WO2022026714A1 - Well integrity smart joint - Google Patents
Well integrity smart joint Download PDFInfo
- Publication number
- WO2022026714A1 WO2022026714A1 PCT/US2021/043710 US2021043710W WO2022026714A1 WO 2022026714 A1 WO2022026714 A1 WO 2022026714A1 US 2021043710 W US2021043710 W US 2021043710W WO 2022026714 A1 WO2022026714 A1 WO 2022026714A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- components
- joint
- sensory system
- disposed
- well integrity
- Prior art date
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/02—Couplings; joints
- E21B17/08—Casing joints
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/01—Devices for supporting measuring instruments on drill bits, pipes, rods or wirelines; Protecting measuring instruments in boreholes against heat, shock, pressure or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/005—Monitoring or checking of cementation quality or level
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/06—Measuring temperature or pressure
- E21B47/07—Temperature
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
- E21B47/12—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
- E21B47/14—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
- E21B47/18—Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid, e.g. mud pressure pulse telemetry
Definitions
- An embodiment of a well integrity joint including a body, and at least two components of a sensory system, disposed on the joint such that the at least components of a sensory system are connectible by a straight line that does not intersect the body.
- Figure 1 is a side view of a well integrity joint as disclosed herein;
- Figure 2 is an end view of Figure 1;
- Figure 3 is a view of a wellbore system including the well integrity joint disclosed herein.
- a well integrity joint 10 is illustrated in side view.
- the joint 10 includes a body 12 that is intended to be deployed in a wellbore and cemented in place to become a casing of the wellbore.
- the joint 10 includes at least two components 14 of a sensory system.
- Components 14 may be active or passive components.
- the components may be active or passive acoustic devices and in embodiments include cement bond log components, ultrasonic components, etc.
- the components are disposed about a periphery of the body 12.
- Advantage is achieved by ensuring the components 14 are “line of sight” to one another, or alternatively stated, they are connectible by a straight line 15 that does not intersect the body, the angular displacement between the components 14 must take into account the radius of the body 12. The closer the components 14 are to the body 12, the closer they must be to one another in order to ensure that the “line of sight is maintained. The longer the components 14 are however, measured in a direction radial to a longitudinal axis of the body 12 the further the components 14 may be from one another while still maintaining the line of sight.
- the further (measured radially) that a component is from the body the greater the angularity (azimuthally) between the components can be without the straight line intersecting the body 12.
- employing supports 16 to mount the components 14 even further radially from the body 12 will increase the angle that may be approached without violating the overriding principle that the straight line must not intersect the body 12.
- the increasing distance from the casing facilitates interrogation of a greater volume of the cement in the annulus (sometimes the B annulus).
- the angularity between components that are circumferentially disposed about the body 12 may be from greater than 0 degrees to less than 180 degrees while maintaining the straight line between the two components 14 not intersecting the body 12.
- the greater the radial displacement from body 12 the greater the angle within the range stated. This is a mathematical limit, but practicality may dictate a smaller angle range since actual borehole annulus radial dimension is limited.
- circumferential displacement of components 14 is contemplated but axial displacement as well as a combination of circumferential and axial (e.g. helically arranged, for example) are also contemplated.
- axial displacement as well as a combination of circumferential and axial (e.g. helically arranged, for example) are also contemplated.
- the maintenance of a line of sight between two components that are to be a part of a signal communication whether that be one-way (pitch-catch) or reflective (pulse echo) is important.
- These placements may also be combined among various pairs of components 14.
- more than one type of component may be disposed in a particular location on body 12 or on supports 16 to provide additional confirmation of signal indication of well integrity.
- a transducer that is used for a pitch and catch operation may be disposed upon a certain support 16 and a reflector may also be disposed on that particular support 16.
- the reflector may operate in a pulse echo operation with another transducer on another support while the transducer on the same support communicates with a different transducer on yet another support 16.
- Spectral Radial CBL (cement bond log) sensors 18 may also be employed on the support 16 as well or separately as illustrated in Figure 1. In fact, as many sensors or transceivers as are desired may be disposed at a support providing there is sufficient room to install them.
- supports 16 are also fins of stabilizer subs 20. They need not be a part of the stabilizer subs 20 but as shown the combination of utilities this configuration for efficiency.
- CBL sensors 18 are disposed about the body 12 separately from the supports 16.
- Communicating the information collected in the joint 10 may be by short hop communications, through casing acoustic communication, dedicated signal carriers in the cemented annulus, radio signal communication, etc.
- FIG. 3 a wellbore system 30 employing the well integrity joint (up to many of them) is illustrated.
- the system 30 includes a borehole 32 in a subsurface formation 34.
- a casing 36 is disposed in the borehole 30 and cemented in place with cement 38.
- the casing 36 includes at least one well integrity joint 10 therein.
- Embodiment 1 A well integrity joint including a body, and at least two components of a sensory system, disposed on the joint such that the at least components of a sensory system are connectible by a straight line that does not intersect the body.
- Embodiment 2 The joint as in any prior embodiment further including at least two supports on or as a part of the pipe joint, the at least two supports extending radially outwardly of the body, one of the at least two components of a sensory system being disposed on one of the at least two supports.
- Embodiment 3 The joint as in any prior embodiment wherein the straight line does not intersect any of the at least two supports.
- Embodiment 4 The joint as in any prior embodiment wherein the at least two components of a sensory system are transducers.
- Embodiment 5 The joint as in any prior embodiment wherein the at least two components of a sensory system are a transducer and a reflector.
- Embodiment 6 The joint as in any prior embodiment wherein the at least two components of a sensory system are active acoustic components.
- Embodiment 7 The joint as in any prior embodiment wherein the at least two components of a sensory system are ultrasonic components.
- Embodiment 8 The joint as in any prior embodiment wherein the at least two components of a sensory system are cement bond log components.
- Embodiment 9 The joint as in any prior embodiment wherein the at least two components of a sensory system are passive acoustic components.
- Embodiment 10 The joint as in any prior embodiment wherein the at least two components of a sensory system are arranged about a circumference of the body.
- Embodiment 11 The joint as in any prior embodiment wherein the at least two components of a sensory system are arranged along a length of the body.
- Embodiment 12 The joint as in any prior embodiment wherein the at least two components of a sensory system are arranged angularly relative to one another wherein the angular range is from greater than zero degrees apart to less than 180 degrees apart.
- Embodiment 13 The joint as in any prior embodiment further including a temperature sensor disposed on or as a part of the casing body.
- Embodiment 14 A method for monitoring well cement including propagating a signal between the at least two components of a sensory system as in any prior embodiment.
- Embodiment 15 The method as in any prior embodiment wherein the signal is propagated through cement disposed between the at least two components of a sensory system.
- Embodiment 16 The method as in any prior embodiment wherein the signal is continuous over time.
- Embodiment 17 A method for operating a wellbore system including disposing one or more well integrity j oints as in any prior embodiment in a borehole, and monitoring integrity of the borehole over time using the one or more well integrity joints.
- Embodiment 18 A wellbore system including a borehole in a subsurface formation, and a casing string in the borehole, the casing string including a well integrity joint as in any prior embodiment.
Abstract
Description
Claims
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA3187256A CA3187256A1 (en) | 2020-07-30 | 2021-07-29 | Well integrity smart joint |
GB2302013.4A GB2611998A (en) | 2020-07-30 | 2021-07-29 | Well integrity smart joint |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US202063058912P | 2020-07-30 | 2020-07-30 | |
US63/058,912 | 2020-07-30 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2022026714A1 true WO2022026714A1 (en) | 2022-02-03 |
Family
ID=80002875
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2021/043710 WO2022026714A1 (en) | 2020-07-30 | 2021-07-29 | Well integrity smart joint |
Country Status (4)
Country | Link |
---|---|
US (1) | US20220034172A1 (en) |
CA (1) | CA3187256A1 (en) |
GB (1) | GB2611998A (en) |
WO (1) | WO2022026714A1 (en) |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
KR101728134B1 (en) * | 2016-01-12 | 2017-04-18 | 김진삼 | Groundwater monitoring apparatus |
US20170167246A1 (en) * | 2015-12-14 | 2017-06-15 | Baker Hughes Incorporated | Fluid loss sensor |
US20170199295A1 (en) * | 2014-07-15 | 2017-07-13 | Halliburton Energy Services, Inc. | Acoustic calipering and analysis of annulus materials |
US20180306750A1 (en) * | 2017-04-19 | 2018-10-25 | General Electric Company | Detection system including sensors and method of operating such |
US20180347349A1 (en) * | 2017-05-31 | 2018-12-06 | Saudi Arabian Oil Company | Acoustic coupler for downhole logging while drilling applications |
Family Cites Families (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP4121627A1 (en) * | 2020-06-04 | 2023-01-25 | Halliburton Energy Services Inc. | Stabilizer including modified helical wellbore stabilizing elements |
-
2021
- 2021-07-29 CA CA3187256A patent/CA3187256A1/en active Pending
- 2021-07-29 US US17/388,607 patent/US20220034172A1/en not_active Abandoned
- 2021-07-29 GB GB2302013.4A patent/GB2611998A/en active Pending
- 2021-07-29 WO PCT/US2021/043710 patent/WO2022026714A1/en active Application Filing
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20170199295A1 (en) * | 2014-07-15 | 2017-07-13 | Halliburton Energy Services, Inc. | Acoustic calipering and analysis of annulus materials |
US20170167246A1 (en) * | 2015-12-14 | 2017-06-15 | Baker Hughes Incorporated | Fluid loss sensor |
KR101728134B1 (en) * | 2016-01-12 | 2017-04-18 | 김진삼 | Groundwater monitoring apparatus |
US20180306750A1 (en) * | 2017-04-19 | 2018-10-25 | General Electric Company | Detection system including sensors and method of operating such |
US20180347349A1 (en) * | 2017-05-31 | 2018-12-06 | Saudi Arabian Oil Company | Acoustic coupler for downhole logging while drilling applications |
Also Published As
Publication number | Publication date |
---|---|
CA3187256A1 (en) | 2022-02-03 |
GB2611998A (en) | 2023-04-19 |
GB202302013D0 (en) | 2023-03-29 |
US20220034172A1 (en) | 2022-02-03 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US9074462B2 (en) | Integrated fiber optic monitoring system for a wellsite and method of using same | |
US20090165547A1 (en) | Apparatus and Method for Detecting Fluid Entering a Wellbore | |
EA015016B1 (en) | Method of applying a strain sensor to a cylindrical structure | |
US20070068262A1 (en) | Fiber Optic Differential Pressure Sensor | |
US20060067162A1 (en) | Ultrasonic cement scanner | |
US11591898B2 (en) | Port and snorkel for sensor array | |
US20180328120A1 (en) | Mitigation of cable damage during perforation | |
WO2008137388A1 (en) | Mounting system for a fiber optic cable at a downhole tool | |
EP3280875B1 (en) | Flow monitoring tool | |
CA2584841A1 (en) | Telemetry wave detection apparatus and method | |
US20170107809A1 (en) | Circumferential array borehole evaluation tool | |
US6581454B1 (en) | Apparatus for measurement | |
US10677703B2 (en) | Methods and systems for determining fluid density by distributed acoustic sensing | |
US20220034172A1 (en) | Well integrity smart joint | |
US9016141B2 (en) | Dry pressure compensated sensor | |
WO2013003152A2 (en) | Distributed sensors to measure cement state | |
US11371342B2 (en) | Flow monitoring tool | |
US20200011172A1 (en) | Sensor nipple and port for downhole production tubing | |
US11326440B2 (en) | Instrumented couplings | |
WO2022271507A1 (en) | Along string measurement tool with pressure sensor array | |
CN105298474A (en) | Sound marker |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 21850328 Country of ref document: EP Kind code of ref document: A1 |
|
ENP | Entry into the national phase |
Ref document number: 3187256 Country of ref document: CA |
|
ENP | Entry into the national phase |
Ref document number: 202302013 Country of ref document: GB Kind code of ref document: A Free format text: PCT FILING DATE = 20210729 |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 21850328 Country of ref document: EP Kind code of ref document: A1 |