NO20161539A1 - Bearing assembly cooling methods - Google Patents
Bearing assembly cooling methods Download PDFInfo
- Publication number
- NO20161539A1 NO20161539A1 NO20161539A NO20161539A NO20161539A1 NO 20161539 A1 NO20161539 A1 NO 20161539A1 NO 20161539 A NO20161539 A NO 20161539A NO 20161539 A NO20161539 A NO 20161539A NO 20161539 A1 NO20161539 A1 NO 20161539A1
- Authority
- NO
- Norway
- Prior art keywords
- heat exchanger
- bearing assembly
- inner member
- carrier
- rcd
- Prior art date
Links
- 238000001816 cooling Methods 0.000 title claims description 17
- 239000012530 fluid Substances 0.000 claims description 28
- 239000002826 coolant Substances 0.000 claims description 22
- 238000000034 method Methods 0.000 claims description 17
- 239000011248 coating agent Substances 0.000 claims description 10
- 238000000576 coating method Methods 0.000 claims description 10
- 238000003825 pressing Methods 0.000 claims description 2
- 238000005524 ceramic coating Methods 0.000 claims 3
- 238000005553 drilling Methods 0.000 description 20
- 238000007789 sealing Methods 0.000 description 8
- 230000009467 reduction Effects 0.000 description 7
- 230000015572 biosynthetic process Effects 0.000 description 6
- 238000005755 formation reaction Methods 0.000 description 6
- 229920001971 elastomer Polymers 0.000 description 5
- 239000000314 lubricant Substances 0.000 description 4
- 239000005060 rubber Substances 0.000 description 4
- 239000007789 gas Substances 0.000 description 3
- 239000007788 liquid Substances 0.000 description 3
- 238000005461 lubrication Methods 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 230000008569 process Effects 0.000 description 3
- 238000007792 addition Methods 0.000 description 2
- 238000005520 cutting process Methods 0.000 description 2
- 230000002706 hydrostatic effect Effects 0.000 description 2
- 230000004941 influx Effects 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 239000003507 refrigerant Substances 0.000 description 2
- 229920001875 Ebonite Polymers 0.000 description 1
- 230000003044 adaptive effect Effects 0.000 description 1
- 230000015556 catabolic process Effects 0.000 description 1
- 239000000919 ceramic Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 230000001276 controlling effect Effects 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 230000003247 decreasing effect Effects 0.000 description 1
- 238000006731 degradation reaction Methods 0.000 description 1
- 239000000806 elastomer Substances 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 239000011152 fibreglass Substances 0.000 description 1
- 238000010438 heat treatment Methods 0.000 description 1
- 230000001050 lubricating effect Effects 0.000 description 1
- 239000000203 mixture Substances 0.000 description 1
- 230000001105 regulatory effect Effects 0.000 description 1
- 230000008439 repair process Effects 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 1
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
- 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
-
- 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
-
- 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
- E21B36/00—Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
- E21B36/001—Cooling arrangements
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E10/00—Energy generation through renewable energy sources
- Y02E10/10—Geothermal energy
Landscapes
- Geology (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Mining & Mineral Resources (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Physics & Mathematics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Mounting Of Bearings Or Others (AREA)
- Earth Drilling (AREA)
- Sliding-Contact Bearings (AREA)
- Support Of The Bearing (AREA)
- Rolling Contact Bearings (AREA)
Description
Bearing Assembly Cooling Methods
BACKGROUND
[0001] Technical Field: The subject matter generally relates to systems and techniques in the field of oil and gas operations. Reduction of heat in rotating control devices (RCDs) improves the life of such RCDs.
[0002] When a well site is completed, pressure control equipment may be placed near the surface of the earth. The pressure control equipment may control the pressure in the wellbore while drilling, completing and producing the wellbore. The pressure control equipment may include blowout preventers (BOP), rotating control devices (RCDs), and the like. The RCD is a drill-through device with a rotating seal that contacts and seals against the drill string (drill pipe with tool joints, casing, drill collars, Kelly, etc.) for the purposes of controlling the pressure or fluid flow to the surface.
[0003] RCDs and other pressure control equipment are used in underbalanced drilling (UBD) and managed pressure drilling (MPD), which are relatively new and improved drilling techniques, and work particularly well in certain offshore drilling environments. Both technologies are enabled by drilling with a closed and pressurizable circulating fluid system as compared to a drilling system that is open-to-atmosphere at the surface. Managed pressure drilling is an adaptive drilling process used to more precisely control the annular pressure profile throughout the wellbore. MPD addresses the drill-ability of a prospect, typically by being able to adjust the equivalent mud weight with the intent of staying within a "drilling window" to a deeper depth and reducing drilling non-productive time in the process. The drilling window changes with depth and is typically described as the equivalent mud weight required to drill between the formation pressure and the pressure at which an underground blowout or loss of circulation would occur. The equivalent weight of the mud and cuttings in the annulus is controlled with fewer interruptions to drilling progress while being kept above the formation pressure at all times. An influx of formation fluids is not invited to flow to the surface while drilling. Underbalanced drilling (UBD) is drilling with the hydrostatic head of the drilling fluid intentionally designed to be lower than the pressure of the formations being drilled, typically to improve the well's productivity upon completion by avoiding invasive mud and cuttings damage while drilling. An influx of formation fluids is therefore invited to flow to the surface while drilling. The hydrostatic head of the fluid may naturally be less than the formation pressure, or it can be induced.
[0004] The thrust generated by the wellbore fluid pressure, the radial forces on the bearing assembly within the RCD and other forces cause a substantial amount of heat to build in the conventional RCD. The heat causes the seals and bearings to wear and subsequently require repair. The conventional RCD typically requires an external cooling system that circulates fluid and utilizes various valves and hose through the seals and bearings in order to remove the heat. However, risers, used in many oilfield operations, particularly subsea operations, may pose significant obstacles to the use of external coolants, lubricants, lubricating systems and/or cooling systems.
[0005] Therefore, an improved system for cooling radial seals and the bearing section of an RCD is desired, particularly a system which is able to function in environments with or without an external control system. If the radial seals are not sufficiently cooled, the localized temperature at the sealing surface will rise until the temperature limitations of the seal material is reached and degradation of the radial seal begins. High pressure, velocity and temperature conditions at increasing lengths of time affect and reduce the length of usable life for a seal. In order to obtain sufficient life from radial seals, the rate of heat extraction should be fast enough to allow the temperature at the sealing surface to level off at a temperature lower than that of the seal material's upper limit.
[0006] US Pub. No. 2006/0144622 proposes a system and method for cooling a RCD while regulating the pressure on its upper radial seal. Gas, such as air, and liquid, such as oil, are alternatively proposed for use in a heat exchanger in the RCD. A hydraulic control system is proposed to provide fluid to energize a bladder of an active seal to seal around a drilling string and to lubricate the bearings in the RCD.
[0007] The above discussed U.S. Pub. No. US 2006/0144622 is incorporated herein by reference for all purposes in its entirety. The above referenced patent publication has been assigned to the assignee of the current invention.
BRIEFSUMMARY
[0008] The disclosure relates to apparatus and methods for cooling a RCD at a wellbore including a bearing assembly configured for operating in the RCD. A fixed latch with a heat exchanger system and a volume of a cooling medium is configured for reducing heat proximate the bearing assembly, an inner member, and one or more seals between the bearing assembly and the inner member.
[0009] As used herein the term "RCD" or "RCDs" and the phrases "pressure control equipment", "pressure control apparatus" or "pressure control device(s)" shall refer to well related pressure control equipment/apparatus/device(s) including, but not limited to, rotating-control-device(s), active rotating control devices, blowout preventers (BOPs), and the like.
BRIEF DESCRIPTION OF THE FIGURES
[0010] The exemplary embodiments may be better understood, and numerous objects, features, and advantages made apparent to those skilled in the art by referencing the accompanying drawings. These drawings are used to illustrate only typical exemplary embodiments of this invention, and are not to be considered limiting of its scope, for the invention may admit to other equally effective exemplary embodiments. The figures are not necessarily to scale and certain features and certain views of the figures may be shown exaggerated in scale or in schematic in the interest of clarity and conciseness.
[0011] Figure 1 depicts a schematic view of a well site håving pressure control devices for sealing an item or piece of oilfield equipment. Figure 2 depicts a cross sectional view of a pressure control device embodiment håving a fixed latch with a heat exchanger therein and a heat exchanger system. Figure 3 depicts a cross sectional view of half of a pressure control device embodiment håving a carrier håving a pressure reduction system and a heat exchanger profile.
DETAILED DESCRIPTION OF THE EXEMPLARY EMBODIMENT(S)
[0012] The description that follows includes exemplary apparatus, methods, techniques, and instruction sequences that embody techniques of the inventive subject matter. However, it is understood that the described exemplary embodiments may be practiced without these specific details.
[0013] Figure 1 depicts a schematic view of a well site 100 håving pressure control devices 102 for sealing a rotating drill string or other piece of oilfield equipment 122. The well site 100 may have a wellbore 106 formed in the earth and lined with a casing 108. At the Earth's surface or sea floor 110 (see, for example, US publication no, 2014/0027129 Figs. 1, 1A and 1B and accompanying description depicting exemplary schematic views of fixed offshore rig and land wellsites which is incorporated herein by reference) the one or more pressure control devices 102 may control pressure in the wellbore 106. The pressure control devices 102 may include, but are not limited to, BOPs, RCDs, and the like. Risers 107 may be positioned above, with and/or below the pressure control devices 102. The risers 107 may present challenges to introducing lubricants, coolants, lubrication systems and/or cooling systems for the pressure control devices 102. As shown, the top pressure control device 102 is an RCD 114. A staged seal 116 may be part of a bearing assembly 117a located in the RCD 114. The staged seal 116 may be a radial seal håving a pressure reduction system 118. The pressure reduction system 118 may be a closed piston system configured to stage pressure across the staged seal 116. Further, the staged seal 116 may be configured to engage and seal an inner member 104 during oilfield operations. The inner member 104 may be any suitable, rotatable equipment to be sealed by the staged seal 116.
[0014] A pressure control device 102 is located directly below the RCD 114 (as shown) and may be a sealing device 119. The sealing device 119 may have stripper rubbers 120 for sealing against the rotating drill string or piece of oilfield equipment 122, and a bearing assembly 117b. The bearing assembly 117b may have a fixed latch (or RCD body) 126 configured to engage a bearing 128. The stripper rubbers 120 may engage the rotating drill string 122 as the drill string 122 is inserted into the wellbore 106. The fixed latch 126 may have a heat exchanger 130 (see Figure 2) built into the latch in order to cool the latch as will be discussed in more detail below. The RCD 114 with the staged seal 116 does not necessarily, although can be, used above or with the RCD 114 with the sealing device 119.
[0015] Figure 2 depicts a cross sectional view of the pressure control device 102 håving the fixed latch 126 with a heat exchanger profile 400 therein. The fixed latch 126 may secure a bearing assembly 402 within the pressure control device 102. The fixed latch 126 and bearing assembly 402 may allow the inner member 104 to rotate relative to the fixed latch 126 and bearing assembly 402 as the drill string 122 is run through the pressure control device 102. As the inner member 104 rotates with or relative to the drill string 122, the motion creates friction between the inner member 104 and an inner surface 407 of the bearing assembly 402. The friction may cause heating in both the bearing assembly 402 and the seals or shaft seals 406, which lie between the bearing assembly 402 and the inner member 104. The increased heat decreases life span of the seals 406 and the bearing assembly 402. The bearing assembly 402 and the seals 406 may respectively be any suitable bearing assembly and seals used in the pressure control device 102 including those described herein.
[0016] The heat exchanger profile 400 may cool the fixed latch 126, and bearing assembly 402 during operation thereby extending the life of the seals 406 and bearing assembly 402. This may further allow the bearing assembly 402 to operate or be operational with a self-contained lubricant (i.e. an integral bearing assembly 402 with lubricant without any external lubrication system or without any lubrication system running through a riser 107 to the surface). The heat exchanger profiles 400 may be fluid passages 401 through the interior surface area 403 of the fixed latch 126. The fluid passages 401 may be configured to maximize the interior surface area 403 that is cooled in the fixed latch 126. Any suitable heat exchanger shape or channel way for paths/fluid passages 401 may be used for the heat exchanger profile 400 so long as the fixed latch 126 is cooled. By way of example only, in the embodiment shown, there is one inlet 415a and one outlet 415b, to the path/fluid passages 401.
[0017] The heat exchanger profile 400 may be coupled to or integral with a heat exchanger system 408 and may cool through or from either side of the RCD 114. The heat exchanger system 408 may include, but is not limited to, a heat exchanger 410, a tank 411 for containing a volume of cooling medium or coolant 405, a pump 412, an optional separate condenser 409, and one or more conduits 414. The heat exchanger 410 may be any suitable device for cooling the fluid, a quantity or volume of cooling medium 405, circulating through the conduit 414 including, but not limited to, the exposed sea temperature on the conduit 414, a shell and tube exchanger, and the like. The pump 412 may be any suitable device for circulating the quantity of cooling medium 405 from the tank 411 through the conduit 414. The optional separate condenser 409 may be included to condense any gases or fluids after håving circulated the fluid passages 401 and conduits 414. By way of example only, the optional separate condenser 409 may be located near the outlet 415b but could also be located near the inlet 415a or intermediate thereto. The pump 412 may be any suitable device for delivering the quantity of cooling medium 405 through the heat exchanger system 408 including, but not limited to, a centrifugal pump, a reciprocating pump, and the like. The quantity of cooling medium 405 may be any suitable medium for cooling the heat exchanger system 408 including, but not limited to, water, sea water, refrigerant, refrigerant mixtures, liquids (including those that remain in a liquid state during the heat exchange process) or gasses, air, oil and/or the like.
[0018] The inner member 104 may further include an insulating coating 416 on the inner surface 142 of the inner member 104. The insulating coating 416 may be configured to reduce heat transfer from the inner surface 142 of the inner member 104 caused by heated wellbore fluids to the seals 406. This additional cooling may prevent the wear on the seals 406. By way of example only, in one embodiment, the insulating coating 416 may be made of ceramic, refractory, hard rubber, fiberglass, composite, elastomer, and/or thermal/electrical materials of suitable thickness for insulating a passage of inner member 104. In addition, the insulating coating 416 may extend to one or more surfaces on the stripper rubber mount 132 to which the stripper rubber(s) 120 are attached to.
[0019] Figure 3 depicts a cross sectional view of half of a pressure control device 102 embodiment håving a carrier 500 (see US Provisional Appl. No. 61/986,544, filed on April 30, 2014, which is herein incorporated by reference) håving the pressure reduction system 118 and in the heat exchanger profile 400. The carrier 500 as shown is configured to support a seal element 502 for engaging the drill string 122. The seal element 502 may be configured to seal drill string 122 as the drill pipe is run into or out of the wellbore 106 (as shown in Figure 1). The carrier 500 may be located below, above or within the bearing assembly 117 of an RCD 114. In one embodiment, the pressure reduction system 118 may operate in the same manner as described in US Provisional Appl. No. 61/986,544, in order to apply pressure to the outer radial surface 504 of the seal element 502. In another embodiment, the pressure reduction system 118 may be controlled by a hydraulic unit or controller in order to maintain the pressure on the outer radial surface 504 of the seal element 502.
[0020] The heat exchanger profile 400 may operate in the same manner as described in conjunction with Figure 2. To this end, the heat exchanger profile 400 may be a part of the heat exchanger system 408 and have the heat exchanger 410, the pump 412 and the conduit 414 (as shown in Figure 2). A carrier inlet 510 and a carrier outlet (not pictured) may continue or extend the heat exchanger profiles 400 from the fixed latch 126 into the carrier 500 (or from another heat exchanger profile 400 independent of the fixed latch 126), allowing the cooling medium 405 to circulate through the carrier 500. The heat exchanger profile 400 in the carrier 500 may reduce the heat in the carrier 500 and thereby reduce the temperature of the volume of fluid 303 applying pressure to the seal element 502. Further, the carrier 500 may have a layer of insulating coating 506 on the carrier's surfaces 508 (by way of example on the outer or exterior surface) to help reduce heat transfer caused by heated wellbore fluids. The decreased temperature applied to the seal element 502 may reduce wear and increase the life of the seal element 502.
[0021] In addition, the heat exchanger system 408, heat exchanger profile 400, and carrier 500 may be a closed hydraulic control system 420, thereby eliminating the need for an external cooling system to control the temperature of the pressure control device 102. A closed hydraulic system 420 may relieve demand on limited resources, and further, addresses difficulty in installing and maintaining an external cooling system in extreme environments. Risers 107, used in subsea operations, may also pose significant obstacles to the use of external cooling systems.
[0022] While the exemplary embodiments are described with reference to various implementations and exploitations, it will be understood that these exemplary embodiments are illustrative and that the scope of the inventive subject matter is not limited to them. Many variations, modifications, additions and improvements are possible. For example, although the exemplary embodiments have thus far been depicted and described with a closed hydraulic control system 420, the exemplary embodiments described within may also be utilized in conjunction with an open or external hydraulic control system. Further, the implementations and techniques used herein may be applied to any strippers, seals, or packer members at the well site, such as the BOP, and the like.
[0023] Plural instances may be provided for components, operations or structures described herein as a single instance. In general, structures and functionality presented as separate components in the exemplary configurations may be implemented as a combined structure or component. Similarly, structures and functionality presented as a single component may be implemented as separate components. These and other variations, modifications, additions, and improvements may fall within the scope of the inventive subject matter.
Claims (20)
1. An apparatus for reducing heat in a pressure control device in a wellbore, comprising: a fixed latch in the pressure control device, wherein an interior surface
of the fixed latch defines one or more fluid passages; a heat exchanger system in fluid communication with the fluid passage;
and a volume of cooling medium housed within the fixed latch and the heat
exchanger system, wherein the volume of cooling medium is configured for removing and absorbing heat from the pressure control device.
2. The apparatus of claim 1, wherein the heat exchanger system further comprises
a heat exchanger in the heat exchanger system, wherein the heat
exchanger is configured for cooling the volume of cooling medium; and
one or more conduits in the heat exchanger system, wherein the one or
more conduits is configured for housing the volume of cooling medium.
3. The apparatus of claim 2, further comprising
an inlet port connected to the fluid passage; and
an outlet port connected to the fluid passage.
4. The apparatus of claim 2, further comprising
a condenser in the heat exchanger system, wherein the condenser is
configured to condense the volume of cooling medium.
5. The apparatus of claim 4, wherein the heat exchanger system further comprises
a pump configured to circulate the volume of cooling medium through
the fluid passage and the conduit.
6. The apparatus of claim 5 further comprising
a bearing assembly housed within the fixed latch; and
an inner member housed within the bearing assembly, wherein the
inner member is configured to rotate relative to the bearing assembly, and further wherein the inner member includes an insulating coating on an inner surface of the inner member.
7. The apparatus of claim 6, wherein the insulating coating is an insulating ceramic coating.
8. The apparatus of claim 7, further comprising
a carrier mounted to the pressure control device, wherein the fluid
passages extend to a surface of the carrier; and further wherein the surface of the carrier has an insulating coating.
9. The apparatus of claim 8, further comprising one or more seals situated between the inner member and the bearing assembly.
10. The apparatus of claim 1, wherein the fluid passages and the heat exchanger system are a closed hydraulic system.
11. An apparatus for reducing heat in a bearing assembly and a RCD at a wellbore, comprising: a piece of oilfield equipment; an inner member housed within the bearing assembly, wherein the
inner member is configured to rotate relative to the bearing assembly; one or more seals situated between the inner member and the bearing
assembly; a fixed latch configured to secure the bearing assembly radially within
the RCD; wherein the fixed latch defines a heat exchanger profile located within
the fixed latch configured to allow a quantity of cooling medium to circulate through the fixed latch thereby cooling the bearing assembly, the inner member, and the seals during operation; and wherein the RCD is configured to engage the piece of oilfield
equipment as the piece of oilfield equipment passes through the RCD, and further wherein the RCD is configured to rotate with the piece of oilfield equipment.
12. The apparatus of claim 11, further comprising an insulating coating on an inner surface of the inner member.
13. The apparatus of claim 11, further comprising: a seal element mounted to the RCD; a pressure control device mounted to the RCD; wherein the piece of oilfield equipment is proximate the RCD, and
wherein the seal element is configured to engage the piece of oilfield equipment as the piece of oilfield equipment passes through the pressure control device configured to seal against the piece of oilfield equipment; a carrier mounted to the bearing assembly, wherein the carrier is
configured to secure the seal element within the pressure control device; and wherein the carrier defines a heat exchanger profile located within the
carrier, and wherein the heat exchanger profile is configured to allow a quantity of cooling medium to circulate through the pressure control device thereby cooling the seal element during operation.
14. The apparatus of claim 13 wherein the carrier has an exterior carrier surface;
and further comprising a layer of insulating coating on the exterior carrier surface.
15. A method for reducing heat proximate a bearing assembly of a RCD at a wellbore, comprising the steps of: rotating an inner member housed within the bearing assembly; circulating a quantity of cooling medium through a heat exchanger
system at the RCD; and delivering the quantity of cooling medium through a heat exchanger
profile connected to the heat exchanger system, wherein the heat exchanger profile is defined on an interior surface of a fixed latch for exchanging heat generated by the inner member rotating within the bearing assembly.
16. The method according to claim 15, further comprising the steps of: removing the quantity of cooling medium from the heat exchanger
profile; and repeating the steps of circulating, delivering and removing.
17. The method according to claim 15, further comprising the step of insulating the inner member with a ceramic coating on an inner surface of the inner member.
18. The method according to claim 15, wherein the heat exchanger profile is further connected to a carrier supporting a seal element, and further comprising the steps of
insulating the carrier with a layer of ceramic coating on a surface of the
carrier;
reducing heat in the carrier; and
reducing heat of a volume of fluid applying pressure to the seal
element.
19. The method according to claim 15 further comprising the step of condensing the quantity of cooling medium.
20. The method according to claim 15 further comprising the step of reducing a temperature experienced by a seal located between the
inner member and the fixed latch.
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201461986661P | 2014-04-30 | 2014-04-30 | |
PCT/US2015/028555 WO2015168429A2 (en) | 2014-04-30 | 2015-04-30 | Bearing assembly cooling methods |
Publications (1)
Publication Number | Publication Date |
---|---|
NO20161539A1 true NO20161539A1 (en) | 2016-09-26 |
Family
ID=53175187
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
NO20161539A NO20161539A1 (en) | 2014-04-30 | 2016-09-26 | Bearing assembly cooling methods |
Country Status (8)
Country | Link |
---|---|
US (1) | US20150315874A1 (en) |
AU (1) | AU2015253003B2 (en) |
CA (1) | CA2942542C (en) |
EA (1) | EA035191B1 (en) |
GB (1) | GB2539356B (en) |
MX (1) | MX2016013237A (en) |
NO (1) | NO20161539A1 (en) |
WO (1) | WO2015168429A2 (en) |
Families Citing this family (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
AU2015253019B2 (en) * | 2014-04-30 | 2017-09-07 | Weatherford Technology Holdings, Llc | Sealing element mounting |
US20190024473A1 (en) * | 2017-07-18 | 2019-01-24 | Schlumberger Technology Corporation | Rotating annular preventer and methods of use thereof |
US10494877B2 (en) | 2017-08-16 | 2019-12-03 | Weatherford Technology Holdings, Llc | Subsea rotating control device apparatus having debris barrier |
US11136848B2 (en) | 2019-04-26 | 2021-10-05 | NTDrill Holdings, LLC | Rotating control device with cooling mandrel |
US11255144B2 (en) * | 2019-12-08 | 2022-02-22 | Hughes Tool Company LLC | Annular pressure cap drilling method |
MX2023005887A (en) * | 2020-11-21 | 2023-06-05 | Electrical Subsea & Drilling As | Packer arrangement for sealingly guiding a drillstring therethrough. |
US11808111B2 (en) * | 2022-02-11 | 2023-11-07 | Weatherford Technology Holdings, Llc | Rotating control device with integrated cooling for sealed bearings |
Family Cites Families (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5178215A (en) * | 1991-07-22 | 1993-01-12 | Folsom Metal Products, Inc. | Rotary blowout preventer adaptable for use with both kelly and overhead drive mechanisms |
US5251869A (en) * | 1992-07-16 | 1993-10-12 | Mason Benny M | Rotary blowout preventer |
US7836946B2 (en) * | 2002-10-31 | 2010-11-23 | Weatherford/Lamb, Inc. | Rotating control head radial seal protection and leak detection systems |
US7926593B2 (en) * | 2004-11-23 | 2011-04-19 | Weatherford/Lamb, Inc. | Rotating control device docking station |
-
2015
- 2015-04-30 WO PCT/US2015/028555 patent/WO2015168429A2/en active Application Filing
- 2015-04-30 GB GB1617603.4A patent/GB2539356B/en active Active
- 2015-04-30 EA EA201692195A patent/EA035191B1/en not_active IP Right Cessation
- 2015-04-30 US US14/701,012 patent/US20150315874A1/en not_active Abandoned
- 2015-04-30 AU AU2015253003A patent/AU2015253003B2/en active Active
- 2015-04-30 CA CA2942542A patent/CA2942542C/en active Active
- 2015-04-30 MX MX2016013237A patent/MX2016013237A/en unknown
-
2016
- 2016-09-26 NO NO20161539A patent/NO20161539A1/en unknown
Also Published As
Publication number | Publication date |
---|---|
GB201617603D0 (en) | 2016-11-30 |
CA2942542A1 (en) | 2015-11-05 |
AU2015253003B2 (en) | 2017-02-02 |
US20150315874A1 (en) | 2015-11-05 |
AU2015253003A1 (en) | 2016-09-29 |
GB2539356A (en) | 2016-12-14 |
EA035191B1 (en) | 2020-05-12 |
GB2539356B (en) | 2019-01-23 |
WO2015168429A3 (en) | 2016-01-28 |
CA2942542C (en) | 2018-02-27 |
EA201692195A1 (en) | 2017-02-28 |
MX2016013237A (en) | 2017-01-09 |
WO2015168429A2 (en) | 2015-11-05 |
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Representative=s name: HAMSOE PATENTBYRA ANS, POSTBOKS 171, 4301 SANDNES |