US20200063547A1

US20200063547A1 - Sensor configuration

Info

Publication number: US20200063547A1
Application number: US16/488,833
Authority: US
Inventors: Shailesh Shashank Dighe; Douglas Patterson; Thorsten Regener
Original assignee: Baker Hughes Inc
Current assignee: Baker Hughes Holdings LLC
Priority date: 2017-03-17
Filing date: 2017-03-17
Publication date: 2020-02-27
Also published as: AR111289A1; WO2018169542A1; MX2019011051A; AU2017404493A1; BR112019019176A2; EP3596307A4; CA3056749A1; CN110431284A; EP3596307A1

Abstract

A sensor configuration including a centralizer having a rib, a hollow defined within the rib, and a sensor positioned within the hollow. A borehole system including a borehole, a tubular string disposed within the borehole, a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string, a sensor within the hollow. A method for acquiring data in a borehole including running a sensor configuration as in any prior embodiment on a tubular string into a borehole, cementing the tubular string in the borehole, and sensing with the sensor configuration, a parameter in the borehole.

Description

BACKGROUND

In the resource exploration and recovery industry, information about conditions in the downhole environment is often helpful. One particular example of information is to know what the condition of the cement integrity is. are means to determine such information available in the art, that include running a wireline into a borehole after a cementing job is completed and sensing parameters related to the integrity of that cement. The results of the method are generally good but this method does require an additional wireline run. Rig time is ever-increasingly expensive and at the time of writing of this disclosure is running upwards of a million dollars a day. While it is possible to forego the information, it is preferable to have more rather than less information about the downhole conditions in order to avoid downtime, inefficiencies, etc. Accordingly the art would welcome alternative configurations that provide information about the downhole environment but also reduce rig time.

SUMMARY

BRIEF DESCRIPTION OF THE DRAWINGS

The following descriptions should not be considered limiting in any way. With reference to the accompanying drawings, like elements are numbered alike:

FIG. 1 is a schematic illustration of a borehole with a tubular member therein and a solid body centralizer as described herein;

FIG. 2 is a cross sectional view of the centralizer illustrated in FIG. 1; and

FIG. 3 is an illustration similar to FIG. 1 but including another string in the borehole.

DETAILED DESCRIPTION

A detailed description of one or more embodiments of the disclosed apparatus and method are presented herein by way of exemplification and not limitation with reference to the Figures.
Referring to FIG. 1, a sensor configuration 10 is illustrated in situ. The Figure includes borehole 12 within which is also disposed a tubular string 14, the sensor configuration being disposed about the string. The sensor configuration 10 comprises a centralizer 16 with a sensor 18 (while the term sensor may mean just a sensor itself, it is broadly intended herein to also include associated electronics and/or a power source) disposed therein (one or more sensors in one or more centralizer ribs) as discussed in more detail below. Centralizers 16 are commonly employed to maintain a tubular string at or near a center axis of a borehole 12 in which the tubular string 14 is disposed. Centralizer types known in the art include solid body centralizers (having an inside diameter surface that will fit over a tubular and a body of material that includes ribs, the material being essentially a solid mass or foamed mass or machined on a tubular like a stabilizer on a bottom hole assembly). Centralizers may be constructed of most materials having sufficient crush resistance to function as a centralizer in a downhole environment. Determination of suitability of a particular material for the task at hand is well within the level of skill of one of ordinary skill in the art. Metal material and polymeric material are two examples of materials employable.
Referring to FIG. 2, a cross section view of a sensor configuration 10 as disclosed herein is illustrated. The sensor configuration 10, as noted above, comprises a centralizer 16 and a sensor 18 disposed therein. The centralizer 16 is of a solid body type if viewed from an exterior thereof, with ribs 20 (helical or axially straight or of any other configuration) extending radially outwardly of a body 22. One or more of the ribs 20 defines a hollow 24 therein sufficient in size to accommodate the sensor 18 (and/or electronics, and/or power source). It should be appreciated that particular dimensions of the hollow 24 may be different in various iterations of the sensor configuration depending upon the particular size and type of sensor selected for use. One particular sensor contemplated for use in this configuration is a piezoelectric transducer utilized in a commercial tool known as a segmented bond tool (SBT) available from Baker Hughes Incorporated Houston Tex. from the SBT is positioned within the hollow 24. The sensor 18 may be configured to operate on battery power (disposed in the hollow with the sensor), inductive power from another tool run in the well later, power generated downhole, etc. electronics required to control the sensor and the power supply (both collectively under the penumbra of numeral 18) may be located in the hollow 24 as well.
The sensor configuration 10 is to be disposed on the tubular 14 in the same manner as prior art solid body centralizers are used specifically, the centralizer 16 is disposed on the tubular 14 and secured in place. In an alternate embodiment, the centralizer 16 may be located in between two segments of tubular 14 similar to a stabilizer in a drill string. Securement may be by welding, threading, or any other securement method know to the art for securement of centralizers or stabilizers. Important to note is that the centralizer presents no impediment to the inside diameter flow area of the tubular 14. Rib 20 containing sensor 18 is located in the annular space outside of the tubular 14. Sensors for cement integrity checks of the past were run in the ID of the tubing string 14, thereby necessarily being an impediment to flow but also requiring the separate run of wireline that the disclosure herein avoids. The sensors 18, being contained with the hollow 24 and in some embodiments being sealed within the hollow 24, also have no impact on flow area within the tubular 14. Of the possible types of sensors that may be employed in the hollow(s) 24, some include cement integrity sensors, pressure sensors, temperature sensors, etc. or combinations including at least one of the foregoing. Also, since generally more than one rib will be a part of a centralizer, it is contemplated to dispose one or more different sensors in different ribs. Stated alternately, in an embodiment where there are four ribs and wherein each of those four ribs is possessed of a hollow, there could be four sensors of the same type, three of the same and one different, a different sensor in each rib, some ribs without sensors, etc. It is also contemplated to but more than one type of sensor in a single hollow in iterations hereof.
In connection with embodiments that include a cement integrity sensor, in addition to the SBT sensor noted above, other sensors such as Electromagnetic Acoustic Transducers (EMATs), wedge transducers, pulse-echo transducers, pitch-catch configuration or combinations including at least one of the foregoing are contemplated. It is to be appreciated that the location of the cement integrity sensor in the ribs 20 is advantageous in itself for SBT type sensors. Specifically, the sensors being positioned outside of the tubular 14 brings them closer to the cement that the sensor is to examine and avoids the need for a sensory signal to pass through the tubular string 14 itself as would be the case in prior art systems.
Regardless of type of sensor used, the sensor configuration is a permanent part of the tubular string 14 and hence allows for sensory readings over time with related storage of that sensory information to the extent of an on board memory in the sensor 18. The information stored can be sent to surface via a communications conduit put in place with the tubular string 14, or can be downloaded to an after run tool 26 such as a drilling assembly, a completion string, etc., that includes an interrogator 28 (see FIG. 3). And while one of the benefits of the sensor configuration hereof is to avoid the need for a dedicated run to obtain sensory information such as with a wireline run of a sensor, it is possible to run a dedicated interrogation tool to receive the data stored in the sensor 18.
The embodiments contemplated herein may be manufactured by traditional manufacturing methods or by additive manufacturing methods.
A method for acquiring data from a borehole is also contemplated including disposing a centralizer defining a hollow in a rib and a sensor in the hollow in a tubing string; collecting data with the sensor. The data may be collected over time since the sensor is permanently mounted on the tubular string in the borehole. The sensor may communicate the data or store the data for future delivery to an interrogator. The interrogator may be run on a tool having a primary function other than as an interrogator such as a drilling assembly, a completion string, wireline, slick-line, etc. The data may be of any kind, including data for the parameters set forth hereinabove.
Set forth below are some embodiments of the foregoing disclosure:

Embodiment 1

A sensor configuration including a centralizer having a rib, a hollow defined within the rib, and a sensor positioned within the hollow.

Embodiment 2

The sensor configuration as in any prior embodiment wherein the centralizer is a solid body centralizer.

Embodiment 3

The sensor configuration as in any prior embodiment wherein the sensor is entirely contained within the hollow.

Embodiment 4

The sensor configuration as in any prior embodiment wherein the sensor is sealed within the hollow.

Embodiment 5

The sensor configuration as in any prior embodiment wherein the sensor is a cement integrity sensor.

Embodiment 6

The sensor configuration as in any prior embodiment wherein the sensor is a temperature sensor.

Embodiment 7

The sensor configuration as in any prior embodiment wherein the sensor is a pressure sensor.

Embodiment 8

The sensor configuration as in any prior embodiment wherein the rib is more than one rib, at least more than one of the more than one ribs containing sensors.

Embodiment 9

The sensor configuration as in any prior embodiment wherein the sensors are selected from the same type of sensor or different sensors for the more than one of the more than one rib.

Embodiment 10

The sensor configuration as in any prior embodiment wherein the centralizer comprises a metallic material.

Embodiment 11

The sensor configuration as in any prior embodiment wherein the centralizer comprises a polymeric material.

Embodiment 12

A borehole system including a borehole, a tubular string disposed within the borehole, a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string, a sensor within the hollow.

Embodiment 13

A method for acquiring data in a borehole including running a sensor configuration as in any prior embodiment on a tubular string into a borehole, cementing the tubular string in the borehole, and sensing with the sensor configuration, a parameter in the borehole.

Embodiment 14

The method as in any prior embodiment wherein the sensing is over time.

Embodiment 15

The method as in any prior embodiment further including running another tool whose primary function is not sensor interrogation with an interrogator thereon.

Embodiment 16

The method as in any prior embodiment wherein the tool is a drilling assembly.

Embodiment 17

The method as in any prior embodiment wherein the tool is a completion string.
The use of the terms “a” and “an” and “the” and similar referents in the context of describing the invention (especially in the context of the following claims) are to be construed to cover both the singular and the plural, unless otherwise indicated herein or clearly contradicted by context. Further, it should further be noted that the terms “first,” “second,” and the like herein do not denote any order, quantity, or importance, but rather are used to distinguish one element from another. The modifier “about” used in connection with a quantity is inclusive of the stated value and has the meaning dictated by the context (e.g., it includes the degree of error associated with measurement of the particular quantity).
The teachings of the present disclosure may be used in a variety of well operations. These operations may involve using one or more treatment agents to treat a formation, the fluids resident in a formation, a wellbore, and/or equipment in the wellbore, such as production tubing. The treatment agents may be in the form of liquids, gases, solids, semi-solids, and mixtures thereof. Illustrative treatment agents include, but are not limited to, fracturing fluids, acids, steam, water, brine, anti-corrosion agents, cement, permeability modifiers, drilling muds, emulsifiers, demulsifiers, tracers, flow improvers etc. Illustrative well operations include, but are not limited to, hydraulic fracturing, stimulation, tracer injection, cleaning, acidizing, steam injection, water flooding, cementing, etc.
While the invention has been described with reference to an exemplary embodiment or embodiments, it will be understood by those skilled in the art that various changes may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In addition, many modifications may be made to adapt a particular situation or material to the teachings of the invention without departing from the essential scope thereof. Therefore, it is intended that the invention not be limited to the particular embodiment disclosed as the best mode contemplated for carrying out this invention, but that the invention will include all embodiments falling within the scope of the claims. Also, in the drawings and the description, there have been disclosed exemplary embodiments of the invention and, although specific terms may have been employed, they are unless otherwise stated used in a generic and descriptive sense only and not for purposes of limitation, the scope of the invention therefore not being so limited.

Claims

1. A sensor configuration comprising

a centralizer having a rib;

a hollow defined within the rib; and

a sensor positioned within the hollow.

2. The sensor configuration as claimed in claim 1 wherein the centralizer is a solid body centralizer.

3. The sensor configuration as claimed in claim 1 wherein the sensor is entirely contained within the hollow.

4. The sensor configuration as claimed in claim 1 wherein the sensor is sealed within the hollow.

5. The sensor configuration as claimed in claim 1 wherein the sensor is a cement integrity sensor.

6. The sensor configuration as claimed in claim 1 wherein the sensor is a temperature sensor.

7. The sensor configuration as claimed in claim 1 wherein the sensoris a pressure sensor.

8. The sensor configuration as claimed in claim 1 wherein the rib is more than one rib, at least more than one of the more than one ribs containing sensors.

9. The sensor configuration as claimed in claim 8 wherein the sensors are selected from the same type of sensor or different sensors for the more than one of the more than one rib.

10. The sensor configuration as claimed in claim 2 wherein the centralizer comprises a metallic material.

11. The sensor configuration as claimed in claim 2 wherein the centralizer comprises a polymeric material.

12. A borehole system comprising:

a borehole;

a tubular string disposed within the borehole;

a centralizer having a rib, and the rib defining a hollow, disposed upon the tubular string;

a sensor within the hollow.

13. A method for acquiring data in a borehole comprising:

running a sensor configuration as claimed in claim 1 on a tubular string into a borehole;

cementing the tubular string in the borehole; and

sensing with the sensor configuration, a parameter in the borehole.

14. The method as claimed in claim 12 wherein the sensing is over time.

15. The method as claimed in claim 11 further including running another tool whose primary function is not sensor interrogation with an interrogator thereon.

16. The method as claimed in claim 12 wherein the tookis a drilling assembly.

17. The method as claimed in claim 12 wherein the tool is a completion string.