206 may house motors, gears, power supplies, an information handling system 124, discussed below, and/or the like. This may allow control box 206 to rotate spool 118 clockwise or counterclockwise and operate lock bar 204, which may prevent rotation of spool 118.
Mechanisms within control box 206 may be powered by onsite power source or transit power source that may be brought to remote wireline system 112, further discussed below. Control box 206 includes one or more connection ports 208, which may allow power to enter control box 206 and power the mechanisms within. Connection ports 208 may allow for the connection of electrical power or hydraulic power.
Additionally, remote wireline system 112 may include a communication device 122, that may be wireless, as illustrated in FIG. 1, or a wired connection. In examples, communication device 122 may be disposed on control box 206 or within control box 206. Communication device 122 may also be powered by onsite power source or transit power source that may be brought to remote wireline system 112. In examples, communication device 122 may connect to a remote 210 either wirelessly or through wired communication. Remote 210 may operate remote wireline system 112, specifically sending commands to rotate spool 118 either clockwise or counterclockwise, which may raise and/or lower conveyance 114. Additionally, remote 210 may include a counter 212, which may indicate the length of conveyance 114 that may be released from spool 118 during operations. Conveyance 114 may release from spool 118 through one or more guides 214, which may operate and function to prevent entanglement of conveyance 114. Referring back to FIG. 1, one or more counter wheels 216 may be used to determine the length of conveyance 114 that may be release from spool 118. The measurement of length may be communicated from counter wheels 216 to control box 206. Communication device 122 may communicate the length to remote 210, which may display the length on counter 212.
During operations communication device 122 may transmit measurements from control box 206 to an offsite information handling system 124 either wirelessly or through wired communication. Without limitation, information handling system 124 may be disposed at an offsite location or in a vehicle or skid, not illustrated.
Information handling system 124 may include any instrumentality or aggregate of instrumentalities operable to compute, estimate, classify, process, transmit, receive, retrieve, originate, switch, store, display, manifest, detect, record, reproduce, handle, or utilize any form of information, intelligence, or data for business, scientific, control, or other purposes. For example, an information handling system 124 may be a personal computer, a network storage device, or any other suitable device and may vary in size, shape, performance, functionality, and price. Information handling system 124 may include random access memory (RAM), one or more processing resources such as a central processing unit 126 (CPU) or hardware or software control logic, ROM, and/or other types of nonvolatile memory. Additional components of the information handling system 124 may include one or more disk drives 128, output devices 130, such as a video display, and one or more network ports for communication with external devices as well as an input device 132 (e.g., keyboard, mouse, etc.). Information handling system 124 may also include one or more buses operable to transmit communications between the various hardware components.
Alternatively, systems and methods of the present disclosure may be implemented, at least in part, with non-transitory computer-readable media. Non-transitory computer-readable media may include any instrumentality or aggregation of instrumentalities that may retain data and/or instructions for a period of time. Non-transitory computer-readable media may include, for example, storage media such as a direct access storage device (e.g., a hard disk drive or floppy disk drive), a sequential access storage device (e.g., a tape disk drive), compact disk, CD-ROM, DVD, RAM, ROM, electrically erasable programmable read-only memory (EEPROM), and/or flash memory; as well as communications media such wires, optical fibers, microwaves, radio waves, and other electromagnetic and/or optical carriers; and/or any combination of the foregoing.
During operations, remote wireline system 112 may be controlled by information handling system 124. For example, personnel may activate remote wireline system 112 from an offsite location by information handling system 124. Remote wireline system 112 may function to transmit measurements from wellbore 102 to information handling system 124. As illustrated in FIG. 1, measurements may be taken by production operation by measuring the flow of desirable fluids from perforations 134 through casing 136 to production tubing 116.
FIG. 3 illustrates a cutaway of example production tubing 116 to show nodes 300 which may be utilized to take different measurement for operations within wellbore 102. In examples, nodes 300 may operate by any number of communication modes to move data, which may also be referred to as data packets, from wellbore 102 to surface 104. In examples, each node 300 may be disposed at and/or near perforation 134. This may allow each node 300 to measure fluid flow into production tubing 116. Measurements taken by each node 300 may be simultaneously conveyed uphole as uplink data to acoustic receiver node 302. As discussed above, acoustic receiver node 302 may be lowered into production tubing 116 using remote wireline system 112 (e.g., referring to FIG. 1). Additionally, acoustic receiver node 302 may transmit downlink data to nodes 300 to request measurement data and/or change modes on nodes 300. Without limitation, nodes 300 may include transducers, receivers, transmitters and/or the like to communication between nodes 300 and acoustic receiver node 302. Without limitation, transducers, receivers, transmitters and/or the like may be embedded into node 300 at various location within node 300. Additionally, nodes 300 may be tubular in nature and/or a ring as illustrated in FIG. 3. In other examples, as illustrated in FIG. 4, nodes 300 may be an elongated device attached to the exterior surface of casing 136 using one or more attachment devices 400, such as bands and/or clamps. This may allow each node 300 to connect to the outside of casing 136.
Referring again to FIG. 3, nodes 300 may be attached to casing 136 in close proximity to perforations 134. One or more packers 140 may block an internal diameter of casing 136, which may force fluids to flow up an internal diameter of production tubing 116 within the end of tubing 138 placed above the uppermost perforation 142. Nodes 300 may operate by sending uplink data and receiving downlink data on any carrier frequency. In examples, individual nodes 300 may be operating simultaneously on different carrier frequencies to reduce interference and/or receiver saturation. Additionally, acoustic channel(s) may support unidirectional transmission paths to reduce interference and/or receiver saturation. Further, the position of transducers (transmitters/receivers) may be selected to reduce interference and/or receiver saturation. For example, a receiver and a transmitter may be on opposite sides of node 300 (e.g., a 180° offset). In examples, transducers may be positioned on different sides of node 300 (e.g., a 90° offset or some other offset), but not on opposite sides. Furthermore, nodes 300 may provide different types of acoustic waves, namely shear waves and compressional waves in a different communication mode.
In examples, nodes 300 may include controllers, not illustrated, which may provide power, data storage/buffering, and mode control for the respective node 300. During operations, nodes 300 may operate, for example, for six months to one year with supplied power from the controllers or a separate power source. During this time, nodes 300 may actively take measurements and send them uphole using remote wireline system 112 (e.g., referring to FIG. 1). For example, nodes 300 may collect point data regarding the movement of the fracturing fluid into formation 304 through perforations 134. Data may also include where production is originating. For example, production data which may be found in the first week and up to nine months of production operations. Data collected by nodes 300 may be transmitted to surface from heel 306 of wellbore 102. Heel 306 may be defined as the area at which wellbore 102 transfers from vertical to horizontal. As illustrated in FIG. 3, conveyance 114 may be lowered into wellbore 102 to heel 306, within production tubing 116, by remote wireline system 112. In examples, conveyance 114 may be a digital acoustic sensing fiber optic cable. While FIGS. 1 and 2 illustrates remote wireline system 112 that may be semi-permanent and operating to move conveyance 114 up and down production tubing 116, conveyance 114 may be removable, semi-permanent, or permanently installed.
As discussed above, remote wireline system 112 may be a temporary installation on wellhead 106. In examples, remote wireline system 112 may be powered by local power source at wellhead 106. However, remote wireline system 112 may not have a power source but may be powered by personnel during measurement operations. For example, remote wireline system 112 may have quick disconnects, e.g. connection ports 208, for power, hydraulic fluid, and/or the like that may be necessary to operate remote wireline system 112. During an operation, a vehicle or skid (not illustrated) may attached to remote wireline system 112 through one or more quick connects to power, operate, or send and receive data from nodes 300. Without limitation, an information handling system 124 may be disposed within the vehicle or skid and connected to acoustic receiver node 302 through the quick connects and conveyance 114. This may allow for the operator to collect data from the one or more nodes 300. Without limitation, information handling system may connect to remote wireline system 112 wirelessly through communication device 122 and not through a quick connect.
In examples, remote wireline system 112 may be connected to on site power source at wellhead 106. This may allow remote wireline system 112 to be operated remotely. For example, remote wireline system 112 may communicate with an offsite information handling system 124 that may be at an offsite facility, a vehicle, or a skid. Additionally, in a producing oil field, there may be any number of remote wireline systems 112 that may be controlled remotely with an offsite information handling system 124.
Accordingly, the systems and methods disclosed herein may be directed to a method for receiving measurement data from a remote wireline system. The systems and methods may include any of the various features of the systems and methods disclosed herein, including one or more of the following statements.
Statement 1. A system for communicating downhole measurements may comprise a remote wireline system. The remote wireline system may further comprise a base support, a spool frame attached to the base support, a spool attached to the spool frame and a conveyance attached to the spool at a first end and wound around the spool, an acoustic receiver node attached at a second end of the conveyance opposite the first end of the conveyance, a control box attached to the base support and connected to the spool, and a communication device disposed in the control box. The system may further comprise a wellhead, wherein the conveyance is configured to lower the acoustic receiver node into one or more production tubing sections through the wellhead.
Statement 2. The system of statement 1, further comprising one or more nodes disposed on the casing.
Statement 3. The system of statement 2, wherein the one or more nodes are configured to communicate with each other and the acoustic receiver node.
Statement 4. The system of statement 3, wherein the one or more nodes are configured to measure fluid flow within the one or more production tubing sections.
Statement 5. The system of statements 1 or 2, wherein the acoustic receiver node is communicatively coupled to the communication device.
Statement 6. The system of statement 5, wherein the communication device is configured to communicate with an offsite location.
Statement 7. The system of statements 1, 2, or 5, wherein the base support is configured to connect the remote wireline system to the wellhead through one or more connection devices.
Statement 8. The system of statements 1, 2, 5, or 7 wherein the base support is configured to connect the remote wireline system to a surface through one or more connection devices.
Statement 9. The system of statements 1, 2, 5, 7, or 8 further comprising one or more quick connects that are configured to connect the remote wireline system to a power source, hydraulic fluid, or a data connection through one or more connection ports disposed on the control box.
Statement 10. The system of statement 9, wherein the power source, the hydraulic fluid, or the data connection is disposed on a vehicle or a skid.
Statement 11. A method for communicating downhole measurements may comprise attaching a remote wireline system to a wellhead. The remote wireline system may comprise a base support that is configured to connect the remote wireline system to the wellhead, a spool frame attached to the base support and a spool attached to the spool frame and a power source, wherein the power source is configured to power the spool, a conveyance attached to the spool at a first end and wound around the spool, an acoustic receiver node attached at a second end of the conveyance opposite the first end of the conveyance, a control box attached to the base support and connected to the spool, and a communication device disposed in the control box. The method may further comprise lowering the acoustic receiver node through one or more production tubing sections to a heel of a wellbore, communicating with one or more nodes disposed in the one or more production tubing section with the acoustic receiver node, and transmitting one or more data packets uphole from the one or more nodes to the acoustic receiver node.
Statement 12. The method of statement 11, further comprising measuring fluid flow within the one or more production tubing sections to form the data packets.
Statement 13. The method of statements 11 or 12, further comprising transmitting the data packets to an offsite location.
Statement 14. The method of statements 11-13, wherein the remote wireline system further comprises one or more quick connects.
Statement 15. The method of statement 14, further comprising connecting the remote wireline system to the power source, hydraulic fluid, or a data connection through the one or more quick connects through one or more connection ports disposed on the control box.
Statement 16. The method of statement 15, wherein the power source, the hydraulic fluid, or the data connection is disposed on a vehicle or skid.
Statement 17. The method of statements 11-14, further comprising activating the remote wireline system wireless with a remote that is wirelessly communicating with the communication device.
Statement 18. The method of statement 17, further comprising locking the remote wireline system wireless with the remote, wherein the remote activates a lock bar connected to the spool frame and the spool
Statement 19. The method of statements 11-14 and 17, further comprising removing the remote wireline system from the wellhead.
Statement 20. The method of statements 11-14, 17, and 19, wherein the conveyance comprises a fiber optic cable.
The preceding description provides various examples of the systems and methods of use disclosed herein which may contain different method steps and alternative combinations of components. It should be understood that, although individual examples may be discussed herein, the present disclosure covers all combinations of the disclosed examples, including, without limitation, the different component combinations, method step combinations, and properties of the system. It should be understood that the compositions and methods are described in terms of “comprising,” “containing,” or “including” various components or steps, the compositions and methods can also “consist essentially of” or “consist of” the various components and steps. Moreover, the indefinite articles “a” or “an,” as used in the claims, are defined herein to mean one or more than one of the element that it introduces.
For the sake of brevity, only certain ranges are explicitly disclosed herein. However, ranges from any lower limit may be combined with any upper limit to recite a range not explicitly recited, as well as, ranges from any lower limit may be combined with any other lower limit to recite a range not explicitly recited, in the same way, ranges from any upper limit may be combined with any other upper limit to recite a range not explicitly recited. Additionally, whenever a numerical range with a lower limit and an upper limit is disclosed, any number and any included range falling within the range are specifically disclosed. In particular, every range of values (of the form, “from about a to about b,” or, equivalently, “from approximately a to b,” or, equivalently, “from approximately a-b”) disclosed herein is to be understood to set forth every number and range encompassed within the broader range of values even if not explicitly recited. Thus, every point or individual value may serve as its own lower or upper limit combined with any other point or individual value or any other lower or upper limit, to recite a range not explicitly recited.
Therefore, the present examples are well adapted to attain the ends and advantages mentioned as well as those that are inherent therein. The particular examples disclosed above are illustrative only and may be modified and practiced in different but equivalent manners apparent to those skilled in the art having the benefit of the teachings herein. Although individual examples are discussed, the disclosure covers all combinations of all of the examples. Furthermore, no limitations are intended to the details of construction or design herein shown, other than as described in the claims below. Also, the terms in the claims have their plain, ordinary meaning unless otherwise explicitly and clearly defined by the patentee. It is therefore evident that the particular illustrative examples disclosed above may be altered or modified and all such variations are considered within the scope and spirit of those examples. If there is any conflict in the usages of a word or term in this specification and one or more patent(s) or other documents that may be incorporated herein by reference, the definitions that are consistent with this specification should be adopted.

Claims

What is claimed is:

1. A system for communicating downhole measurements comprising:

a remote wireline system comprising:

a base support;

a spool frame attached to the base support;

a spool attached to the spool frame and a conveyance attached to the spool at a first end and wound around the spool;

an acoustic receiver node attached at a second end of the conveyance opposite the first end of the conveyance;

a control box attached to the base support and connected to the spool; and

a communication device disposed in the control box; and

a wellhead, wherein the conveyance is configured to lower the acoustic receiver node into one or more production tubing sections through the wellhead.

2. The system of claim 1, further comprising one or more nodes disposed on the casing.

3. The system of claim 2, wherein the one or more nodes are configured to communicate with each other and the acoustic receiver node.

4. The system of claim 3, wherein the one or more nodes are configured to measure fluid flow within the one or more production tubing sections.

5. The system of claim 1, wherein the acoustic receiver node is communicatively coupled to the communication device.

6. The system of claim 5, wherein the communication device is configured to communicate with an offsite location.

7. The system of claim 1, wherein the base support is configured to connect the remote wireline system to the wellhead through one or more connection devices.

8. The system of claim 1, wherein the base support is configured to connect the remote wireline system to a surface through one or more connection devices.

9. The system of claim 1, further comprising one or more quick connects that are configured to connect the remote wireline system to a power source, hydraulic fluid, or a data connection through one or more connection ports disposed on the control box.

10. The system of claim 9, wherein the power source, the hydraulic fluid, or the data connection is disposed on a vehicle or a skid.

11. A method for communicating downhole measurements comprising:

attaching a remote wireline system to a wellhead, wherein the remote wireline system comprises:

a base support that is configured to connect the remote wireline system to the wellhead;

a spool frame attached to the base support and a spool attached to the spool frame and a power source, wherein the power source is configured to power the spool;

a conveyance attached to the spool at a first end and wound around the spool;

a control box attached to the base support and connected to the spool; and

a communication device disposed in the control box; and

lowering the acoustic receiver node through one or more production tubing sections to a heel of a wellbore;

communicating with one or more nodes disposed in the one or more production tubing section with the acoustic receiver node; and

transmitting one or more data packets uphole from the one or more nodes to the acoustic receiver node.

12. The method of claim 11, further comprising measuring fluid flow within the one or more production tubing sections to form the data packets.

13. The method of claim 11, further comprising transmitting the data packets to an offsite location.

14. The method of claim 11, wherein the remote wireline system further comprises one or more quick connects.

15. The method of claim 14, further comprising connecting the remote wireline system to the power source, hydraulic fluid, or a data connection through the one or more quick connects through one or more connection ports disposed on the control box.

16. The method of claim 15, wherein the power source, the hydraulic fluid, or the data connection is disposed on a vehicle or skid.

17. The method of claim 11, further comprising activating the remote wireline system wireless with a remote that is wirelessly communicating with the communication device.

18. The method of claim 17, further comprising locking the remote wireline system wireless with the remote, wherein the remote activates a lock bar connected to the spool frame and the spool.

19. The method of claim 11, further comprising removing the remote wireline system from the wellhead.

20. The method of claim 11, wherein the conveyance comprises a fiber optic cable.