US20220298874A1 - Side saddle rig design with integrated mpd - Google Patents
Side saddle rig design with integrated mpd Download PDFInfo
- Publication number
- US20220298874A1 US20220298874A1 US17/693,949 US202217693949A US2022298874A1 US 20220298874 A1 US20220298874 A1 US 20220298874A1 US 202217693949 A US202217693949 A US 202217693949A US 2022298874 A1 US2022298874 A1 US 2022298874A1
- Authority
- US
- United States
- Prior art keywords
- mpd
- coupled
- drilling rig
- wellbore
- manifold
- 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.)
- Pending
Links
- 238000005553 drilling Methods 0.000 claims abstract description 79
- 238000000034 method Methods 0.000 claims description 6
- 230000008878 coupling Effects 0.000 claims description 2
- 238000010168 coupling process Methods 0.000 claims description 2
- 238000005859 coupling reaction Methods 0.000 claims description 2
- 239000012530 fluid Substances 0.000 description 16
- 239000007789 gas Substances 0.000 description 8
- 230000008901 benefit Effects 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 230000004075 alteration Effects 0.000 description 1
- 230000015572 biosynthetic process Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 230000001934 delay Effects 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- 238000006467 substitution reaction Methods 0.000 description 1
Images
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/08—Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/08—Wipers; Oil savers
- E21B33/085—Rotatable packing means, e.g. rotating blow-out preventers
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B15/00—Supports for the drilling machine, e.g. derricks or masts
- E21B15/003—Supports for the drilling machine, e.g. derricks or masts adapted to be moved on their substructure, e.g. with skidding means; adapted to drill a plurality of wells
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B21/00—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
- E21B21/10—Valve arrangements in drilling-fluid circulation systems
- E21B21/106—Valve arrangements outside the borehole, e.g. kelly valves
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/02—Surface sealing or packing
- E21B33/03—Well heads; Setting-up thereof
- E21B33/06—Blow-out preventers, i.e. apparatus closing around a drill pipe, e.g. annular blow-out preventers
Definitions
- the present disclosure relates to the drilling of wells, and specifically to a drilling rig system for use in a wellsite.
- Drilling rigs may be configured to be traveled from location to location to drill multiple wells within the same area known as a wellsite. In certain situations, it may be desirable to travel across an already drilled well for which there is a well-head in place. Further, mast placement on land-drilling rigs may have an effect on drilling activity. For example, depending on mast placement on the drilling rig, an existing well-head may interfere with the location of land-situated equipment such as, for instance, existing wellheads, and may also interfere with raising and lowering of equipment needed for operations. Managed pressure drilling involves the regulation of the annulus pressure of a wellbore being drilled to reduce unwanted flow of fluid into and out of the wellbore from the formation.
- the present disclosure provides for a drilling rig.
- the drilling rig may include a drill rig floor and a substructure.
- the drilling rig may include a managed pressure drilling (MPD) manifold positioned on the drill rig floor or coupled to the substructure.
- the drilling rig may include a rotating control device (RCD) coupled to a blowout preventer (BOP), the BOP coupled to a wellbore.
- the drilling rig may include a flowline coupled to the RCD.
- the drilling rig may include an MPD line coupled to the BOP, the MPD line fluidly coupled between the annulus of the wellbore and the MPD manifold.
- the drilling rig may include an MPD outlet line, the MPD outlet line fluidly coupled between the MPD manifold and the flowline.
- the present disclosure also provides for a method.
- the method may include positioning a drilling rig in a wellsite at a first location aligned with a first wellbore.
- the drilling rig may include a drill rig floor and a substructure.
- the drilling rig may include a managed pressure drilling (MPD) manifold positioned on the drill rig floor or coupled to the substructure.
- the drilling rig may include a rotating control device (RCD) coupled to a blowout preventer (BOP), the BOP coupled to a wellbore.
- the drilling rig may include a flowline coupled to the RCD.
- the drilling rig may include an MPD line coupled to the BOP, the MPD line fluidly coupled between the annulus of the wellbore and the MPD manifold.
- the drilling rig may include an MPD outlet line, the MPD outlet line fluidly coupled between the MPD manifold and the flowline.
- the method may include disconnecting the BOP from the first wellbore; traveling the drilling rig to a second location in the wellsite aligned with a second wellbore; and coupling the BOP to the second wellbore.
- FIG. 1 depicts a side elevation view of a drilling rig consistent with at least one embodiment of the present disclosure.
- FIG. 2 depicts a side elevation view of the drilling rig of FIG. 1 from the other side of the drilling rig.
- FIG. 3 depicts a partial side elevation view of the drilling rig of FIG. 1 .
- FIG. 4 depicts a top view of the drilling rig of FIG. 1 .
- FIGS. 1-4 depict drilling rig 10 consistent with at least one embodiment of the present disclosure.
- Drilling rig 10 may include drill rig floor 20 , right substructure 30 , and left substructure 40 .
- Right and left substructures 30 , 40 may support drill rig floor 20 .
- Mast 50 may be mechanically coupled to one or both of right and left substructures 30 , 40 or drill rig floor 20 .
- the terms “right” and “left” as used herein are used only to refer to each separate substructure to simplify discussion and are not intended to limit this disclosure in any way.
- drill rig floor 20 may include V-door 23 , defining a V-door side of drill rig floor 20 and V-door side 22 of drilling rig 10 .
- drill rig 10 may be a side-saddle drilling rig such that V-door 23 and V-door side 22 may be located over right substructure 30 .
- V-door side 52 of mast 50 may correspondingly face right substructure 30 .
- equipment and structures that pass through the V-door 23 or to drill rig floor 20 from V-door side 22 of drilling rig 10 may, for example, be less likely to interfere with additional wells in the well field.
- V-door side 22 and mast V-door side may face left substructure 40 .
- drilling rig 10 may be centered over wellbore 12 .
- drilling rig 10 may include integrated managed pressure drilling (MPD) system 100 .
- MPD system 100 may be used, for example and without limitation, to allow wellbore 12 to be drilled using managed pressure techniques such that integrated MPD system 100 controls annulus pressure of wellbore 12 .
- integrated MPD system 100 may be used to maintain the pressure within wellbore 12 during make up or break-out operations when employed with, for example and without limitation, a check valve at a drill bit of a drill string used with drilling rig 10 .
- Components of integrated MPD system 100 may be coupled to or positioned on drilling rig 10 such that integrated MPD system 100 may travel with drilling rig 10 during a travel operation such as a skidding operation or a walking operation to move drilling rig 10 from a first location in a wellsite aligned with a first wellbore to a second location in a wellsite aligned with a second wellbore or during a transport operation.
- a travel operation such as a skidding operation or a walking operation to move drilling rig 10 from a first location in a wellsite aligned with a first wellbore to a second location in a wellsite aligned with a second wellbore or during a transport operation.
- integrated MPD system 100 may include rotating control device (RCD) 101 .
- RCD 101 may be operatively coupled to blowout preventer (BOP) 103 .
- BOP 103 may be mechanically and fluidly coupled to wellbore 12 .
- RCD 101 may operate to allow a drill string to pass through BOP 103 while maintaining a sealed fluid connection with the annulus of wellbore 12 and a drill string positioned within wellbore 12 .
- RCD 101 may include output port 105 fluidly coupled to flowline 107 .
- Flowline 107 may be used to return drilling fluid within the annulus of wellbore 12 to mud handling equipment when wellbore 12 is drilled outside of a managed pressure drilling operation.
- flowline 107 may be coupled to RCD 101 via flowline valve 109 .
- Flowline valve 109 may be closed during MPD operations and opened during non-MPD operations.
- Flowline valve 109 may, in some embodiments, be a gate valve, ball valve, or orbit valve.
- integrated MPD system 100 may include MPD line 111 .
- MPD line 111 is fluidly coupled to the annulus of wellbore 12 through MPD port 113 formed in RCD 101 or other component of BOP 103 .
- MPD port 113 may be formed in spool 115 of BOP 103 .
- MPD port 113 may allow for fluid returning through the annulus of wellbore 12 to be diverted from flowline 107 to integrated MPD system 100 via MPD line 111 as discussed below when flowline valve 109 is closed and subsequent valve 110 is opened.
- Subsequent valve 110 may be, in some embodiments, a gate valve, ball valve, or orbit valve.
- MPD line 111 may be coupled to subsequent valve 110 to provide a fluid conduit for fluid to pass from wellbore 12 to MPD manifold 117 .
- MPD manifold 117 may be a choke manifold used to manage the pressure of the annulus of wellbore 12 through the use of one or more valves 119 as shown in FIGS. 3, 4 .
- MPD manifold 117 may be positioned on drill rig floor 20 such that MPD manifold 117 travels with drilling rig 10 .
- MPD manifold 117 may fluidly couple to
- Coriolis meter 123 may be used to measure the mass flow rate and density of the drilling fluid flowing through integrated MPD system 100 to, for example and without limitation, identify kicks and to provide feedback for the control of integrated MPD system 100 .
- one or more valves may be positioned to allow fluid flowing through MPD manifold 117 to bypass Coriolis meter 123 .
- MPD manifold 117 may be fluidly coupled to mud gas separator 121 .
- Mud gas separator 121 may be mechanically coupled to drilling rig 10 such that mud gas separator 121 travels with drilling rig 10 .
- Mud gas separator 121 may be used to separate drilling fluid from gases entrained with the drilling fluid returning from wellbore 12 .
- one or more valves may be positioned to allow fluid flowing through MPD manifold 117 to bypass mud gas separator 121 .
- the drilling fluid may flow through MPD outlet line 125 , which may be fluidly coupled to flowline 107 to allow the drilling fluid to pass to other mud handling equipment which may be positioned on drilling rig 10 or at a location proximate drilling rig 10 .
- the components of integrated MPD system 100 may remain coupled to drilling rig 10 throughout any traveling operations such as skidding or walking operations and, in some embodiments, transport operations.
- the fluid connections of integrated MPD system 100 including, for example and without limitation, the connection of MPD line 111 to BOP 103 or RCD 101 , the connection of MPD line 111 to MPD manifold 117 , the connection of MPD manifold 117 to Coriolis meter 123 , the connection of MPD manifold 117 to mud gas separator 121 , the connection of MPD manifold 117 and Coriolis meter 123 to MPD outlet line 125 , and the fluid connections between flowline 107 and MPD outlet line 125 and RCD 101 , may be maintained throughout such traveling or transport operations.
- such connections need not be rigged down and up for each travel and transport operation, reducing the time required to prepare for transport of drilling rig 10 and reducing delays in beginning operations after the move.
- integrated MPD system 100 may include MPD controller 127 .
- MPD controller 127 may be positioned on drill rig floor 20 and may be used to control operation of integrated MPD system 100 .
- MPD controller 127 may, in some embodiments, control the pressure of the annulus of wellbore 12 based at least in part on measurements of Coriolis meter 123 and other sensors by manipulating one or more valves 119 of integrated MPD system 100 .
Landscapes
- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mechanical Engineering (AREA)
- Earth Drilling (AREA)
- Joints Allowing Movement (AREA)
Abstract
Description
- This application is a nonprovisional application which claims priority from U.S. provisional application No. 63/161,671, filed Mar. 16, 2021, which is incorporated by reference herein in its entirety.
- The present disclosure relates to the drilling of wells, and specifically to a drilling rig system for use in a wellsite.
- Drilling rigs may be configured to be traveled from location to location to drill multiple wells within the same area known as a wellsite. In certain situations, it may be desirable to travel across an already drilled well for which there is a well-head in place. Further, mast placement on land-drilling rigs may have an effect on drilling activity. For example, depending on mast placement on the drilling rig, an existing well-head may interfere with the location of land-situated equipment such as, for instance, existing wellheads, and may also interfere with raising and lowering of equipment needed for operations. Managed pressure drilling involves the regulation of the annulus pressure of a wellbore being drilled to reduce unwanted flow of fluid into and out of the wellbore from the formation.
- The present disclosure provides for a drilling rig. The drilling rig may include a drill rig floor and a substructure. The drilling rig may include a managed pressure drilling (MPD) manifold positioned on the drill rig floor or coupled to the substructure. The drilling rig may include a rotating control device (RCD) coupled to a blowout preventer (BOP), the BOP coupled to a wellbore. The drilling rig may include a flowline coupled to the RCD. The drilling rig may include an MPD line coupled to the BOP, the MPD line fluidly coupled between the annulus of the wellbore and the MPD manifold. The drilling rig may include an MPD outlet line, the MPD outlet line fluidly coupled between the MPD manifold and the flowline.
- The present disclosure also provides for a method. The method may include positioning a drilling rig in a wellsite at a first location aligned with a first wellbore. The drilling rig may include a drill rig floor and a substructure. The drilling rig may include a managed pressure drilling (MPD) manifold positioned on the drill rig floor or coupled to the substructure. The drilling rig may include a rotating control device (RCD) coupled to a blowout preventer (BOP), the BOP coupled to a wellbore. The drilling rig may include a flowline coupled to the RCD. The drilling rig may include an MPD line coupled to the BOP, the MPD line fluidly coupled between the annulus of the wellbore and the MPD manifold. The drilling rig may include an MPD outlet line, the MPD outlet line fluidly coupled between the MPD manifold and the flowline. The method may include disconnecting the BOP from the first wellbore; traveling the drilling rig to a second location in the wellsite aligned with a second wellbore; and coupling the BOP to the second wellbore.
- The present disclosure is best understood from the following detailed description when read with the accompanying figures. It is emphasized that, in accordance with the standard practice in the industry, various features are not drawn to scale. In fact, the dimensions of the various features may be arbitrarily increased or reduced for clarity of discussion.
-
FIG. 1 depicts a side elevation view of a drilling rig consistent with at least one embodiment of the present disclosure. -
FIG. 2 depicts a side elevation view of the drilling rig ofFIG. 1 from the other side of the drilling rig. -
FIG. 3 depicts a partial side elevation view of the drilling rig ofFIG. 1 . -
FIG. 4 depicts a top view of the drilling rig ofFIG. 1 . - It is to be understood that the following disclosure provides many different embodiments, or examples, for implementing different features of various embodiments. Specific examples of components and arrangements are described below to simplify the present disclosure. These are, of course, merely examples and are not intended to be limiting. In addition, the present disclosure may repeat reference numerals and/or letters in the various examples. This repetition is for the purpose of simplicity and clarity and does not in itself dictate a relationship between the various embodiments and/or configurations discussed.
-
FIGS. 1-4 depictdrilling rig 10 consistent with at least one embodiment of the present disclosure. Drillingrig 10 may includedrill rig floor 20,right substructure 30, andleft substructure 40. Right andleft substructures drill rig floor 20.Mast 50 may be mechanically coupled to one or both of right andleft substructures drill rig floor 20. As would be understood by one having ordinary skill in the art with the benefit of this disclosure, the terms “right” and “left” as used herein are used only to refer to each separate substructure to simplify discussion and are not intended to limit this disclosure in any way. In some embodiments,drill rig floor 20 may include V-door 23, defining a V-door side ofdrill rig floor 20 and V-door side 22 ofdrilling rig 10. In some embodiments,drill rig 10 may be a side-saddle drilling rig such that V-door 23 and V-door side 22 may be located overright substructure 30. V-door side 52 ofmast 50 may correspondingly faceright substructure 30. By facing V-door side 22 of drillingrig 10 toward one of thesubstructures door 23 or to drillrig floor 20 from V-door side 22 of drillingrig 10 may, for example, be less likely to interfere with additional wells in the well field. In other embodiments, V-door side 22 and mast V-door side may faceleft substructure 40. In some embodiments, as depicted inFIG. 1 , drillingrig 10 may be centered overwellbore 12. - In some embodiments, drilling
rig 10 may include integrated managed pressure drilling (MPD)system 100.Integrated MPD system 100 may be used, for example and without limitation, to allowwellbore 12 to be drilled using managed pressure techniques such that integratedMPD system 100 controls annulus pressure ofwellbore 12. In some embodiments, integratedMPD system 100 may be used to maintain the pressure withinwellbore 12 during make up or break-out operations when employed with, for example and without limitation, a check valve at a drill bit of a drill string used withdrilling rig 10. Components of integratedMPD system 100 may be coupled to or positioned ondrilling rig 10 such that integratedMPD system 100 may travel with drillingrig 10 during a travel operation such as a skidding operation or a walking operation to move drillingrig 10 from a first location in a wellsite aligned with a first wellbore to a second location in a wellsite aligned with a second wellbore or during a transport operation. - With reference to
FIG. 1 , in some embodiments, integratedMPD system 100 may include rotating control device (RCD) 101. RCD 101 may be operatively coupled to blowout preventer (BOP) 103.BOP 103 may be mechanically and fluidly coupled towellbore 12. RCD 101 may operate to allow a drill string to pass throughBOP 103 while maintaining a sealed fluid connection with the annulus ofwellbore 12 and a drill string positioned withinwellbore 12. RCD 101 may includeoutput port 105 fluidly coupled toflowline 107. Flowline 107 may be used to return drilling fluid within the annulus ofwellbore 12 to mud handling equipment whenwellbore 12 is drilled outside of a managed pressure drilling operation. In some embodiments,flowline 107 may be coupled to RCD 101 viaflowline valve 109.Flowline valve 109 may be closed during MPD operations and opened during non-MPD operations.Flowline valve 109 may, in some embodiments, be a gate valve, ball valve, or orbit valve. - In some embodiments,
integrated MPD system 100 may includeMPD line 111.MPD line 111 is fluidly coupled to the annulus ofwellbore 12 throughMPD port 113 formed inRCD 101 or other component ofBOP 103. In some embodiments,MPD port 113 may be formed inspool 115 ofBOP 103.MPD port 113 may allow for fluid returning through the annulus ofwellbore 12 to be diverted fromflowline 107 tointegrated MPD system 100 viaMPD line 111 as discussed below whenflowline valve 109 is closed andsubsequent valve 110 is opened.Subsequent valve 110 may be, in some embodiments, a gate valve, ball valve, or orbit valve. -
MPD line 111 may be coupled tosubsequent valve 110 to provide a fluid conduit for fluid to pass from wellbore 12 toMPD manifold 117.MPD manifold 117 may be a choke manifold used to manage the pressure of the annulus ofwellbore 12 through the use of one ormore valves 119 as shown inFIGS. 3, 4 . In some embodiments,MPD manifold 117 may be positioned ondrill rig floor 20 such that MPD manifold 117 travels withdrilling rig 10. - In some embodiments, as shown in
FIG. 3 ,MPD manifold 117 may fluidly couple to -
Coriolis meter 123.Coriolis meter 123 may be used to measure the mass flow rate and density of the drilling fluid flowing throughintegrated MPD system 100 to, for example and without limitation, identify kicks and to provide feedback for the control ofintegrated MPD system 100. In some embodiments, one or more valves may be positioned to allow fluid flowing through MPD manifold 117 to bypassCoriolis meter 123. - In some embodiments, as shown in
FIG. 1 ,MPD manifold 117 may be fluidly coupled tomud gas separator 121.Mud gas separator 121 may be mechanically coupled todrilling rig 10 such thatmud gas separator 121 travels withdrilling rig 10.Mud gas separator 121 may be used to separate drilling fluid from gases entrained with the drilling fluid returning fromwellbore 12. In some embodiments, one or more valves may be positioned to allow fluid flowing through MPD manifold 117 to bypassmud gas separator 121. - Once the drilling fluid flows through
MPD manifold 117 and, if desired,Coriolis meter 123 ormud gas separator 121, the drilling fluid may flow throughMPD outlet line 125, which may be fluidly coupled toflowline 107 to allow the drilling fluid to pass to other mud handling equipment which may be positioned ondrilling rig 10 or at a locationproximate drilling rig 10. - In some embodiments, the components of
integrated MPD system 100 may remain coupled todrilling rig 10 throughout any traveling operations such as skidding or walking operations and, in some embodiments, transport operations. In such embodiments, the fluid connections ofintegrated MPD system 100 including, for example and without limitation, the connection ofMPD line 111 toBOP 103 orRCD 101, the connection ofMPD line 111 toMPD manifold 117, the connection of MPD manifold 117 toCoriolis meter 123, the connection of MPD manifold 117 tomud gas separator 121, the connection ofMPD manifold 117 andCoriolis meter 123 toMPD outlet line 125, and the fluid connections betweenflowline 107 andMPD outlet line 125 andRCD 101, may be maintained throughout such traveling or transport operations. In such embodiments, such connections need not be rigged down and up for each travel and transport operation, reducing the time required to prepare for transport ofdrilling rig 10 and reducing delays in beginning operations after the move. - In some embodiments,
integrated MPD system 100 may includeMPD controller 127.MPD controller 127 may be positioned ondrill rig floor 20 and may be used to control operation ofintegrated MPD system 100.MPD controller 127 may, in some embodiments, control the pressure of the annulus ofwellbore 12 based at least in part on measurements ofCoriolis meter 123 and other sensors by manipulating one ormore valves 119 ofintegrated MPD system 100. - The foregoing outlines features of several embodiments so that a person of ordinary skill in the art may better understand the aspects of the present disclosure. Such features may be replaced by any one of numerous equivalent alternatives, only some of which are disclosed herein. One of ordinary skill in the art should appreciate that they may readily use the present disclosure as a basis for designing or modifying other processes and structures for carrying out the same purposes and/or achieving the same advantages of the embodiments introduced herein. One of ordinary skill in the art should also realize that such equivalent constructions do not depart from the spirit and scope of the present disclosure and that they may make various changes, substitutions, and alterations herein without departing from the spirit and scope of the present disclosure.
Claims (9)
Priority Applications (1)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US17/693,949 US20220298874A1 (en) | 2021-03-16 | 2022-03-14 | Side saddle rig design with integrated mpd |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US202163161671P | 2021-03-16 | 2021-03-16 | |
US17/693,949 US20220298874A1 (en) | 2021-03-16 | 2022-03-14 | Side saddle rig design with integrated mpd |
Publications (1)
Publication Number | Publication Date |
---|---|
US20220298874A1 true US20220298874A1 (en) | 2022-09-22 |
Family
ID=83271830
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US17/693,949 Pending US20220298874A1 (en) | 2021-03-16 | 2022-03-14 | Side saddle rig design with integrated mpd |
Country Status (3)
Country | Link |
---|---|
US (1) | US20220298874A1 (en) |
AR (1) | AR125548A1 (en) |
CA (1) | CA3152650A1 (en) |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11873685B2 (en) | 2020-09-01 | 2024-01-16 | Nabors Drilling Technologies Usa, Inc. | Side saddle traversable drilling rig |
US12054993B2 (en) | 2021-03-16 | 2024-08-06 | Nabors Drilling Technologies Usa, Inc. | Side saddle rig design with retractable top drive |
Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20150090450A1 (en) * | 2013-09-30 | 2015-04-02 | National Oilwell Varco, L.P. | Performing simultaneous operations on multiple wellbore locations using a single mobile drilling rig |
US20160326817A1 (en) * | 2015-05-06 | 2016-11-10 | Schlumberger Technology Corporation | Continuous mud circulation during drilling operations |
US20170159372A1 (en) * | 2015-12-04 | 2017-06-08 | Schlumberger Technology Corporation | Rig positioning system |
US10094186B2 (en) * | 2014-11-17 | 2018-10-09 | Weatherford Technology Holdings, Llc | Controlled pressure drilling system with flow measurement and well control |
US10214970B1 (en) * | 2018-06-12 | 2019-02-26 | Nabors Drilling Technologies Usa, Inc. | Post and non-elongated substructure drilling rig |
US20190338600A1 (en) * | 2018-05-03 | 2019-11-07 | Nabors Drilling Technologies Usa, Inc. | Multi-direction traversable drilling rig |
US20200190939A1 (en) * | 2018-12-17 | 2020-06-18 | Weatherford Technology Holdings, Llc | Fault-Tolerant Pressure Relief System for Drilling |
-
2022
- 2022-03-14 US US17/693,949 patent/US20220298874A1/en active Pending
- 2022-03-16 AR ARP220100610A patent/AR125548A1/en unknown
- 2022-03-16 CA CA3152650A patent/CA3152650A1/en active Pending
Patent Citations (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20150090450A1 (en) * | 2013-09-30 | 2015-04-02 | National Oilwell Varco, L.P. | Performing simultaneous operations on multiple wellbore locations using a single mobile drilling rig |
US10094186B2 (en) * | 2014-11-17 | 2018-10-09 | Weatherford Technology Holdings, Llc | Controlled pressure drilling system with flow measurement and well control |
US20160326817A1 (en) * | 2015-05-06 | 2016-11-10 | Schlumberger Technology Corporation | Continuous mud circulation during drilling operations |
US20170159372A1 (en) * | 2015-12-04 | 2017-06-08 | Schlumberger Technology Corporation | Rig positioning system |
US20190338600A1 (en) * | 2018-05-03 | 2019-11-07 | Nabors Drilling Technologies Usa, Inc. | Multi-direction traversable drilling rig |
US10214970B1 (en) * | 2018-06-12 | 2019-02-26 | Nabors Drilling Technologies Usa, Inc. | Post and non-elongated substructure drilling rig |
US20200190939A1 (en) * | 2018-12-17 | 2020-06-18 | Weatherford Technology Holdings, Llc | Fault-Tolerant Pressure Relief System for Drilling |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US11873685B2 (en) | 2020-09-01 | 2024-01-16 | Nabors Drilling Technologies Usa, Inc. | Side saddle traversable drilling rig |
US12054993B2 (en) | 2021-03-16 | 2024-08-06 | Nabors Drilling Technologies Usa, Inc. | Side saddle rig design with retractable top drive |
Also Published As
Publication number | Publication date |
---|---|
AR125548A1 (en) | 2023-07-26 |
CA3152650A1 (en) | 2022-09-16 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US20220298874A1 (en) | Side saddle rig design with integrated mpd | |
US8176985B2 (en) | Well drilling and production using a surface blowout preventer | |
US10221631B2 (en) | Side saddle substructure | |
US8978774B2 (en) | System and method for drilling a subsea well | |
US10808483B2 (en) | System for hydrocarbon recovery | |
US8387705B2 (en) | Systems and methods for running casing into wells drilled with dual-gradient mud systems | |
AU2013271559B2 (en) | Flow control system | |
US9057233B2 (en) | Boost system and method for dual gradient drilling | |
BR112020002864B1 (en) | APPARATUS THAT INCLUDES A TUBE AND METHOD THAT INCLUDES RETURNING THE MUD FROM A WELL INTO A RISER | |
US11634954B2 (en) | Surge reduction system for running liner casing in managed pressure drilling wells | |
WO2012140445A2 (en) | Subsea wellbore construction method and apparatus | |
US9267344B2 (en) | Actuator for dual drill string valve and drill string valve configurations therefore | |
WO2011043763A1 (en) | Well drilling method utilizing real time response to ahead of bit measurements | |
US9291011B2 (en) | Integral diverter system | |
US20210148192A1 (en) | Ball valve capping stack | |
US10683715B2 (en) | Proportional control of rig drilling mud flow | |
US10161244B2 (en) | System and methodology using annulus access valve | |
US20150041147A1 (en) | Oil well safety valve apparatus and method | |
US10364622B2 (en) | Manifold assembly for a mineral extraction system | |
US10590719B2 (en) | Manifold assembly for a mineral extraction system | |
US9664006B2 (en) | Riser isolation device having automatically operated annular seal | |
WO2022154666A1 (en) | A system and method for circulating drilling fluid in connection with open water drilling | |
US9556697B1 (en) | Wellhead system and method for installing a wellhead system | |
CA2859874C (en) | Oil well safety valve apparatus and method | |
US20150114663A1 (en) | Annular gas lift valve |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AS | Assignment |
Owner name: NABORS DRILLING TECHNOLOGIES USA, INC., TEXAS Free format text: ASSIGNMENT OF ASSIGNORS INTEREST;ASSIGNOR:PATTERSON, DEREK;REEL/FRAME:059462/0882 Effective date: 20220324 |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE TO NON-FINAL OFFICE ACTION ENTERED AND FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: FINAL REJECTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: RESPONSE TO NON-FINAL OFFICE ACTION ENTERED AND FORWARDED TO EXAMINER |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: FINAL REJECTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: ADVISORY ACTION MAILED |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: DOCKETED NEW CASE - READY FOR EXAMINATION |
|
STPP | Information on status: patent application and granting procedure in general |
Free format text: NON FINAL ACTION MAILED |