WO2014193616A2 - 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
- WO2014193616A2 WO2014193616A2 PCT/US2014/037054 US2014037054W WO2014193616A2 WO 2014193616 A2 WO2014193616 A2 WO 2014193616A2 US 2014037054 W US2014037054 W US 2014037054W WO 2014193616 A2 WO2014193616 A2 WO 2014193616A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- inclination
- jetting
- receiver
- tool
- transmitter
- 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
- 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
- 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
Definitions
- This technology relates to subsea oil and gas wells.
- this technology relates to measurement of inclination of running, setting, and testing tools during the primary phase of jetting a subsea well.
- Typical subsea drilling operations include a drilling vessel and an arrangement of equipment to accomplish the first drilling phase of a well.
- 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.
- equipment related to the next phase of drilling i.e. a high pressure housing, blow out preventer, marine riser, etc.
- 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.
- a method for jetting a borehole in a sea floor 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.
- Fig. 1A is a perspective view of a jetting assembly according to an embodiment of the present technology
- Fig. IB is an enlarged view of the area indicated by the circle IB in Fig. 1 A;
- Fig. 2 is a side view of the jetting assembly of claim 1 in operation during a primary phase of drilling a well;
- FIG. 3 A 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 in Fig. 3A, as indicated by the area 3B of Fig. 3 A;
- 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 by area 5B of Fig. 5 A;
- 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 by area 7B of Fig. 7A.
- Fig. 1A shows a jetting assembly 10 according to an embodiment of the present technology, including a low pressure housing 12, a casing string 14, a housing running and jet tool 16, drill pipe 18, and a jetting tool 20.
- the housing running and jet tool 16 has a stem 21.
- Jetting assembly 10 is configured to accomplish the first phase of a drilling program, by beginning drilling a wellbore into the sea floor.
- Fig. IB when the jetting assembly 10 is assembled, the end 22 of the jetting tool 20 is positioned a predetermined distance D from the bottom of the casing string 14. In one embodiment, this distance D may be about 18 inches.
- the jetting assembly 10 Before initiating jetting operations, and during the course of jetting the first phase of the well, it is desirable for the jetting assembly 10, and in particular the drill pipe 18 and the casing 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 jetting assembly 10 in practice.
- the jetting tool 20 ejects fluid downward toward the sea floor 24.
- the ejection of fluid causes turbulence at the end of the casing string 14, which turbulence stirs up the sand and sediment on the sea floor 24.
- the sand and sediment is stirred up, it is carried by the fluid upwardly through the casing string 14, along the path indicated by arrows A.
- the sand and sediment may be discharged into the sea through the low pressure housing 12.
- a void space is created immediately below the casing string 14.
- the casing 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
- 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.
- 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.
- Fig. 3A shows a drilling vessel 26, located at the surface of the sea, and additional subsea drilling equipment located at the sea bed 24.
- the drilling 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 in Fig.
- the subsea drilling equipment may be connected to the drilling vessel 26 by a marine riser 28.
- the jetting assembly 10 may be assembled on the drilling vessel 26.
- the housing running and jet tool 16 is inserted and locked into the low pressure housing 12.
- Drill pipe 18 is also attached to the housing running and jet tool 16. This may be accomplished by connecting a bottom thread of the housing running and jet tool 16 to a top thread of the drill pipe 18.
- the jetting tool 20 may then be attached to the drill pipe 18 by, for example, connecting a bottom thread of the drill pipe 18 with a top thread of the jetting tool 20.
- the casing string 14 is also connected to the low pressure housing 12, and is configured so its bottom end is a predetermined distance D from the bottom end 22 of the jetting tool 20, as discussed above.
- the jetting assembly 10 remains connected to the drilling vessel 26 by a drill pipe (not shown) which extends upwardly through the marine riser 28 from the jetting assembly 10 to the drilling vessel 26.
- the fluid to be ejected by the jetting tool 20 is delivered to the jetting tool 20 from the drilling vessel 26 via the drill pipe 18.
- Fig. 4 shows one known method of verifying such a vertical orientation that includes an analog inclination measuring device 34 attached to the jetting assembly 10.
- an analog inclination 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 analog inclination measuring device 34 is attached to or formed integrally with, the housing running and jet tool 16.
- 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 the ROV 36 can only read the analog inclination measuring device 34 from close proximity, as shown in Fig. 4. During the actual jetting operation, however, the ROV 36 must be positioned relatively far away from the jetting assembly 10 so as not to interfere with operations.
- ROV remotely operated vehicle
- a better way to measure the inclination of the jetting assembly 10 is through the use of an electrical inclination sensor 38, as shown in Figs. 5A and 5B.
- an electrical inclination sensor 38 is disclosed in U.S. Patent No. 4,937,518, which is hereby incorporated by reference herein.
- the electrical inclination sensor 38 is attached to the jetting assembly 10, and is configured to send an inclination signal to an operator on the drilling vessel 26 in real time.
- the electrical inclination sensor 38 may be attached to the stem 21 of the housing running and jet tool 16.
- the electrical inclination sensor 38 may be attached to the low pressure housing 12 (as shown in Fig. 7).
- the real time transmission of inclination data from the jetting assembly 10 to an operator on the drilling vessel 26 is advantageous because it eliminates the need to stop jetting between each jetting iteration to allow the ROV 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 the drilling vessel 26 can be accomplished in at least two different ways.
- the data signal from the electrical inclination sensor 38 can be sent via mud pulse transmission (shown in Fig. 6) or acoustic data transmission (shown in Fig. 7).
- the data signal is transmitted from the electrical inclination sensor 38 by a transmitter 40, and received by a receiver 42.
- the electrical inclination sensor 38 may be attached to the stem 21 of the housing running and jet tool 16.
- the transmitter 40 may also be attached to the stem 21 of the housing running and jet tool 16, and may be connected to the electrical inclination sensor 38 by a wire (not shown).
- the receptor stem 44 may be attached to the drill pipe 18 by engaging a top thread of the drill pipe 18 with a corresponding bottom thread of the receptor stem 44.
- a receiver 42 is attached to the receptor stem 44 and in communication with a display 46 that is viewable by an operator.
- the electrical inclination sensor 38 determines the inclination of the stem 21 of the housing running and jet tool 16, which corresponds to the inclination of the entire drill assembly 10.
- the inclination sensor 38 then communicates the inclination data to the transmitter 40.
- the transmitter 40 transmits an inclination data signal upward in a pulse through the mud surrounding the stem 21 and the drill pipe 18 to the receptor stem 44.
- the receiver 42 receives the signal, and communicates the inclination data to the display 46.
- the inclination data is generated constantly by the electrical inclination sensor 38 and transmitted in real time to the receiver 42.
- the operator receives continuous real time data about the inclination of the drill assembly 10 throughout the primary jetting process.
- the electrical inclination sensor 38 is attached to an outer face of the low pressure housing member 12.
- the transmitter 40 is attached to the outer surface of the low pressure housing member 12, and is connected to the electrical inclination sensor 38 by a wire (not shown).
- Receiver 42 is positioned near the drilling vessel 26 (shown as a floating platform in Fig. 7), and is connected to a display 46 (shown in Fig. 6) that is viewable by an operator.
- the electrical inclination sensor 38 senses an inclination of the low pressure housing 12, which corresponds to the inclination of the entire drill assembly 10.
- the inclination sensor 38 then communicates the inclination data to the transmitter 40, which transmits an inclination data signal into the surrounding sea water that is received by receiver 42.
- the receiver 42 Based on the received signal, the receiver 42 communicates the inclination data to the display 46.
- the inclination data is generated constantly by the electrical inclination sensor 38 and transmitted in real time to the receiver 42.
- the operator receives continuous real time data about the inclination of the drill assembly 10 throughout the primary jetting process.
- the receiver 42 is submerged in the sea water proximate the vessel so that it can better intercept the acoustic signals transmitted by the transmitter 40.
- 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 the receiver 42 by, for example, sounding an alarm, sending a message, or sending control signals to automatically or semi-automatically control the equipment.
- the analysis device or system could be located near the receiver 42 or remote from the receiver 42, such as, for example, at a distant location.
Abstract
Description
Claims
Priority Applications (3)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
SG11201509387YA SG11201509387YA (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 (2)
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 |
US13/904,873 | 2013-05-29 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2014193616A2 true WO2014193616A2 (en) | 2014-12-04 |
WO2014193616A3 WO2014193616A3 (en) | 2015-04-16 |
Family
ID=50943576
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/037054 WO2014193616A2 (en) | 2013-05-29 | 2014-05-07 | 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) |
Families Citing this family (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US10047598B1 (en) * | 2017-08-04 | 2018-08-14 | Onesubsea Ip Uk Limited | Subsea monitor system |
Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4937518A (en) | 1988-01-27 | 1990-06-26 | Marelli Autronica S.P.A. | Electrical inclination sensor and a monitoring circuit for the sensor |
Family Cites Families (16)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
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 |
US6075462A (en) * | 1997-11-24 | 2000-06-13 | Smith; Harrison C. | Adjacent well electromagnetic telemetry system and method for use of the same |
US6018501A (en) * | 1997-12-10 | 2000-01-25 | Halliburton Energy Services, Inc. | Subsea repeater and method for use of the same |
GB9914786D0 (en) * | 1999-06-25 | 1999-08-25 | Xl Technology Limited | Seabed analysis |
US7334650B2 (en) * | 2000-04-13 | 2008-02-26 | Weatherford/Lamb, Inc. | Apparatus and methods for drilling a wellbore using casing |
WO2003074836A1 (en) * | 2002-03-01 | 2003-09-12 | Head Philip | Conductor system |
FR2840951B1 (en) * | 2002-06-13 | 2004-12-24 | Inst Francais Du Petrole | INSTRUMENTATION ASSEMBLY OF AN OFFSHORE DRILLING RISER |
GB2428099B (en) * | 2004-03-22 | 2008-05-07 | Vetco Aibel As | A method and a device for monitoring and/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 |
GB2424432B (en) * | 2005-02-28 | 2010-03-17 | Weatherford Lamb | Deep water drilling with casing |
DE102006002838B3 (en) * | 2006-01-20 | 2007-09-13 | Gud Geotechnik Und Dynamik Consult Gmbh | Jet spray column producing and measuring device, has measuring device measuring diameter of jet spray column and partially integrated in drill and jet rods, where drill and jet rods produce bore hole |
EP2516788A1 (en) * | 2009-12-23 | 2012-10-31 | Shell Internationale Research Maatschappij B.V. | Method of drilling and jet drilling system |
NO333844B1 (en) * | 2010-11-09 | 2013-09-30 | Agr Subsea As | A method for establishing a borehole in a seabed and a conductor pipe and a suction module for carrying out the method |
CA2770979A1 (en) * | 2012-03-08 | 2013-09-08 | Cathedral Energy Services Ltd. | Method for transmission of data from a downhole sensor array |
-
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
Patent Citations (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US4937518A (en) | 1988-01-27 | 1990-06-26 | Marelli Autronica S.P.A. | Electrical inclination sensor and a monitoring circuit for the sensor |
Also Published As
Publication number | Publication date |
---|---|
BR112015028445A2 (en) | 2017-07-25 |
SG11201509387YA (en) | 2015-12-30 |
WO2014193616A3 (en) | 2015-04-16 |
US20140353036A1 (en) | 2014-12-04 |
NO20151502A1 (en) | 2015-11-06 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US9759037B2 (en) | Method for monitoring cement plugs | |
US9494033B2 (en) | Apparatus and method for kick detection using acoustic sensors | |
US6640900B2 (en) | Method and apparatus to monitor, control and log subsea oil and gas wells | |
US4273212A (en) | Oil and gas well kick detector | |
US6820008B1 (en) | System and method for measuring deep sea currents | |
AU2009343308B2 (en) | Apparatus and method for evaluating a wellbore, in particular a casing thereof | |
CA2998330C (en) | Mitigation of cable damage during perforation | |
US20040129424A1 (en) | Instrumentation for a downhole deployment valve | |
AU2002324484A1 (en) | Method and apparatus to monitor, control and log subsea oil and gas wells | |
US8511388B2 (en) | Devices and methods for transmitting EDS back-up signals to subsea pods | |
US7273105B2 (en) | Monitoring of a reservoir | |
US7305305B2 (en) | System and method for remotely controlling logging equipment in drilled holes | |
CN107780849B (en) | Marine riser cellular system, well system and the method for well system | |
US20140353036A1 (en) | Apparatus and Method for Measuring Inclination in Subsea Running, Setting, and Testing Tools | |
CN105804725B (en) | Petroleum underground non-contact ultrasonic liquid level monitoring system | |
US10718209B2 (en) | Single packer inlet configurations | |
US9404347B1 (en) | Apparatus and method for connecting a riser from an offshore rig to a subsea structure | |
GB2444195A (en) | Instrumentation for downhole deployment valve | |
NO325551B1 (en) | Method and system for remote control of logging equipment in a borehole | |
NO325858B1 (en) | Borehole logging system and method for remote control |
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: 14730670 Country of ref document: EP Kind code of ref document: A2 |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112015028445 Country of ref document: BR |
|
122 | Ep: pct application non-entry in european phase |
Ref document number: 14730670 Country of ref document: EP Kind code of ref document: A2 |
|
ENP | Entry into the national phase |
Ref document number: 112015028445 Country of ref document: BR Kind code of ref document: A2 Effective date: 20151112 |