US20210231249A1 - Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement - Google Patents
Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement Download PDFInfo
- Publication number
- US20210231249A1 US20210231249A1 US16/774,718 US202016774718A US2021231249A1 US 20210231249 A1 US20210231249 A1 US 20210231249A1 US 202016774718 A US202016774718 A US 202016774718A US 2021231249 A1 US2021231249 A1 US 2021231249A1
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- United States
- Prior art keywords
- conduit
- fluid
- subsea
- flow rate
- valving
- 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.)
- Abandoned
Links
- 238000000034 method Methods 0.000 title claims abstract description 14
- 239000012530 fluid Substances 0.000 claims abstract description 74
- 238000004519 manufacturing process Methods 0.000 claims abstract description 42
- 238000012546 transfer Methods 0.000 claims abstract description 19
- 239000013535 sea water Substances 0.000 claims abstract description 15
- 238000001816 cooling Methods 0.000 claims abstract description 6
- 238000012544 monitoring process Methods 0.000 claims description 7
- 230000015572 biosynthetic process Effects 0.000 claims description 6
- 230000005484 gravity Effects 0.000 claims description 3
- 238000009413 insulation Methods 0.000 description 4
- 239000000463 material Substances 0.000 description 3
- 239000000203 mixture Substances 0.000 description 3
- 239000001993 wax Substances 0.000 description 3
- 239000011248 coating agent Substances 0.000 description 2
- 238000000576 coating method Methods 0.000 description 2
- 238000011161 development Methods 0.000 description 2
- 230000018109 developmental process Effects 0.000 description 2
- 150000004677 hydrates Chemical class 0.000 description 2
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 2
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000007717 exclusion Effects 0.000 description 1
- 229930195733 hydrocarbon Natural products 0.000 description 1
- 150000002430 hydrocarbons Chemical class 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000012797 qualification Methods 0.000 description 1
Images
Classifications
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L53/00—Heating of pipes or pipe systems; Cooling of pipes or pipe systems
- F16L53/70—Cooling of pipes or pipe 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
- E21B17/00—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings
- E21B17/003—Drilling rods or pipes; Flexible drill strings; Kellies; Drill collars; Sucker rods; Cables; Casings; Tubings with electrically conducting or insulating means
-
- 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
- E21B41/00—Equipment or details not covered by groups E21B15/00 - E21B40/00
- E21B41/0007—Equipment or details not covered by groups E21B15/00 - E21B40/00 for underwater installations
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/013—Connecting a production flow line to an underwater well head
-
- 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/01—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
- E21B43/017—Production satellite stations, i.e. underwater installations comprising a plurality of satellite well heads connected to a central station
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L1/00—Laying or reclaiming pipes; Repairing or joining pipes on or under water
- F16L1/12—Laying or reclaiming pipes on or under water
- F16L1/20—Accessories therefor, e.g. floats, weights
-
- F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
- F16—ENGINEERING ELEMENTS AND UNITS; GENERAL MEASURES FOR PRODUCING AND MAINTAINING EFFECTIVE FUNCTIONING OF MACHINES OR INSTALLATIONS; THERMAL INSULATION IN GENERAL
- F16L—PIPES; JOINTS OR FITTINGS FOR PIPES; SUPPORTS FOR PIPES, CABLES OR PROTECTIVE TUBING; MEANS FOR THERMAL INSULATION IN GENERAL
- F16L53/00—Heating of pipes or pipe systems; Cooling of pipes or pipe systems
- F16L53/30—Heating of pipes or pipe systems
- F16L53/32—Heating of pipes or pipe systems using hot fluids
-
- 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
- E21B36/003—Insulating arrangements
Definitions
- This disclosure relates generally to subsea oil and gas production facilities, and particularly to interconnecting conduits extending between subsea components.
- the disclosure further relates to thermal management of such interconnecting conduits.
- the production of hydrocarbons from offshore oil and gas reservoirs requires the transportation of production fluids from the reservoirs to subsea facilities for processing.
- Three phases, i.e., oil, gas and water, may be included in the production fluids.
- the high temperature of the production fluids can have several undesirable effects.
- Special grade subsea and pipeline materials, extensive qualifications of insulation coating and expensive modifications topsides may be required to handle the high temperature of the product.
- water cooled heat exchangers may be used topsides on an offshore platform to reduce the temperature of production fluids, e.g., from around 400° F. to a temperature below 250° F., involving weight, space, cost, etc.
- the high temperature of the product may undesirably result in the occurrence of upheaval buckling, lateral buckling and pipeline walking in flowlines carrying the product.
- the temperature may also undesirably accelerate corrosion and therefore reduce the life of the flowlines.
- the disclosure relates to a system for thermal management of a subsea conduit that carries oil and/or gas produced from a subsea well in a subsea production facility located on a seabed.
- the system includes an interconnecting conduit circuit for carrying production fluids between subsea components.
- the circuit has two ends for connecting to the subsea components, a first conduit section, and a second conduit section in parallel with respect to one another, wherein the first and second conduit sections have different heat transfer with respect to the surrounding seawater.
- the system also includes valving to direct the production fluids through the first conduit section and/or second conduit section such that heat transfer from the production fluids to seawater surrounding the interconnecting conduit circuit can be controlled by adjusting the valving.
- the disclosure can generally relate to a method for thermal management of the subsea conduit in the subsea production facility.
- the method includes transmitting production fluids between subsea components in the interconnecting conduit circuit; and controlling the valving to direct the production fluids through the first conduit section and/or second conduit section such that heat transfer from the production fluids to seawater surrounding the interconnecting conduit circuit is adjusted as desired.
- FIG. 1 shows an example embodiment of a subsea interconnecting conduit according to the prior art.
- FIG. 2 shows an example embodiment of a self-draining interconnecting conduit circuit having two segments and valving.
- FIG. 3 shows another example embodiment of a self-draining interconnecting conduit circuit having two segments and valving optionally controlled by a control system.
- a subsea pipeline 30 carries oil and/or gas produced from a subsea well 35 in the facility located on the seabed.
- a jumper 40 is connected to a first subsea component 20 (in this case, a manifold) and a second subsea component 25 (in this case, a pipeline end termination (PLET)).
- the subsea jumper 40 connects two different structures such as manifold and PLET to allow product flow to or from a subsea pipeline 30 .
- the subsea pipeline 30 is connected to the pipeline end termination.
- the subsea jumper 40 typically consists of interconnected pipes, connectors, bends and insulation coating.
- the insulation (not shown) can ensure the product remains flowing above a certain temperature to avoid formation of waxes or hydrates that risk plugging the jumper pipe and stopping production. During shut down when production is stopped, the insulation is used to allow a minimum safe cool down time typically in the range of 12 to 16 hours to avoid formation of waxes of hydrates.
- the jumper 40 is shaped with a general M-shape to allow for safe thermal expansion as the temperature of the produced fluids increase through the jumper 40 . This helps prevent thermal fatigue of the jumper 40 .
- FIG. 2 a system for thermal management of a subsea conduit that carries oil and/or gas produced from a subsea well in a subsea production facility located on a seabed is illustrated.
- the system includes an interconnecting conduit circuit 2 , also referred to herein as a jumper circuit 2 , for carrying production fluids between subsea components (e.g., manifolds, wellheads, pipeline end terminations, and other equipment residing on the seabed).
- the conduit or jumper can be any suitable device as known for permitting the flow of produced fluids therethrough.
- the jumper circuit 2 has two ends 2 A and 2 B for connecting to the subsea components ( 20 and 25 ).
- the jumper circuit 2 has a first jumper section 2 C and a second jumper section 2 D in parallel with respect to one another as shown.
- the first and second jumper sections 2 C and 2 D provide differing amounts of heat transfer with respect to the surrounding seawater, i.e., 2 C and 2 D have different heat transfer coefficients.
- one of the first and second jumper sections 2 C and 2 D is insulated and the other is uninsulated.
- Valving 4 is provided to direct the production fluids flowing in the jumper circuit 2 through the first jumper section 2 C and/or second jumper section 2 D as desired.
- production fluids can be directed solely through section 2 C, solely through section 2 D, or partially through each of sections 2 C and 2 D. Since the sections 2 C and 2 D have differing heat transfer coefficients, the heat transfer from the production fluids to the seawater surrounding the jumper circuit 2 can be controlled by adjusting the valving 4 as desired.
- each of the jumper sections 2 C and 2 D includes multiple jumper segments changing in direction, e.g., zig-zagging, and sloping downward such that flow of fluid in the jumper segments is assisted by gravity thereby ensuring self-draining of the fluid independent from fluid pressure in the jumper circuit.
- An example of such a configuration is shown in FIG. 3 where jumper segments 3 in the jumper sections 2 C and 2 D change direction and slope downward such that flow of fluid in the jumper segments 3 .
- jumper sections 2 C and 2 D are positioned at an angle greater than 0 degrees and less than 90 degrees such that the jumper sections 2 C and 2 D are sloping with respect to the seabed.
- the valving 4 can be controlled responsive to a control system 6 based on a predetermined fluid temperature and/or flow rate of production fluids flowing through the jumper circuit 2 .
- a temperature sensor 8 such as a phase change thermostat, for example, can be used for continuously monitoring an internal fluid temperature of fluid in the jumper circuit 2 .
- a flow rate sensor 9 can be used for continuously monitoring an internal fluid flow velocity of fluid in the jumper circuit 2 .
- a flying lead or umbilical 10 can be used for transmitting temperature and/or flow rate data from the temperature sensor 8 and/or the flow rate sensor 9 , respectively, to a processor 11 .
- the processor 11 is configured or set to determine whether to activate an alarm based on the temperature and/or flow rate information.
- the alarm indicates the need to adjust the valving 4 .
- Operating personnel can act on the alarm by adjusting the valving 4 manually using an ROV.
- the processor 11 of the control system 6 can also be configured to automatically adjust the valving 4 based on the temperature and/or flow rate information
- the valving 4 is set to direct produced fluid flow through the one of the jumper sections 2 C and 2 D having the greater amount of heat transfer (i.e., the greater heat transfer coefficient) with respect to the surrounding seawater to aid in cooling of produced fluid in the jumper circuit 2 .
- the valving 4 is set to direct produced fluid flow through the one of the jumper sections 2 C and 2 D having the lesser amount of heat transfer (i.e., the lower heat transfer coefficient) with respect to the surrounding seawater to aid in retaining heat and thus maintaining produced fluid temperature above hydrate formation and wax formation temperatures.
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- Engineering & Computer Science (AREA)
- Life Sciences & Earth Sciences (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- General Engineering & Computer Science (AREA)
- Mechanical Engineering (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Geochemistry & Mineralogy (AREA)
- Fluid-Pressure Circuits (AREA)
Abstract
Description
- This disclosure relates generally to subsea oil and gas production facilities, and particularly to interconnecting conduits extending between subsea components. The disclosure further relates to thermal management of such interconnecting conduits.
- The production of hydrocarbons from offshore oil and gas reservoirs requires the transportation of production fluids from the reservoirs to subsea facilities for processing. Three phases, i.e., oil, gas and water, may be included in the production fluids. Subsea developments increasingly must accommodate high temperature production fluids that need to be safely transported to the production facility. The high temperature of the production fluids can have several undesirable effects. Special grade subsea and pipeline materials, extensive qualifications of insulation coating and expensive modifications topsides may be required to handle the high temperature of the product. For instance, water cooled heat exchangers may be used topsides on an offshore platform to reduce the temperature of production fluids, e.g., from around 400° F. to a temperature below 250° F., involving weight, space, cost, etc. In the subsea facility, the high temperature of the product may undesirably result in the occurrence of upheaval buckling, lateral buckling and pipeline walking in flowlines carrying the product. The temperature may also undesirably accelerate corrosion and therefore reduce the life of the flowlines. Attempts have been made at providing a subsea cooling system for use with gas production. No established oil or three phase subsea cooling system is available in the industry.
- There exists a need for cost-effective subsea cooling systems and methods that can be applied to subsea flowlines or interconnecting conduits such as jumpers that carry three-phase production fluids to enable the development of high temperature subsea fields without the disadvantages of known systems.
- In general, in one aspect, the disclosure relates to a system for thermal management of a subsea conduit that carries oil and/or gas produced from a subsea well in a subsea production facility located on a seabed. The system includes an interconnecting conduit circuit for carrying production fluids between subsea components. The circuit has two ends for connecting to the subsea components, a first conduit section, and a second conduit section in parallel with respect to one another, wherein the first and second conduit sections have different heat transfer with respect to the surrounding seawater. The system also includes valving to direct the production fluids through the first conduit section and/or second conduit section such that heat transfer from the production fluids to seawater surrounding the interconnecting conduit circuit can be controlled by adjusting the valving.
- In another aspect, the disclosure can generally relate to a method for thermal management of the subsea conduit in the subsea production facility. The method includes transmitting production fluids between subsea components in the interconnecting conduit circuit; and controlling the valving to direct the production fluids through the first conduit section and/or second conduit section such that heat transfer from the production fluids to seawater surrounding the interconnecting conduit circuit is adjusted as desired.
- These and other objects, features and advantages of the present invention will become better understood with reference to the following description, appended claims and accompanying drawings. The drawings are not considered limiting of the scope of the appended claims. Reference numerals designate like or corresponding, but not necessarily identical, elements. The drawings illustrate only example embodiments. The elements and features shown in the drawings are not necessarily to scale, emphasis instead being placed upon clearly illustrating the principles of the example embodiments. Additionally, certain dimensions or positionings may be exaggerated to help visually convey such principles.
-
FIG. 1 shows an example embodiment of a subsea interconnecting conduit according to the prior art. -
FIG. 2 shows an example embodiment of a self-draining interconnecting conduit circuit having two segments and valving. -
FIG. 3 shows another example embodiment of a self-draining interconnecting conduit circuit having two segments and valving optionally controlled by a control system. - Referring to
FIG. 1 , a prior art subsea production facility is shown. Asubsea pipeline 30 carries oil and/or gas produced from a subsea well 35 in the facility located on the seabed. Ajumper 40 is connected to a first subsea component 20 (in this case, a manifold) and a second subsea component 25 (in this case, a pipeline end termination (PLET)). Thesubsea jumper 40 connects two different structures such as manifold and PLET to allow product flow to or from asubsea pipeline 30. Thesubsea pipeline 30 is connected to the pipeline end termination. Thesubsea jumper 40 typically consists of interconnected pipes, connectors, bends and insulation coating. The insulation (not shown) can ensure the product remains flowing above a certain temperature to avoid formation of waxes or hydrates that risk plugging the jumper pipe and stopping production. During shut down when production is stopped, the insulation is used to allow a minimum safe cool down time typically in the range of 12 to 16 hours to avoid formation of waxes of hydrates. As shown, thejumper 40 is shaped with a general M-shape to allow for safe thermal expansion as the temperature of the produced fluids increase through thejumper 40. This helps prevent thermal fatigue of thejumper 40. - In one embodiment, referring to
FIG. 2 , a system for thermal management of a subsea conduit that carries oil and/or gas produced from a subsea well in a subsea production facility located on a seabed is illustrated. The system includes an interconnectingconduit circuit 2, also referred to herein as ajumper circuit 2, for carrying production fluids between subsea components (e.g., manifolds, wellheads, pipeline end terminations, and other equipment residing on the seabed). The conduit or jumper can be any suitable device as known for permitting the flow of produced fluids therethrough. Thejumper circuit 2 has two ends 2A and 2B for connecting to the subsea components (20 and 25). Thejumper circuit 2 has a first jumper section 2C and a second jumper section 2D in parallel with respect to one another as shown. The first and second jumper sections 2C and 2D provide differing amounts of heat transfer with respect to the surrounding seawater, i.e., 2C and 2D have different heat transfer coefficients. In one embodiment, one of the first and second jumper sections 2C and 2D is insulated and the other is uninsulated. - Valving 4 is provided to direct the production fluids flowing in the
jumper circuit 2 through the first jumper section 2C and/or second jumper section 2D as desired. For example, by adjusting the valving 4, production fluids can be directed solely through section 2C, solely through section 2D, or partially through each of sections 2C and 2D. Since the sections 2C and 2D have differing heat transfer coefficients, the heat transfer from the production fluids to the seawater surrounding thejumper circuit 2 can be controlled by adjusting the valving 4 as desired. - In one embodiment, each of the jumper sections 2C and 2D includes multiple jumper segments changing in direction, e.g., zig-zagging, and sloping downward such that flow of fluid in the jumper segments is assisted by gravity thereby ensuring self-draining of the fluid independent from fluid pressure in the jumper circuit. An example of such a configuration is shown in
FIG. 3 where jumper segments 3 in the jumper sections 2C and 2D change direction and slope downward such that flow of fluid in the jumper segments 3. In one embodiment, jumper sections 2C and 2D are positioned at an angle greater than 0 degrees and less than 90 degrees such that the jumper sections 2C and 2D are sloping with respect to the seabed. - In one embodiment, the valving 4 can be controlled responsive to a
control system 6 based on a predetermined fluid temperature and/or flow rate of production fluids flowing through thejumper circuit 2. A temperature sensor 8 such as a phase change thermostat, for example, can be used for continuously monitoring an internal fluid temperature of fluid in thejumper circuit 2. A flow rate sensor 9 can be used for continuously monitoring an internal fluid flow velocity of fluid in thejumper circuit 2. A flying lead or umbilical 10 can be used for transmitting temperature and/or flow rate data from the temperature sensor 8 and/or the flow rate sensor 9, respectively, to aprocessor 11. Theprocessor 11 is configured or set to determine whether to activate an alarm based on the temperature and/or flow rate information. The alarm indicates the need to adjust the valving 4. Operating personnel can act on the alarm by adjusting the valving 4 manually using an ROV. Theprocessor 11 of thecontrol system 6 can also be configured to automatically adjust the valving 4 based on the temperature and/or flow rate information. - In one embodiment, during routine or early-life production of oil and/or gas from a subsea well, the valving 4 is set to direct produced fluid flow through the one of the jumper sections 2C and 2D having the greater amount of heat transfer (i.e., the greater heat transfer coefficient) with respect to the surrounding seawater to aid in cooling of produced fluid in the
jumper circuit 2. Likewise, in one embodiment, during shutdown or late-life production from the subsea well, the valving 4 is set to direct produced fluid flow through the one of the jumper sections 2C and 2D having the lesser amount of heat transfer (i.e., the lower heat transfer coefficient) with respect to the surrounding seawater to aid in retaining heat and thus maintaining produced fluid temperature above hydrate formation and wax formation temperatures. - It should be noted that only the components relevant to the disclosure are shown in the figures, and that many other components normally part of a subsea oil and gas field are not shown for simplicity.
- For the purposes of this specification and appended claims, unless otherwise indicated, all numbers expressing quantities, percentages or proportions, and other numerical values used in the specification and claims are to be understood as being modified in all instances by the term “about.” Accordingly, unless indicated to the contrary, the numerical parameters set forth in the following specification and attached claims are approximations that can vary depending upon the desired properties sought to be obtained by the present invention. It is noted that, as used in this specification and the appended claims, the singular forms “a,” “an,” and “the,” include plural references unless expressly and unequivocally limited to one referent.
- Unless otherwise specified, the recitation of a genus of elements, materials or other components, from which an individual component or mixture of components can be selected, is intended to include all possible sub-generic combinations of the listed components and mixtures thereof. Also, “comprise,” “include” and its variants, are intended to be non-limiting, such that recitation of items in a list is not to the exclusion of other like items that may also be useful in the materials, compositions, methods and systems of this invention.
Claims (16)
Priority Applications (2)
Application Number | Priority Date | Filing Date | Title |
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US16/774,718 US20210231249A1 (en) | 2020-01-28 | 2020-01-28 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
US18/489,575 US20240044435A1 (en) | 2020-01-28 | 2023-10-18 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
Applications Claiming Priority (1)
Application Number | Priority Date | Filing Date | Title |
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US16/774,718 US20210231249A1 (en) | 2020-01-28 | 2020-01-28 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
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US18/489,575 Continuation US20240044435A1 (en) | 2020-01-28 | 2023-10-18 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
Publications (1)
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US20210231249A1 true US20210231249A1 (en) | 2021-07-29 |
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ID=76969878
Family Applications (2)
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US16/774,718 Abandoned US20210231249A1 (en) | 2020-01-28 | 2020-01-28 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
US18/489,575 Pending US20240044435A1 (en) | 2020-01-28 | 2023-10-18 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
Family Applications After (1)
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US18/489,575 Pending US20240044435A1 (en) | 2020-01-28 | 2023-10-18 | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
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Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060016617A1 (en) * | 2004-07-26 | 2006-01-26 | Corbishley Terrence J | Marine and submarine pipelines |
US20160130918A1 (en) * | 2013-06-06 | 2016-05-12 | Shell Oil Company | Jumper line configurations for hydrate inhibition |
US20160222761A1 (en) * | 2015-01-30 | 2016-08-04 | Bp Corporation North America Inc. | Subsea Heat Exchangers For Offshore Hydrocarbon Production Operations |
US9920597B2 (en) * | 2014-06-24 | 2018-03-20 | Aker Solutions As | System for subsea pumping or compressing |
US20210180436A1 (en) * | 2019-12-13 | 2021-06-17 | Saipem S.A. | Subsea Installation for Heating a Two-Phase Liquid/Gas Effluent Circulating Inside a Subsea Casing |
US20220034661A1 (en) * | 2020-07-31 | 2022-02-03 | DUNLOP OIL & MARINE Ltd. | Floating buoy excursion analyzer system |
-
2020
- 2020-01-28 US US16/774,718 patent/US20210231249A1/en not_active Abandoned
-
2023
- 2023-10-18 US US18/489,575 patent/US20240044435A1/en active Pending
Patent Citations (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20060016617A1 (en) * | 2004-07-26 | 2006-01-26 | Corbishley Terrence J | Marine and submarine pipelines |
US20160130918A1 (en) * | 2013-06-06 | 2016-05-12 | Shell Oil Company | Jumper line configurations for hydrate inhibition |
US9920597B2 (en) * | 2014-06-24 | 2018-03-20 | Aker Solutions As | System for subsea pumping or compressing |
US20160222761A1 (en) * | 2015-01-30 | 2016-08-04 | Bp Corporation North America Inc. | Subsea Heat Exchangers For Offshore Hydrocarbon Production Operations |
US20210180436A1 (en) * | 2019-12-13 | 2021-06-17 | Saipem S.A. | Subsea Installation for Heating a Two-Phase Liquid/Gas Effluent Circulating Inside a Subsea Casing |
US20220034661A1 (en) * | 2020-07-31 | 2022-02-03 | DUNLOP OIL & MARINE Ltd. | Floating buoy excursion analyzer system |
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US20240044435A1 (en) | 2024-02-08 |
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