US20140353036A1 - Apparatus and Method for Measuring Inclination in Subsea Running, Setting, and Testing Tools - Google Patents
Apparatus and Method for Measuring Inclination in Subsea Running, Setting, and Testing Tools Download PDFInfo
- Publication number
- US20140353036A1 US20140353036A1 US13/904,873 US201313904873A US2014353036A1 US 20140353036 A1 US20140353036 A1 US 20140353036A1 US 201313904873 A US201313904873 A US 201313904873A US 2014353036 A1 US2014353036 A1 US 2014353036A1
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- United States
- Prior art keywords
- inclination
- jetting
- receiver
- tool
- transmitter
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
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- 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
- E21B7/00—Special methods or apparatus for drilling
- E21B7/18—Drilling by liquid or gas jets, with or without entrained pellets
- E21B7/185—Drilling by liquid or gas jets, with or without entrained pellets underwater
-
- 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
- E21B44/00—Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
-
- 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
- E21B47/02—Determining slope or direction
- E21B47/022—Determining slope or direction of the borehole, e.g. using geomagnetism
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- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Geophysics (AREA)
- Earth Drilling (AREA)
- Length Measuring Devices Characterised By Use Of Acoustic Means (AREA)
- Testing Of Devices, Machine Parts, Or Other Structures Thereof (AREA)
Abstract
A system for jetting a borehole in a seafloor, the system including a tubular, and a jetting tool inserted into the tubular and having an end from which fluid is selectively discharged to excavate the borehole. An electrical inclination sensor is attached to the stem of the tubular, and is in communication a transmitter. A receiver is positioned proximate the sea surface and is in communication with the transmitter through the fluid in a drill pipe, so that when the jetting tool is excavating the borehole, an inclination of the tubular is sensed by the inclination sensor, which inclination is communicated from the transmitter to the receiver.
Description
- 1. Field of the Invention
- This technology relates to subsea oil and gas wells. In particular, this technology relates to measurement of inclination of running, setting, and testing tools during the primary phase of jetting a subsea well.
- 2. Brief Description of Related Art
- Typical subsea drilling operations include a drilling vessel and an arrangement of equipment to accomplish the first drilling phase of a well. Where the sea floor is sandy, the first phase of the drilling operation may include jetting. Jetting is a process wherein a jetting tool, enclosed within a casing, is placed adjacent the sea floor. Fluid is sprayed through the end of the jetting tool and directed at the sand on the sea floor. The fluid is turbulent and stirs up the sand, which mixes with the fluid and is carried up the casing away from the bottom of the casing. When the sand is thus removed, the casing is lowered into the void left behind. This process is continued until the casing reaches a predetermined depth, after which equipment related to the next phase of drilling (i.e. a high pressure housing, blow out preventer, marine riser, etc.) is connected.
- It is beneficial for the equipment used in this first stage of drilling to be vertically oriented while the well is created. Such a vertical orientation allows for straight and proper connections of equipment used in subsequent phases of drilling. Accordingly, monitoring the inclination of the jetting equipment used during the first phase of drilling may be beneficial to help ensure that a vertical orientation is maintained.
- Disclosed herein is a system for jetting a borehole in a sea floor. In an example, the system includes a tubular having a stem, a housing running and jet tool, and a jetting tool inserted into the tubular and having an end from which fluid is selectively discharged to excavate the borehole. An electrical inclination sensor is attached either to the stem of the tubular, or to the housing running and jet tool. The electrical inclination sensor measures vertical inclination of the jetting tool and the housing running and jet tool.
- A transmitter is attached to the electrical inclination sensor that receives information related to the inclination of the jetting tool and the housing running and jet tool from the electrical inclination sensor. The transmitter than transmits either a mud pulse signal or an acoustic signal, depending on the placement of the transmitter, containing information about the inclination of the jetting tool and the housing running and jet tool.
- A receiver is located at the drilling vessel and is configured to receive the mud pulse or other acoustic signal from the transmitter. If the transmitter is attached to the stem of the jetting tool, the receiver may be attached to a receptor at the top of the drill string. If the transmitter is attached to the housing and drill tool, so that is transmits acoustic signals into the sea water, the receiver may be positioned near the drilling vessel and submerged in the sea.
- Also disclosed herein is a method for jetting a borehole in a sea floor. The method includes the steps of jetting a borehole by selectively discharging fluid our of a jetting tool directed at the sea floor, and providing an electrical inclination sensor that measures the inclination of the jetting tool. The method also provides monitoring the inclination of the jetting tool with the electrical inclination sensor prior to and during drilling activities, acoustically transmitting a signal containing information about the inclination of the jetting tool via a transmitter attached to the electrical inclination sensor, and receiving the signal with a receiver proximate the sea surface.
- The present technology will be better understood on reading the following detailed description of nonlimiting embodiments thereof, and on examining the accompanying drawings, in which:
-
FIG. 1A is a perspective view of a jetting assembly according to an embodiment of the present technology; -
FIG. 1B is an enlarged view of the area indicated by thecircle 1B inFIG. 1A ; -
FIG. 2 is a side view of the jetting assembly ofclaim 1 in operation during a primary phase of drilling a well; -
FIG. 3A is a perspective view of a system for running, setting, and testing subsea jetting tools according to an embodiment of the present technology; -
FIG. 3B is an enlarged side view of a portion of the jetting equipment shown inFIG. 3A , as indicated by thearea 3B ofFIG. 3A ; -
FIG. 4 is a side view of a the jetting assembly according to an embodiment of the present technology, with a known analog inclination sensor and a remotely operated vehicle; -
FIG. 5A is a side view of the jetting assembly according to an embodiment of the present technology, including an electrical inclination sensor attached to the stem of the housing running and jet tool; -
FIG. 5B is an enlarged side view of the electrical inclination tool attached to the stem of the housing running and jet tool, as indicated byarea 5B ofFIG. 5A ; -
FIG. 6 is a perspective view of components of a system for running, setting, and testing subsea jetting tools according to an embodiment of the present technology, including a transmitter and receiver configured to communicate via mud pulse data transmission; -
FIG. 7A is a side view of components of a system for running, setting, and testing subsea jetting tools according to an embodiment of the present technology, including a transmitter and receiver configured to communicate via acoustic data transmission; and -
FIG. 7B is a side view of a portion of the jetting assembly, including an electrical inclination sensor and a transmitter configured for acoustic data transmission, as indicated byarea 7B ofFIG. 7A . - The foregoing aspects, features, and advantages of the present technology will be further appreciated when considered with reference to the following description of preferred embodiments and accompanying drawings, wherein like reference numerals represent like elements. In describing the preferred embodiments of the technology illustrated in the appended drawings, specific terminology will be used for the sake of clarity. However, the technology is not intended to be limited to the specific terms used, and it is to be understood that each specific term includes equivalents that operate in a similar manner to accomplish a similar purpose.
-
FIG. 1A shows ajetting assembly 10 according to an embodiment of the present technology, including alow pressure housing 12, acasing string 14, a housing running andjet tool 16,drill pipe 18, and ajetting tool 20. The housing running andjet tool 16 has astem 21.Jetting assembly 10 is configured to accomplish the first phase of a drilling program, by beginning drilling a wellbore into the sea floor. As shown inFIG. 1B , when the jettingassembly 10 is assembled, theend 22 of the jettingtool 20 is positioned a predetermined distance D from the bottom of thecasing string 14. In one embodiment, this distance D may be about 18 inches. Before initiating jetting operations, and during the course of jetting the first phase of the well, it is desirable for the jettingassembly 10, and in particular thedrill pipe 18 and thecasing 14, to be vertically oriented. Such a vertical orientation allows for the successful connection and operation of equipment during subsequent drilling phases. -
FIG. 2 shows the jettingassembly 10 in practice. Once the jettingassembly 10 is positioned vertically adjacent thesea floor 24, the jettingtool 20 ejects fluid downward toward thesea floor 24. The ejection of fluid causes turbulence at the end of thecasing string 14, which turbulence stirs up the sand and sediment on thesea floor 24. As the sand and sediment is stirred up, it is carried by the fluid upwardly through thecasing string 14, along the path indicated by arrows A. In the embodiment shown, the sand and sediment may be discharged into the sea through thelow pressure housing 12. As the sand and sediment is stirred and carried upward by the drill fluid, a void space is created immediately below thecasing string 14. Thecasing string 14 then travels downward to fill the void space. This sequence of operation (i.e., jetting, removal of sand and sediment, and lowering of the casing string) is repeated as needed until theassembly 10 achieves a predetermined depth. The fluid may be incontaminable, to minimize or eliminate environmental hazards when the fluid is discharged in the sea along with the sand and sediment. - Referring to
FIG. 3A , there is shown a system for running, setting, and testing subsea jetting tools, including equipment used to carry out subsequent phases of drilling after the first phase is completed. Specifically,FIG. 3A shows adrilling vessel 26, located at the surface of the sea, and additional subsea drilling equipment located at thesea bed 24. Although thedrilling vessel 26 is shown to be a ship, it could also be a drilling platform, such as, for example, a floating platform, tension leg platform, etc. An enlarged view of some of this additional subsea drilling equipment is shown inFIG. 3B , and includes thelow pressure housing 12, ahigh pressure housing 30 configured for insertion inside thelow pressure housing 12, and apressure management device 32, such as, for example, a blowout preventer (BOP). As shown, the subsea drilling equipment may be connected to thedrilling vessel 26 by amarine riser 28. - In practice, the jetting
assembly 10 may be assembled on thedrilling vessel 26. To accomplish this, the housing running andjet tool 16 is inserted and locked into thelow pressure housing 12.Drill pipe 18 is also attached to the housing running andjet tool 16. This may be accomplished by connecting a bottom thread of the housing running andjet tool 16 to a top thread of thedrill pipe 18. Similarly, the jettingtool 20 may then be attached to thedrill pipe 18 by, for example, connecting a bottom thread of thedrill pipe 18 with a top thread of the jettingtool 20. Thecasing string 14 is also connected to thelow pressure housing 12, and is configured so its bottom end is a predetermined distance D from thebottom end 22 of the jettingtool 20, as discussed above. Once the jettingassembly 10 has been assembled, it is lowered to the sea floor. The jettingassembly 10 remains connected to thedrilling vessel 26 by a drill pipe (not shown) which extends upwardly through themarine riser 28 from the jettingassembly 10 to thedrilling vessel 26. The fluid to be ejected by the jettingtool 20 is delivered to thejetting tool 20 from thedrilling vessel 26 via thedrill pipe 18. - As discussed above, it is desirable that the jetting
assembly 10 maintain a vertical orientation through the jetting phase. Accordingly,FIG. 4 shows one known method of verifying such a vertical orientation that includes an analoginclination measuring device 34 attached to the jettingassembly 10. In an example, an analoginclination measuring device 34 is of the type known as a “Bullseye” device in the industry that includes liquid in a sealed chamber, and a ball floating in the liquid. Reference lines are drawn on surfaces of the chamber, and as the equipment inclines, the liquid pushes the floating ball to a corresponding reference line. Association of the ball with a particular reference line indicates how much the device is inclined. Options exist where the analoginclination measuring device 34 is attached to or formed integrally with, the housing running andjet tool 16. - In practice, the use of such an analog
inclination measuring device 34 requires that an inclination reading be taken between each iteration of jetting (i.e., between each sequence of jetting, sand and sediment removal, and lowering of the casing string). Such an inclination reading requires use of a remotely operated vehicle (ROV) 36, and can be time consuming and inefficient. This is because theROV 36 can only read the analoginclination measuring device 34 from close proximity, as shown inFIG. 4 . During the actual jetting operation, however, theROV 36 must be positioned relatively far away from the jettingassembly 10 so as not to interfere with operations. This means that between each iteration of jetting, theROV 36 must move into close proximity of the analoginclination measuring device 34, take the inclination reading, transmit the reading to an operator on thedrilling vessel 26, and move back away from the jetting assembly 10 a safe distance. - A better way to measure the inclination of the jetting
assembly 10 is through the use of anelectrical inclination sensor 38, as shown inFIGS. 5A and 5B . One example of such anelectrical inclination sensor 38 is disclosed in U.S. Pat. No. 4,937,518, which is hereby incorporated by reference herein. As shown, theelectrical inclination sensor 38 is attached to the jettingassembly 10, and is configured to send an inclination signal to an operator on thedrilling vessel 26 in real time. In some embodiments, theelectrical inclination sensor 38 may be attached to thestem 21 of the housing running andjet tool 16. In other embodiments, theelectrical inclination sensor 38 may be attached to the low pressure housing 12 (as shown inFIG. 7 ). - The real time transmission of inclination data from the jetting
assembly 10 to an operator on thedrilling vessel 26 is advantageous because it eliminates the need to stop jetting between each jetting iteration to allow theROV 36 to take an inclination reading. Furthermore, the real time transmission allows an operator to detect a problem with the inclination immediately when the problem occurs, rather than waiting for the next break between jetting iterations. Thus, the jetting process is more efficient, and potential problems can be identified and remedied more rapidly. - Signal transmission from the
electrical inclination sensor 38 to the operator on thedrilling vessel 26 can be accomplished in at least two different ways. For example, the data signal from theelectrical inclination sensor 38 can be sent via mud pulse transmission (shown inFIG. 6 ) or acoustic data transmission (shown inFIG. 7 ). In each case, the data signal is transmitted from theelectrical inclination sensor 38 by atransmitter 40, and received by areceiver 42. - In the case of mud pulse transmission, shown in
FIG. 6 , theelectrical inclination sensor 38 may be attached to thestem 21 of the housing running andjet tool 16. Thetransmitter 40 may also be attached to thestem 21 of the housing running andjet tool 16, and may be connected to theelectrical inclination sensor 38 by a wire (not shown). Coupled with thedrill pipe 18, proximate thedrilling vessel 26, is areceptor stem 44. The receptor stem 44 may be attached to thedrill pipe 18 by engaging a top thread of thedrill pipe 18 with a corresponding bottom thread of thereceptor stem 44. Areceiver 42 is attached to thereceptor stem 44 and in communication with adisplay 46 that is viewable by an operator. - In practice, the
electrical inclination sensor 38 determines the inclination of thestem 21 of the housing running andjet tool 16, which corresponds to the inclination of theentire drill assembly 10. Theinclination sensor 38 then communicates the inclination data to thetransmitter 40. Next, thetransmitter 40 transmits an inclination data signal upward in a pulse through the mud surrounding thestem 21 and thedrill pipe 18 to thereceptor stem 44. At thereceptor stem 44, thereceiver 42 receives the signal, and communicates the inclination data to thedisplay 46. In certain embodiments, the inclination data is generated constantly by theelectrical inclination sensor 38 and transmitted in real time to thereceiver 42. Thus, the operator receives continuous real time data about the inclination of thedrill assembly 10 throughout the primary jetting process. - In an example of acoustic data transmission, as shown in
FIGS. 7A and 7B , theelectrical inclination sensor 38 is attached to an outer face of the lowpressure housing member 12. Likewise, thetransmitter 40 is attached to the outer surface of the lowpressure housing member 12, and is connected to theelectrical inclination sensor 38 by a wire (not shown).Receiver 42 is positioned near the drilling vessel 26 (shown as a floating platform inFIG. 7 ), and is connected to a display 46 (shown inFIG. 6 ) that is viewable by an operator. - In an example of operation, the
electrical inclination sensor 38 senses an inclination of thelow pressure housing 12, which corresponds to the inclination of theentire drill assembly 10. Theinclination sensor 38 then communicates the inclination data to thetransmitter 40, which transmits an inclination data signal into the surrounding sea water that is received byreceiver 42. Based on the received signal, thereceiver 42 communicates the inclination data to thedisplay 46. In certain embodiments, the inclination data is generated constantly by theelectrical inclination sensor 38 and transmitted in real time to thereceiver 42. Thus, the operator receives continuous real time data about the inclination of thedrill assembly 10 throughout the primary jetting process. In this embodiment, thereceiver 42 is submerged in the sea water proximate the vessel so that it can better intercept the acoustic signals transmitted by thetransmitter 40. - In certain embodiments, the
receiver 42 can communicate with an analysis device or system, such as a computer, processor, network, software, analytics engine, etc. Such communication may be by means of a wire, or wireless transmission signals. The analysis device or system may be adapted to react to certain data received from thereceiver 42 by, for example, sounding an alarm, sending a message, or sending control signals to automatically or semi-automatically control the equipment. In addition, the analysis device or system could be located near thereceiver 42 or remote from thereceiver 42, such as, for example, at a distant location. - While the technology has been shown or described in only some of its forms, it should be apparent to those skilled in the art that it is not so limited, but is susceptible to various changes without departing from the scope of the invention. Furthermore, it is to be understood that the above disclosed embodiments are merely illustrative of the principles and applications of the present invention. Accordingly, numerous modifications may be made to the illustrative embodiments and other arrangements may be devised without departing from the spirit and scope of the present invention as defined by the appended claims.
Claims (13)
1. A system for jetting a borehole in a seafloor, the system comprising:
a tubular;
a jetting tool inserted into the tubular and having an end from which fluid is selectively discharged to excavate the borehole;
an electrical inclination sensor attached to the stem of the tubular;
a transmitter in communication with the electrical inclination sensor; and
a receiver proximate the sea surface and in communication with the transmitter through the fluid in a drill pipe, so that when the jetting tool is excavating the borehole, an inclination of the tubular is sensed by the inclination sensor, which inclination is communicated from the transmitter to the receiver.
2. The system of claim 1 , further comprising a display in communication with the receiver that is accessible to an operator, and shows the information transmitted to the receiver.
3. The system of claim 1 , wherein the transmitter transmits, and the receiver receives, information about the inclination of the tubular continuously in real time.
4. The system of claim 1 , wherein communication between the receiver and the transmitter comprises acoustic pulses that propagate through the drill pipe.
5. A system for jetting a borehole in a seafloor, the system comprising:
running and setting tools, including at least a housing running and jet tool operatively connected to a drilling vessel, and a jetting tool having an end from which fluid is selectively discharged to excavate the borehole;
an electrical inclination sensor attached to the housing running and jet tool, and capable of measuring the relative vertical inclination of the housing running and jet tool;
a transmitter attached to the electrical inclination sensor that receives information related to the inclination of the housing running and jet tool from the electrical inclination sensor, and that transmits an acoustic signal containing information about the inclination of the housing running and jet tool into the sea; and
a receiver located proximate the drilling vessel and at least partially submerged in the sea, the receiver configured to receive the acoustic signal from the transmitter.
6. The system of claim 5 , further comprising a display in communication with the receiver, and accessible to an operator, that shows the information transmitted to the receiver in the acoustic signal.
7. The system of claim 5 , wherein the transmitter transmits, and the receiver receives, information about the inclination of the housing running and jet tool continuously in real time.
8. A method for jetting a borehole in a seafloor, the method comprising:
jetting a borehole by selectively discharging fluid out of a jetting tool directed at the sea floor;
providing an electrical inclination sensor that measures the inclination of the jetting tool;
monitoring the inclination of the jetting tool with the electrical inclination sensor prior to and during jetting activities; and
acoustically transmitting, to a receiver proximate the sea surface, a signal containing information about the inclination of the jetting tool via a transmitter attached to the electrical inclination sensor.
9. The method of claim 8 , further comprising the step of displaying the information about the inclination of the jetting tool on a display screen in communication with the receiver.
10. The method of claim 8 , wherein the step of monitoring the inclination of the jetting tool is carried out continuously in real time during the landing and setting of subsea wellhead consumables on the sea floor.
11. The method of claim 8 , wherein the jetting tool is deployed on a fluid filled tubular string, and wherein the step of acoustically transmitting the signal comprises directing pulses through the fluid in the string.
12. The method of claim 8 , wherein the step of acoustically transmitting the signal comprises directing pulses through sea water.
13. The method of claim 8 , further comprising the step of receiving the signal by the receiver.
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/904,873 US20140353036A1 (en) | 2013-05-29 | 2013-05-29 | Apparatus and Method for Measuring Inclination in Subsea Running, Setting, and Testing Tools |
SG11201509387YA SG11201509387YA (en) | 2013-05-29 | 2014-05-07 | Apparatus and method for measuring inclination in subsea running, setting and testing tools |
PCT/US2014/037054 WO2014193616A2 (en) | 2013-05-29 | 2014-05-07 | Apparatus and method for measuring inclination in subsea running, setting and testing tools |
BR112015028445A BR112015028445A2 (en) | 2013-05-29 | 2014-05-07 | system and method for blasting a well on a seabed |
NO20151502A NO20151502A1 (en) | 2013-05-29 | 2015-11-06 | Apparatus and method for measuring inclination in subsea running setting and testing tools |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US13/904,873 US20140353036A1 (en) | 2013-05-29 | 2013-05-29 | Apparatus and Method for Measuring Inclination in Subsea Running, Setting, and Testing Tools |
Publications (1)
Publication Number | Publication Date |
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US20140353036A1 true US20140353036A1 (en) | 2014-12-04 |
Family
ID=50943576
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US13/904,873 Abandoned US20140353036A1 (en) | 2013-05-29 | 2013-05-29 | Apparatus and Method for Measuring Inclination in Subsea Running, Setting, and Testing Tools |
Country Status (5)
Country | Link |
---|---|
US (1) | US20140353036A1 (en) |
BR (1) | BR112015028445A2 (en) |
NO (1) | NO20151502A1 (en) |
SG (1) | SG11201509387YA (en) |
WO (1) | WO2014193616A2 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP3438350A1 (en) * | 2017-08-04 | 2019-02-06 | OneSubsea IP UK Limited | Subsea deployment monitoring system |
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US3353612A (en) * | 1964-06-01 | 1967-11-21 | Clyde E Bannister | Method and apparatus for exploration of the water bottom regions |
US4558744A (en) * | 1982-09-14 | 1985-12-17 | Canocean Resources Ltd. | Subsea caisson and method of installing same |
US4813496A (en) * | 1988-06-01 | 1989-03-21 | Vetco Gray Inc. | Drill ahead tool |
US4937518A (en) * | 1988-01-27 | 1990-06-26 | Marelli Autronica S.P.A. | Electrical inclination sensor and a monitoring circuit for the sensor |
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US7080689B2 (en) * | 2002-06-13 | 2006-07-25 | Institut Francais Du Petrole | Instrumentation assembly for an offshore riser |
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US20130234859A1 (en) * | 2012-03-08 | 2013-09-12 | Cathedral Energy Services Ltd. | Method for Transmission of Data from a Downhole Sensor Array |
US8967292B2 (en) * | 2010-11-09 | 2015-03-03 | Agr Subsea As | Method and device for establishing a borehole in the seabed |
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US6075462A (en) * | 1997-11-24 | 2000-06-13 | Smith; Harrison C. | Adjacent well electromagnetic telemetry system and method for use of the same |
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GB9914786D0 (en) * | 1999-06-25 | 1999-08-25 | Xl Technology Limited | Seabed analysis |
EP2516788A1 (en) * | 2009-12-23 | 2012-10-31 | Shell Internationale Research Maatschappij B.V. | Method of drilling and jet drilling system |
-
2013
- 2013-05-29 US US13/904,873 patent/US20140353036A1/en not_active Abandoned
-
2014
- 2014-05-07 BR BR112015028445A patent/BR112015028445A2/en not_active IP Right Cessation
- 2014-05-07 WO PCT/US2014/037054 patent/WO2014193616A2/en active Application Filing
- 2014-05-07 SG SG11201509387YA patent/SG11201509387YA/en unknown
-
2015
- 2015-11-06 NO NO20151502A patent/NO20151502A1/en unknown
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US3353612A (en) * | 1964-06-01 | 1967-11-21 | Clyde E Bannister | Method and apparatus for exploration of the water bottom regions |
US4558744A (en) * | 1982-09-14 | 1985-12-17 | Canocean Resources Ltd. | Subsea caisson and method of installing same |
US4937518A (en) * | 1988-01-27 | 1990-06-26 | Marelli Autronica S.P.A. | Electrical inclination sensor and a monitoring circuit for the sensor |
US4813496A (en) * | 1988-06-01 | 1989-03-21 | Vetco Gray Inc. | Drill ahead tool |
US8042616B2 (en) * | 2000-04-13 | 2011-10-25 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling a wellbore using casing |
US20030168218A1 (en) * | 2002-03-01 | 2003-09-11 | Philip Head | Conductor system |
US7080689B2 (en) * | 2002-06-13 | 2006-07-25 | Institut Francais Du Petrole | Instrumentation assembly for an offshore riser |
US7938201B2 (en) * | 2002-12-13 | 2011-05-10 | Weatherford/Lamb, Inc. | Deep water drilling with casing |
US7685892B2 (en) * | 2004-03-22 | 2010-03-30 | Vetco Gray Scandinavia As | Method and a device for monitoring an/or controlling a load on a tensioned elongated element |
US7328741B2 (en) * | 2004-09-28 | 2008-02-12 | Vetco Gray Inc. | System for sensing riser motion |
US8096370B2 (en) * | 2006-01-20 | 2012-01-17 | Gud Ingenieurburo Fur Spezialtiefbau Gmbh | Apparatus and method for producing soil elements underground |
US8967292B2 (en) * | 2010-11-09 | 2015-03-03 | Agr Subsea As | Method and device for establishing a borehole in the seabed |
US20130234859A1 (en) * | 2012-03-08 | 2013-09-12 | Cathedral Energy Services Ltd. | Method for Transmission of Data from a Downhole Sensor Array |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP3438350A1 (en) * | 2017-08-04 | 2019-02-06 | OneSubsea IP UK Limited | Subsea deployment monitoring system |
Also Published As
Publication number | Publication date |
---|---|
BR112015028445A2 (en) | 2017-07-25 |
SG11201509387YA (en) | 2015-12-30 |
WO2014193616A3 (en) | 2015-04-16 |
NO20151502A1 (en) | 2015-11-06 |
WO2014193616A2 (en) | 2014-12-04 |
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