MULTI-SENSOR DOWNHOLE GAUGE

Provided is a downhole gauge for use in a wellbore, a well system, and a method. The downhole gauge, in one aspect, includes a gauge housing, the gauge housing having a first end and a second opposing end. The downhole gauge, according to this aspect, further includes first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end.

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Description
CROSS-REFERENCE TO RELATED APPLICATION

This application claims the benefit of U.S. Provisional Application Ser. No. 63/425,349, filed on Nov. 15, 2022, entitled “MULTI-SENSOR PERMANENT DOWNHOLE GAUGE,” commonly assigned with this application and incorporated herein by reference in its entirety.

BACKGROUND

In some oil and gas production environments, it may be desirable to collect data from downhole sensors.

BRIEF DESCRIPTION

Reference is now made to the following descriptions taken in conjunction with the accompanying drawings, in which:

FIG. 1 illustrates a well system, including a sensor array having one or more downhole gauges designed, manufactured and/or operated according to one embodiment of the disclosure;

FIGS. 2A through 2E illustrate different views of one embodiment of a downhole gauge designed, manufactured and/or operated according to one or more embodiments of the disclosure;

FIGS. 3A through 3E illustrate different views of an alternative embodiment of a downhole gauge designed, manufactured and/or operated according to one or more embodiments of the disclosure;

FIGS. 4A through 4E illustrate different views of an alternative embodiment of a downhole gauge designed, manufactured and/or operated according to one or more embodiments of the disclosure;

FIGS. 5A through 5E illustrate different views of an alternative embodiment of a downhole gauge designed, manufactured and/or operated according to one or more embodiments of the disclosure;

FIGS. 6A through 6E illustrate different views of an alternative embodiment of a downhole gauge designed, manufactured and/or operated according to one or more embodiments of the disclosure; and

FIGS. 7A through 7E illustrate different views of an alternative embodiment of a downhole gauge designed, manufactured and/or operated according to one or more embodiments of the disclosure.

 DETAILED DESCRIPTION

In the drawings and descriptions that follow, like parts are typically marked throughout the specification and drawings with the same reference numerals, respectively. The drawn figures are not necessarily to scale. Certain features of the disclosure may be shown exaggerated in scale or in somewhat schematic form and some details of certain elements may not be shown in the interest of clarity and conciseness. The present disclosure may be implemented in embodiments of different forms.

Specific embodiments are described in detail and are shown in the drawings, with the understanding that the present disclosure is to be considered an exemplification of the principles of the disclosure, and is not intended to limit the disclosure to that illustrated and described herein. It is to be fully recognized that the different teachings of the embodiments discussed herein may be employed separately or in any suitable combination to produce desired results.

Unless otherwise specified, use of the terms “connect,” “engage,” “couple,” “attach,” or any other like term describing an interaction between elements is not meant to limit the interaction to direct interaction between the elements and may also include indirect interaction between the elements described. Unless otherwise specified, use of the terms “up,” “upper,” “upward,” “uphole,” “upstream,” or other like terms shall be construed as generally away from the bottom, terminal end of a well; likewise, use of the terms “down,” “lower,” “downward,” “downhole,” “downstream,” or other like terms shall be construed as generally toward the bottom, terminal end of a well, regardless of the wellbore orientation. Use of any one or more of the foregoing terms shall not be construed as denoting positions along a perfectly vertical axis. Unless otherwise specified, use of the term “subterranean formation” shall be construed as encompassing both areas below exposed earth and areas below earth covered by water such as ocean or fresh water.

As used herein, the term “substantially” in reference to a given parameter means and includes to a degree that one skilled in the art would understand that the given parameter, property, or condition is met with a small degree of variance, such as within acceptable manufacturing tolerances. For example, a parameter that is substantially met may be at least about 90% met, at least about 95% met, at least about 99% met, or even at least about 100% met.

It is often most efficient to package pressure and/or temperature sensors into a downhole gauge (e.g., within a gauge housing of the downhole gauge), such as a Permanent Downhole Gauge (PDG), for monitoring downhole (e.g., reservoir) pressures and/or temperatures, among other measurements. Historically downhole gauge packaging has been limited to two pressure/temperature sensor sets. This design practice limits the downhole gauge to either both sensors monitoring the same pressure/temperature source (e.g., redundant measurement) or the downhole gauge can monitor two different pressure/temperature sources with two single sensors. Historically, in those situations where a third pressure source is desired, or redundant sensor sets for each pressure/temperature source is desired, one or more housings are added adjacent (e.g., radially offset and either axially aligned or axially offset, and coupled via a block splitter) thereto or there below (e.g., axially offset and radially offset or radially aligned) to obtain the additional pressure/temperature measurements. Adding sensors in this manner either requires the gauge mandrel, or other host tubular, to increase in OD to protect the downhole gauge or the gauge mandrel, or the other host tubular to be considerably longer. Additionally, when downhole gauges are axially added together, a short segment of Tubing Encapsulated Conductor (TEC) is required to connect the downhole gauges. Each TEC connection adds a potential leak point to the downhole gauges, which is undesirable.

The present disclosure teaches one skilled in the art how to package three or more sensors/sensor sets into a single gauge housing (e.g., single cylindrical gauge housing) of a downhole gauge, which heretofore was not feasible. This new three or more sensor downhole gauge design reduces the overall size of the downhole gauge, as well reduces the number of potential leak paths and/or failure points. Moreover, the new three or more sensor downhole gauge design may employ a newly developed single board for each of the three or more sensor, each single board including both the communications electronics and sensor electronics in a Hybrid ASIC (e.g., collectively forming a sensor set). This new Hybrid ASIC has allowed the downhole gauge to achieve an acceptable length, all the while including three or more sensors. Accordingly, in one or more embodiments a single TEC (e.g., single TEC path) may communicate with each of the three or more sensors of the downhole gauge. Moreover, the new three or more sensor downhole gauge design may be a splitter less design, and thus not employ a block splitter to accommodate the multiple radially offset downhole gauges.

The new third (e.g., or more) sensor/sensor set may be used for a variety of different purposes. In at least one embodiment, the new third (e.g., or more) sensor/sensor set is just another pressure and/or temperature sensor. In another embodiment, the new third (e.g., or more) sensor/sensor set is a water cut sensor, phase change sensor (e.g., steam break through sensor), an accelerometer (e.g., vibration sensor) or gyroscope (e.g., orientation sensor). In another embodiment, the new third (e.g., or more) sensor/sensor set is a position sensor, as might be used for determining a position of an interval control valve (ICV). In yet another embodiment, the new third (e.g., or more) sensor/sensor set is a CO2, H2 or H2S sensor, among others. Notwithstanding, the new third (e.g., or more) sensor/sensor set should not be limited to any specific sensor, and thus may include many different pressure and/or temperature sensors.

Referring now to FIG. 1, there is shown one embodiment of a well system 100, including a sensor array 102 having one or more downhole gauges designed, manufactured and/or operated according to one embodiment of the disclosure. The sensor array 102, in some embodiments, may include one or more downhole gauges 105 interconnected by lengths of wellbore conveyance 110. In certain embodiments, the wellbore conveyance 110 is a cable. The sensor array 102 may include any suitable number of downhole gauges 105. For example, in some embodiments of the disclosure, the sensor array 102 may include between ten and one hundred downhole gauges 105. The downhole gauges 105 may each be configured to detect at least one of a pressure and/or temperature, among other measurements. For example, some or all of the downhole gauges 105 in the sensor array 102 (e.g., a distributed sensor array) may each be configured to at least substantially simultaneously (e.g., at substantially the same time, in the same time interval) detect at least one of a pressure and/or a temperature in a wellbore and relay those sensed values, such that a continuous profile of conditions in the wellbore relating to such sensed values may be provided to an operator monitoring wellbore conditions.

The sensor array 102, in the illustrated embodiment, is deployed within a wellbore 115, e.g., a well for the production of oil, natural gas, water, or another subterranean resource. Each downhole gauge 105 of the sensor array 102 may be used to collect data related to at least one of a pressure and/or a temperature, among others, at a particular location within the wellbore 115. For example, each downhole gauge 105 of the sensor array 102 may collect data relating to conditions within a string of tubular components (e.g., a production string) positioned in the wellbore 115, data relating to conditions in an annulus between the string and the wellbore 115 itself, or combinations thereof, again among others. For example, ones of the downhole gauges 105 of the sensor array 102 may be positioned outside of the production string in the wellbore annulus between the string and a casing or liner string adjacent the wall of the wellbore 115.

In some embodiments, the ones of the downhole gauges 105 of the sensor array 102 may be placed in direct communication with an interior of the production string in the wellbore. For example, ones of the downhole gauges 105 of the sensor array 102 may be coupled to the outside of the production string and one or more apertures in the production string may place the ones of the downhole gauge 105 of the sensor array 102 in communication with the interior of the production string (e.g., in direct communication with pressure and/or temperature inside the production string via the apertures). Data from each individual downhole gauge 105 may be combined to provide information about a pressure and/or temperature profile within the wellbore 115 along a length of the wellbore 115 along which the sensor array 102 is deployed.

Turning to FIGS. 2A through 2E, illustrated are different views of one embodiment of a downhole gauge 200 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The downhole gauge 200, in the illustrated embodiment, includes a gauge housing 210. The gauge housing 210, in one or more embodiments, may comprise a single gauge housing. In yet another embodiment, the gauge housing 210 may comprise separate gauge housing sections that cooperate (e.g., are interconnected) to form a single gauge housing. For example, in the illustrated embodiment of FIGS. 2A through 2E, the gauge housing 210 includes five separate interconnected gauge housing sections 210a, 210b, 210c, 210d, 210e. For example, in the illustrated embodiment, the first gauge housing section 210a is a tubing encapsulated conductor (TEC) housing, the second gauge housing section 210b is a first pressure housing, the third gauge housing section 210c is a sensor manifold housing, the fourth gauge housing section 210d is a second pressure housing, and the fifth gauge housing section 210e is a hydraulic line housing.

The downhole gauge 200, in the illustrated embodiment, additionally includes a TEC 220 coupled with a first end 215a of the gauge housing 210 (e.g., the first gauge housing section 210a), as well as a hydraulic line 230 (e.g., coupled to a remote pressure source) coupled with a second end 215b of the gauge housing 210 (e.g., the fifth gauge housing section 210e). The TEC 220, in the illustrated embodiment, terminates within the gauge housing 210 proximate a TEC connection 225 coupled with the first gauge housing section 210a. Similarly, the hydraulic line 230 terminates at a hydraulic line connection 235 coupled with the fifth gauge housing section 210e.

In accordance with one embodiment of the disclosure, the downhole gauge 200 includes three or more sensors located within the gauge housing 210. For example, in the illustrated embodiment of FIGS. 2A through 2E, the downhole gauge 200 includes a first sensor 240, a second sensor 260, and a third sensor 280, all located within an interior of the gauge housing 210. In at least one embodiment, one or more of the first sensor 240, second sensor 260, and third sensor 280 are sensor sets, and thus include the communication electronics and sensor electronics on a single board.

As shown in FIG. 2C, the first sensor 240 may include a connection 245 (e.g., a metal-to-metal seal, such as an olive seal), which may allow the first sensor 240 to measure the pressure and/or temperature in an inside diameter (ID) of tubing that the downhole gauge 200 is coupled. In contrast, as shown in FIG. 2D, the second sensor 260 may fail to include a connection, which may allow the second sensor 260 to measure the pressure and/or temperature in an annulus surrounding the tubing that the downhole gauge 200 is coupled. Furthermore, as shown in FIG. 2E, the third sensor 280 may be directly coupled to the hydraulic line 230, which may allow the third sensor 280 to measure the pressure and/or temperature of a remote zone. While the first, second and third sensors 240, 260, 280 are each pressure and/or temperature sensors, other embodiments may exist wherein one or more of the first, second and third sensors 240, 260, 280 are another type of sensor, as discussed above.

In the illustrated embodiment of FIGS. 2A through 2E, the fifth gauge housing section 210e is a thinner walled tubular 205. Accordingly, in at least one embodiment, the fifth gauge housing section 210e may only be rated for up to about 1000 Bar (e.g., approximately 15K psi). Furthermore, as shown in FIGS. 2A through 2E, seals 242, 262, 282, may be used to separate the first sensor 240, second sensor 260, and third sensor 280 from other features within the gauge housing 210, including from one another. Furthermore, while the embodiment of FIGS. 2A through 2E illustrate only a first sensor 240, a second sensor 260 and a third sensor 280, other embodiments may exist wherein a fourth sensor, fifth sensor, etc. may be included within the gauge housing 210.

Turning to FIGS. 3A through 3E, illustrated are different views of an alternative embodiment of a downhole gauge 300 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The downhole gauge 300 of FIGS. 3A through 3E is similar in many respects to the downhole gauge 200 of FIGS. 2A through 2E. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole gauge 300 differs, for the most part, from the downhole gauge 200, in that the downhole gauge 300 employs a thicker walled 305 fifth gauge housing second 310e. The thicker walled 305 fifth gauge housing section 310e, along with optional high pressure welds, allows the downhole gauge 300 to accommodate wells with higher hydrostatic pressures. Accordingly, the downhole gauge 300 of FIGS. 3A through 3E may be rated for pressures greater than 1000 Bar (e.g., greater than approximately 15K psi), including being rated for pressures above 1700 Bar (e.g., greater than approximately 25K psi) and/or above 2400 Bar (e.g., greater than approximately 35K psi).

Turning to FIGS. 4A through 4E, illustrated are different views of an alternative embodiment of a downhole gauge 400 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The downhole gauge 400 of FIGS. 4A through 4E is similar in many respects to the downhole gauge 300 of FIGS. 3A through 3E. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole gauge 400 differs, for the most part, from the downhole gauge 300, in that the downhole gauge 400 employs a fourth sensor 440. The fourth sensor 440, as discussed above, may be any type of sensor and remain within the scope of the disclosure. For instance, the fourth sensor 440 could be another pressure and/or temperature sensor that is configured to measure the pressure and/or temperature of another location, or alternatively could be a redundant pressure and/or temperature sensor configured to measure the pressure and/or temperature of an existing location. Alternatively, the fourth sensor 440 could be a different type of sensor, and thus not configured to measure pressure and/or temperature. Moreover, while FIGS. 4A through 4E show the fourth sensor 440 positioned to the left of the first sensor 240, the fourth sensor 440 could be located at any other position within the gauge housing 210 and remain within the scope of the disclosure.

In the embodiment of FIGS. 4A through 4E, the fourth sensor 440 is mounted on a chassis 444. This chassis 444 is coupled to a chassis 244 of the first pressure and/or temperature sensor 240, and installed in the ID of the gauge housing 210. The fourth sensor 440 could also be mounted on a chassis which is threaded into a portion of the gauge housing 210 wall. Furthermore, one chassis could also be designed such that two or more sensors could be mounted together.

Turning to FIGS. 5A through 5E, illustrated are different views of an alternative embodiment of a downhole gauge 500 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The downhole gauge 500 of FIGS. 5A through 5E is similar in many respects to the downhole gauge 300 of FIGS. 3A through 3E. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole gauge 500 differs, for the most part, from the downhole gauge 300, in that the downhole gauge 500 employs its second sensor 260 for measuring the pressure and/or temperature of a remote zone, and uses the third sensor 280 (e.g., now in a sixth gauge housing section 510a) for measuring the annulus pressure.

Additionally, the downhole gauge 500 may include an internal wire passageway 550, such that a wire (e.g., TEC) may traverse the length of the downhole gauge 500. Thus, rather than the downhole gauge 500 having the hydraulic line 230 and hydraulic line connection 235, the downhole gauge 500 may include a second TEC 520 and associated second TEC connection 525.

Turning to FIGS. 6A through 6E, illustrated are different views of an alternative embodiment of a downhole gauge 600 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The downhole gauge 600 of FIGS. 6A through 6E is similar in many respects to the downhole gauge 500 of FIGS. 5A through 5E. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole gauge 600 differs, for the most part, from the downhole gauge 500, in that the downhole gauge 600 employs simple holes 610 in the gauge housing 210 (e.g., holes extending through the sidewall thickness of the gauge housing 210 in either of the fifth gauge housing section 210e or sixth gauge housing section 510a) to provide access to fluid within the annulus. In contrast, the downhole gauge 500 employs a sensor manifold housing for its fifth gauge housing section 210e.

Turning to FIGS. 7A through 7E, illustrated are different views of an alternative embodiment of a downhole gauge 700 designed, manufactured and/or operated according to one or more embodiments of the disclosure. The downhole gauge 700 of FIGS. 7A through 7E is similar in many respects to the downhole gauge 500 of FIGS. 5A through 5E. Accordingly, like reference numbers have been used to indicate similar, if not identical, features. The downhole gauge 700 differs, for the most part, from the downhole gauge 500, in that the downhole gauge 700 employs a fourth sensor 740. The fourth sensor 740, as discussed above, may be any type of sensor and remain within the scope of the disclosure. For instance, the fourth sensor 740 could be another pressure and/or temperature sensor that is configured to measure the pressure and/or temperature of another location, or alternatively could be a redundant pressure and/or temperature sensor configured to measure the pressure and/or temperature of an existing location. Alternatively, the fourth sensor 740 could be a different type of sensor other than a pressure and/or temperature sensor. Moreover, while FIGS. 7A through 7E show the fourth sensor 740 positioned to the left of the first sensor 240, the fourth sensor 740 could be located at any other position within the gauge housing 210 and remain within the scope of the disclosure.

A downhole gauge according to the present disclosure has many benefits. For example, a downhole gauge with three or more sensors (e.g., three or more pressure and/or temperature sensors) minimizes TEC terminations, minimizes downhole gauge length (e.g., vs adding downhole gauge below) and minimizes potential leak paths. A downhole gauge with three or more sensors (e.g., three or more pressure and/or temperature sensors) also minimizes downhole gauge “footprint” on the gauge mandrel, reduces gauge mandrel OD, and enables installation of downhole gauge in tight casing scenarios. Similarly, the downhole gauge with hydraulic connection at the bottom eliminates the need to machine hydraulic channels in the gauge mandrel to enable the downhole gauge to monitor a remote zone, reduces gauge mandrel complexity, and minimizes gauge mandrel OD. Furthermore, a downhole gauge with three or more sensors (e.g., three or more pressure and/or temperature sensors) provides additional monitoring capabilities, reduced complexity (e.g., vs installing separate tool(s)) and reduces potential leak paths. Likewise, a downhole gauge with three pressure and/or temperature sensors, and the option to add additional sensors, along with a TEC feedthrough, enables multi-drop capability.

Aspects disclosed herein include:

A. A downhole gauge for use in a wellbore, the downhole gauge including: 1) a gauge housing, the gauge housing having a first end and a second opposing end; and 2) first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end.

B. A well system, the well system including: 1) a wellbore extending through one or more subterranean formations; 2) a tubular located within the wellbore; and 3) a downhole gauge coupled with the tubular within the wellbore, the downhole gauge including: a) a gauge housing, the gauge housing having a first end and a second opposing end; and b) first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end.

C. A method, the method including: 1) positioning a tubular within a wellbore extending through one or more subterranean formations, the tubular having a downhole gauge coupled therewith, the downhole gauge including: a) a gauge housing, the gauge housing having a first end and a second opposing end; and b) first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end; and 2) measuring one or more properties within the wellbore using the first, second and third sensors located within the interior of the gauge housing.

Aspects A, B, and C may have one or more of the following additional elements in combination: Element 1: further including a tubing encapsulated conductor (TEC) coupled to the first end of the gauge housing using a tubing encapsulated conductor (TEC) connection. Element 2: wherein the tubing encapsulated conductor (TEC) is a first tubing encapsulated conductor (TEC), and further including a second tubing encapsulated conductor (TEC) coupled to the second end of the gauge housing using a second tubing encapsulated conductor (TEC) connection. Element 3: further including one or more internal wire passageways extending from the first and second opposing ends of the gauge housing, the one or more internal wire passageways configured to couple the first tubing encapsulated conductor (TEC) and the second tubing encapsulated conductor (TEC). Element 4: wherein the gauge housing includes a plurality of interconnected gauge housing sections. Element 5: wherein the first sensor is a first pressure and/or temperature sensor, the first pressure and/or temperature sensor configured to measure a first pressure and/or temperature in an inside diameter (ID) of tubing that the downhole gauge is coupled. Element 6: wherein the second sensor is a second pressure and/or temperature sensor, the second pressure and/or temperature sensor configured to measure a second pressure and/or temperature in an annulus surrounding the tubing that the downhole gauge is coupled. Element 7: wherein the third sensor is a third pressure and/or temperature sensor, the third pressure and/or temperature sensor configured to measure a third pressure and/or temperature of a remote zone. Element 8: further including a fourth sensor located within the interior the gauge housing, the fourth sensor not configured to measure pressure and/or temperature. Element 9: wherein one or more of the first, second and third sensors is a sensor set, each sensor set including communication electronics and sensor electronics on a single board. Element 10: wherein the downhole gauge is a first downhole gauge, and further including a second downhole gauge coupled with the tubular within the wellbore, the first and second downhole gauges forming a sensor array, the second downhole gauge including: i) a second gauge housing, the second gauge housing having opposing ends; and ii) a second set of first, second and third sensors located within an interior of the second gauge housing between the opposing ends.

Those skilled in the art to which this application relates will appreciate that other and further additions, deletions, substitutions and modifications may be made to the described embodiments.

Claims

1. A downhole gauge for use in a wellbore, comprising:

a gauge housing, the gauge housing having a first end and a second opposing end; and
first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end.

2. The downhole gauge as recited in claim 1, further including a tubing encapsulated conductor (TEC) coupled to the first end of the gauge housing using a tubing encapsulated conductor (TEC) connection.

3. The downhole gauge as recited in claim 2, wherein the tubing encapsulated conductor (TEC) is a first tubing encapsulated conductor (TEC), and further including a second tubing encapsulated conductor (TEC) coupled to the second end of the gauge housing using a second tubing encapsulated conductor (TEC) connection.

4. The downhole gauge as recited in claim 3, further including one or more internal wire passageways extending from the first and second opposing ends of the gauge housing, the one or more internal wire passageways configured to couple the first tubing encapsulated conductor (TEC) and the second tubing encapsulated conductor (TEC).

5. The downhole gauge as recited in claim 1, wherein the gauge housing includes a plurality of interconnected gauge housing sections.

6. The downhole gauge as recited in claim 1, wherein the first sensor is a first pressure and/or temperature sensor, the first pressure and/or temperature sensor configured to measure a first pressure and/or temperature in an inside diameter (ID) of tubing that the downhole gauge is coupled.

7. The downhole gauge as recited in claim 6, wherein the second sensor is a second pressure and/or temperature sensor, the second pressure and/or temperature sensor configured to measure a second pressure and/or temperature in an annulus surrounding the tubing that the downhole gauge is coupled.

8. The downhole gauge as recited in claim 7, wherein the third sensor is a third pressure and/or temperature sensor, the third pressure and/or temperature sensor configured to measure a third pressure and/or temperature of a remote zone.

9. The downhole gauge as recited in claim 8, further including a fourth sensor located within the interior the gauge housing, the fourth sensor not configured to measure pressure and/or temperature.

10. The downhole gauge as recited in claim 1, wherein one or more of the first, second and third sensors is a sensor set, each sensor set including communication electronics and sensor electronics on a single board.

11. A well system, comprising:

a wellbore extending through one or more subterranean formations;
a tubular located within the wellbore; and
a downhole gauge coupled with the tubular within the wellbore, the downhole gauge including: a gauge housing, the gauge housing having a first end and a second opposing end; and first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end.

12. The well system as recited in claim 11, further including a tubing encapsulated conductor (TEC) coupled to the first end of the gauge housing using a tubing encapsulated conductor (TEC) connection.

13. The well system as recited in claim 12, wherein the tubing encapsulated conductor (TEC) is a first tubing encapsulated conductor (TEC), and further including a second tubing encapsulated conductor (TEC) coupled to the second end of the gauge housing using a second tubing encapsulated conductor (TEC) connection.

14. The well system as recited in claim 13, further including one or more internal wire passageways extending from the first and second opposing ends of the gauge housing, the one or more internal wire passageways configured to couple the first tubing encapsulated conductor (TEC) and the second tubing encapsulated conductor (TEC).

15. The well system as recited in claim 11, wherein the gauge housing includes a plurality of interconnected gauge housing sections.

16. The well system as recited in claim 11, wherein the first sensor is a first pressure and/or temperature sensor, the first pressure and/or temperature sensor configured to measure a first pressure and/or temperature in an inside diameter (ID) of tubing that the downhole gauge is coupled.

17. The well system as recited in claim 16, wherein the second sensor is a second pressure and/or temperature sensor, the second pressure and/or temperature sensor configured to measure a second pressure and/or temperature in an annulus surrounding the tubing that the downhole gauge is coupled.

18. The well system as recited in claim 17, wherein the third sensor is a third pressure and/or temperature sensor, the third pressure and/or temperature sensor configured to measure a third pressure and/or temperature of a remote zone.

19. The well system as recited in claim 18, further including a fourth sensor located within the interior the gauge housing, the fourth sensor not configured to measure pressure and/or temperature.

20. The well system as recited in claim 11, wherein one or more of the first, second and third sensors is a sensor set, each sensor set including communication electronics and sensor electronics on a single board.

21. The well system as recited in claim 11, wherein the downhole gauge is a first downhole gauge, and further including a second downhole gauge coupled with the tubular within the wellbore, the first and second downhole gauges forming a sensor array, the second downhole gauge including:

a second gauge housing, the second gauge housing having opposing ends; and
a second set of first, second and third sensors located within an interior of the second gauge housing between the opposing ends.

22. A method, comprising:

positioning a tubular within a wellbore extending through one or more subterranean formations, the tubular having a downhole gauge coupled therewith, the downhole gauge including: a gauge housing, the gauge housing having a first end and a second opposing end; and first, second and third sensors located within an interior of the gauge housing between the first end and the second opposing end; and
measuring one or more properties within the wellbore using the first, second and third sensors located within the interior of the gauge housing.
Patent History
Publication number: 20240159143
Type: Application
Filed: Nov 14, 2023
Publication Date: May 16, 2024
Inventors: Louis Francis Lafleur (Spring, TX), Colin McKay (Aberdeen), Glen P. Breerwood (Spring, TX)
Application Number: 18/508,813
Classifications
International Classification: E21B 47/07 (20060101); E21B 47/01 (20060101);