WO2014197557A1 - Configurations de conduites d'écoulement pour l'inhibition d'hydrates - Google Patents
Configurations de conduites d'écoulement pour l'inhibition d'hydrates Download PDFInfo
- Publication number
- WO2014197557A1 WO2014197557A1 PCT/US2014/040845 US2014040845W WO2014197557A1 WO 2014197557 A1 WO2014197557 A1 WO 2014197557A1 US 2014040845 W US2014040845 W US 2014040845W WO 2014197557 A1 WO2014197557 A1 WO 2014197557A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- jumper line
- subsea
- jumper
- subsea device
- elbows
- Prior art date
Links
- 230000005764 inhibitory process Effects 0.000 title description 5
- 238000004891 communication Methods 0.000 claims abstract description 3
- 239000012530 fluid Substances 0.000 claims abstract description 3
- 238000000034 method Methods 0.000 claims description 20
- 238000002347 injection Methods 0.000 claims description 8
- 239000007924 injection Substances 0.000 claims description 8
- 229930195733 hydrocarbon Natural products 0.000 claims description 7
- 150000002430 hydrocarbons Chemical class 0.000 claims description 7
- 150000004677 hydrates Chemical group 0.000 description 8
- 230000008901 benefit Effects 0.000 description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 5
- 230000015572 biosynthetic process Effects 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- 238000007792 addition Methods 0.000 description 2
- 239000007788 liquid Substances 0.000 description 2
- 239000000463 material Substances 0.000 description 2
- 238000012986 modification Methods 0.000 description 2
- 230000004048 modification Effects 0.000 description 2
- 235000004507 Abies alba Nutrition 0.000 description 1
- 241000191291 Abies alba Species 0.000 description 1
- 229910000975 Carbon steel Inorganic materials 0.000 description 1
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 1
- RTAQQCXQSZGOHL-UHFFFAOYSA-N Titanium Chemical compound [Ti] RTAQQCXQSZGOHL-UHFFFAOYSA-N 0.000 description 1
- 239000010962 carbon steel Substances 0.000 description 1
- 239000002131 composite material Substances 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- -1 flexible pipes Substances 0.000 description 1
- 239000003112 inhibitor Substances 0.000 description 1
- 230000007257 malfunction Effects 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 239000007787 solid Substances 0.000 description 1
- 229910052719 titanium Inorganic materials 0.000 description 1
- 239000010936 titanium Substances 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
- 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
- E21B37/00—Methods or apparatus for cleaning boreholes or 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
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/12—Methods or apparatus for controlling the flow of the obtained fluid to or in wells
Definitions
- the present disclosure relates generally to jumper line configurations. More specifically, in certain embodiments the present disclosure relates jumper line configurations for hydrate inhibition and associated methods.
- Jumper lines are flowlines that are commonly used to connected subsea units together. Conventional jumper line configurations often incorporate a valley and a bend in order to provide flexibility to the jumper line. During shut ins, liquids may settle and segregate in the lower middle section of these jumper lines. During shut in restart cycles, these jumper lines are often at risk of forming gas hydrates.
- the present disclosure relates generally to jumper line configurations. More specifically, in certain embodiments the present disclosure relates jumper line configurations for hydrate inhibition and associated methods.
- the present disclosure provides a jumper line system comprising: a first subsea device; a second subsea device; and a jumper line providing fluid communication between the first subsea device and the second subsea device, wherein the jumper line does not comprise a valley.
- the present disclosure provides a method of transporting hydrocarbons from a subsea well comprising: providing a subsea well; providing a manifold; connecting the subsea well to the manifold via a jumper line, wherein the jumper line does not comprise a valley; and flowing hydrocarbons from the subsea well to the manifold via the jumper line.
- the present disclosure provides a method of connecting two subsea devices comprising: providing a first subsea device; providing a second subsea device; providing a jumper line, wherein the jumper line comprises a first end section and a second end section and does not comprise a valley; connecting the first end section of the jumper line to the first subsea device; and connecting the second end section of the jumper line to the second subsea device.
- Figure 1 is a side view illustration of a typical M-shaped jumper line geometry.
- Figure 2 is a side view illustration of a jumper line geometry in accordance with an embodiment of the present disclosure.
- Figures 3A and 3B are top and side view illustrations of a jumper line geometry in accordance with an embodiment of the present disclosure.
- the present disclosure relates generally to jumper line configurations. More specifically, in certain embodiments the present disclosure relates jumper line configurations for hydrate inhibition and associated methods. [0016]
- the description that follows includes exemplary apparatuses, methods, techniques, and instruction sequences that embody techniques of the inventive subject matter. However, it is understood that the described embodiments may be practiced without these specific details.
- FIG. 1 illustrates a conventional jumper line configuration 100.
- conventional jumper line configuration 100 may comprise a first subsea device 110, a second subsea device 120, and a jumper line 130.
- Jumper line 130 may comprise one or more straight sections 131, one or more elbows 132, one or more peaks 133, one or more valleys 134, and one or more end sections 135.
- the one or more peaks 133 are comprised of one or more elbows 132.
- the one or more peaks 133 define the one or more valleys 133.
- the valleys 134 and elbows 132 may provide flexibility to the jumper line.
- liquids may settle and segregate in the valleys 134, as well as end sections 135, of the jumper lines 130 thus increasing the risk of hydrates forming in the valleys 134 during shut in-restart cycles.
- the present disclosure provides jumper line configurations that aid in the prevention of hydrate blockages. Examples of such jumper line configurations are illustrated in Figure 2 and Figures 3 A and 3B.
- jumper line configuration 200 may comprise a first subsea device 210, a second subsea device, and a jumper line 230.
- first subsea device 210 and second subsea device 220 can comprise any type subsea equipment.
- suitable subsea devices include subsea Christmas trees, well heads, and manifolds.
- first subsea device 210 may comprise a well head.
- second subsea device 210 may comprise a manifold.
- Jumper line 230 may be constructed out of any material suitable for use as a jumper line. Examples of suitable materials include carbon steel, allows of titanium and chrome, flexible pipes, or composite materials.
- Jumper line 230 may comprise one or more straight sections 231, one or more elbows 232, peak 233, and one or more end sections 235.
- the one or more straight sections 231 may be horizontal or vertical along a primary axis.
- the primary axis is defined as the horizontal line that is in line with the overall flow of hydrocarbons from first subsea device 210 to second subsea device 220.
- the one or more straight sections 231 may be inclined from 0 degrees to 90 degrees from the primary axis.
- the one or more straight sections 231 may be straight along the primary axis while incorporating a number of straight sections and elbows along a perpendicular axis.
- peak 233 is comprised of the one or more elbows 232.
- the one or more elbows 232 may comprise one or more connectors.
- jumper line configuration 200 does not comprise a valley defined by one or more peaks 233. Rather, in certain embodiments, the maximum elevation of jumper line configuration 200 occurs at peak 233, and no local maximum elevation occurs on either side of peak 233.
- jumper line 230 may further comprise one or more injection ports 236 wherein a hydrate inhibitor may be injected into the jumper line 230.
- the one or more injection ports 236 may be disposed on the one or more end sections 235.
- jumper line 230 may further comprises one or more valves 237 that allow the end sections of jumper line 230 to be drained or provide means to move gas from the first subsea device 210 to the second subsea device 220.
- the one or more valves 237 may be disposed on the one or more end sections 235 above the one or more injection ports 236.
- the one or more valves 237 may be disposed on the one or more ends sections 235 below the one or more injection ports 236.
- the one or more valves 237 may be tree valves.
- gas may segregate into the one or more peaks 233 of the jumper lines 230 and water may segregate into the one or more end sections 235 of jumper lines 230.
- the one or more valves 237 may be manipulated to drain the water from the one or more end sections 235, thus lowering the risk of forming hydrates when the lines are restarted.
- Figure 3A illustrates a side view of jumper line configuration 300
- Figure 3B illustrates a top view of jumper line configuration 300
- jumper line configuration 300 may comprise a first subsea device 310, a second subsea device 320, and a jumper line 330.
- Jumper line 330 may comprise straight section 331, one or more elbows 332, peak 333, and one or more end section 335.
- Jumper line 330 may further comprise one or more injection ports 336 and one or more valves 337.
- straight section 331 may be inclined with respect to the primary axis.
- peak 333 is comprised of a single elbow 332. Similar to jumper line configuration 200, jumper line configuration 300 does not comprise a valley defined by one or more peaks 333. Rather, in certain embodiments, the maximum elevation of jumper line configuration 300 occurs at peak 333, and no local maximum elevation occurs on either side of peak 333.
- jumper line 330 may comprise one or more secondary elbows 338. The one or more secondary elbows 338 may be arranged in a configuration that does not result in the formation of a valley in jumper line 330 along the primary axis.
- the one or more secondary elbows 338 may be in an axis perpendicular to the primary axis and produce one or more bends 339 in jumper line 330 in the same plane as the flow within the jumper line 330.
- the one or more secondary elbows 338 may provide flexibility to the jumper line configuration 300.
- the jumper line configuration discussed herein may have several advantages.
- One advantage is that the jumper line configurations discussed herein are able to provide bends without having valleys, thus increasing the flexibly while limiting the formation of hydrates.
- Another advantage is that using the jumper line geometry discussed herein, gas may segregate into the higher part so of the jumper line and water may segregate in the low sections, thus allowing water to be drained during shut ins.
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)
- Laying Of Electric Cables Or Lines Outside (AREA)
- Other Liquid Machine Or Engine Such As Wave Power Use (AREA)
- Optical Communication System (AREA)
- Earth Drilling (AREA)
- Pipeline Systems (AREA)
Abstract
Priority Applications (5)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US14/895,575 US20160130918A1 (en) | 2013-06-06 | 2014-06-04 | Jumper line configurations for hydrate inhibition |
EP14807984.1A EP3004520A4 (fr) | 2013-06-06 | 2014-06-04 | Configurations de conduites d'écoulement pour l'inhibition d'hydrates |
CN201480031987.1A CN105283625B (zh) | 2013-06-06 | 2014-06-04 | 用于抑制水化的跨接线构造 |
AU2014275020A AU2014275020B2 (en) | 2013-06-06 | 2014-06-04 | Jumper line configurations for hydrate inhibition |
BR112015030340A BR112015030340A8 (pt) | 2013-06-06 | 2014-06-04 | sistema de linha de escoamento |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US201361831911P | 2013-06-06 | 2013-06-06 | |
US61/831,911 | 2013-06-06 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2014197557A1 true WO2014197557A1 (fr) | 2014-12-11 |
Family
ID=52008553
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2014/040845 WO2014197557A1 (fr) | 2013-06-06 | 2014-06-04 | Configurations de conduites d'écoulement pour l'inhibition d'hydrates |
Country Status (6)
Country | Link |
---|---|
US (1) | US20160130918A1 (fr) |
EP (1) | EP3004520A4 (fr) |
CN (1) | CN105283625B (fr) |
AU (1) | AU2014275020B2 (fr) |
BR (1) | BR112015030340A8 (fr) |
WO (1) | WO2014197557A1 (fr) |
Families Citing this family (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB201414733D0 (en) * | 2014-08-19 | 2014-10-01 | Statoil Petroleum As | Wellhead assembly |
US11634970B2 (en) | 2020-01-28 | 2023-04-25 | Chevron U.S.A. Inc. | Systems and methods for thermal management of subsea conduits using a jumper having adjustable insulating elements |
US20210231249A1 (en) * | 2020-01-28 | 2021-07-29 | Chevron U.S.A. Inc. | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20030145997A1 (en) * | 2002-02-06 | 2003-08-07 | Gawain Langford | Flowline jumper for subsea well |
US6760275B2 (en) * | 1997-04-07 | 2004-07-06 | Kenneth J. Carstensen | High impact communication and control system |
US7296629B2 (en) * | 2003-10-20 | 2007-11-20 | Fmc Technologies, Inc. | Subsea completion system, and methods of using same |
WO2009079364A2 (fr) * | 2007-12-14 | 2009-06-25 | Baker Hughes Incorporated | Compresseur de gaz et pompe electriques immerges |
US8235121B2 (en) * | 2009-12-16 | 2012-08-07 | Dril-Quip, Inc. | Subsea control jumper module |
Family Cites Families (20)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US3825045A (en) * | 1972-08-22 | 1974-07-23 | Fmc Corp | Fluid delivery and vapor recovery apparatus |
US6022421A (en) * | 1998-03-03 | 2000-02-08 | Sonsub International, Inc, | Method for remotely launching subsea pigs in response to wellhead pressure change |
US7100694B2 (en) * | 2001-01-08 | 2006-09-05 | Stolt Offshore S.A. | Marine riser tower |
US7426963B2 (en) * | 2003-10-20 | 2008-09-23 | Exxonmobil Upstream Research Company | Piggable flowline-riser system |
US7219740B2 (en) * | 2004-11-22 | 2007-05-22 | Energy Equipment Corporation | Well production and multi-purpose intervention access hub |
US8215406B2 (en) * | 2006-02-03 | 2012-07-10 | Exxonmobil Upstream Research Company | Wellbore method and apparatus for completion, production and injection |
US7565932B2 (en) * | 2006-04-06 | 2009-07-28 | Baker Hughes Incorporated | Subsea flowline jumper containing ESP |
CA2664617C (fr) * | 2006-10-04 | 2012-08-28 | Fluor Technologies Corporation | Duse de production sous-marine double pour une production de puits haute pression |
US8469101B2 (en) * | 2007-09-25 | 2013-06-25 | Exxonmobil Upstream Research Company | Method and apparatus for flow assurance management in subsea single production flowline |
US8382457B2 (en) * | 2008-11-10 | 2013-02-26 | Schlumberger Technology Corporation | Subsea pumping system |
US8555978B2 (en) * | 2009-12-02 | 2013-10-15 | Technology Commercialization Corp. | Dual pathway riser and its use for production of petroleum products in multi-phase fluid pipelines |
US8863784B2 (en) * | 2010-04-22 | 2014-10-21 | Cameron International Corporation | Viscoelastic damped jumpers |
US9500247B2 (en) * | 2010-11-01 | 2016-11-22 | University Of Houston | Pounding tune mass damper with viscoelastic material |
WO2013027081A1 (fr) * | 2011-08-23 | 2013-02-28 | Total Sa | Ensemble tête de puits sous-marin, installation sous-marine utilisant l'ensemble tête de puits et procédé de complétion d'ensemble tête de puits |
US20130153038A1 (en) * | 2011-09-16 | 2013-06-20 | Andrew J. Barden | Apparatus and methods for providing fluid into a subsea pipeline |
AU2013254435B2 (en) * | 2012-04-26 | 2017-08-24 | Enpro Subsea Limited | Oilfield apparatus and methods of use |
US20160010434A1 (en) * | 2014-07-10 | 2016-01-14 | Baker Hughes Incorporated | Submersible Pump Assembly Inside Subsea Flow Line Jumper and Method of Operation |
US9739108B2 (en) * | 2014-09-02 | 2017-08-22 | Onesubsea Ip Uk Limited | Seal delivery system |
US9181786B1 (en) * | 2014-09-19 | 2015-11-10 | Baker Hughes Incorporated | Sea floor boost pump and gas lift system and method for producing a subsea well |
WO2016123340A1 (fr) * | 2015-01-30 | 2016-08-04 | Bp Corporation North America, Inc. | Échangeurs de chaleur sous-marins pour des mises en œuvre de production d'hydrocarbures en mer |
-
2014
- 2014-06-04 CN CN201480031987.1A patent/CN105283625B/zh not_active Expired - Fee Related
- 2014-06-04 WO PCT/US2014/040845 patent/WO2014197557A1/fr active Application Filing
- 2014-06-04 BR BR112015030340A patent/BR112015030340A8/pt not_active Application Discontinuation
- 2014-06-04 US US14/895,575 patent/US20160130918A1/en not_active Abandoned
- 2014-06-04 AU AU2014275020A patent/AU2014275020B2/en not_active Ceased
- 2014-06-04 EP EP14807984.1A patent/EP3004520A4/fr not_active Withdrawn
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US6760275B2 (en) * | 1997-04-07 | 2004-07-06 | Kenneth J. Carstensen | High impact communication and control system |
US20030145997A1 (en) * | 2002-02-06 | 2003-08-07 | Gawain Langford | Flowline jumper for subsea well |
US7296629B2 (en) * | 2003-10-20 | 2007-11-20 | Fmc Technologies, Inc. | Subsea completion system, and methods of using same |
WO2009079364A2 (fr) * | 2007-12-14 | 2009-06-25 | Baker Hughes Incorporated | Compresseur de gaz et pompe electriques immerges |
US8235121B2 (en) * | 2009-12-16 | 2012-08-07 | Dril-Quip, Inc. | Subsea control jumper module |
Non-Patent Citations (1)
Title |
---|
See also references of EP3004520A4 * |
Also Published As
Publication number | Publication date |
---|---|
BR112015030340A8 (pt) | 2019-12-24 |
AU2014275020A1 (en) | 2016-01-28 |
AU2014275020B2 (en) | 2017-04-27 |
CN105283625A (zh) | 2016-01-27 |
EP3004520A1 (fr) | 2016-04-13 |
CN105283625B (zh) | 2017-12-26 |
BR112015030340A2 (pt) | 2017-07-25 |
EP3004520A4 (fr) | 2017-01-25 |
US20160130918A1 (en) | 2016-05-12 |
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US9644457B2 (en) | Subsea processing of well fluids | |
US9835283B2 (en) | Polymeric device to protect pipe coupling | |
AU2012291947A1 (en) | Flexible pipe with injection tube and method for transporting a petroleum effluent | |
US8950498B2 (en) | Methods, apparatus and systems for conveying fluids | |
AU2014275020B2 (en) | Jumper line configurations for hydrate inhibition | |
BR112018074937B1 (pt) | Conjunto, método para uso de um módulo de controle de fluxo e sistema | |
EP3719249B1 (fr) | Équipement pour le raccordement de conduits sous-marins | |
KR101924777B1 (ko) | 해양플랜트 | |
US20170016309A1 (en) | Long offset gas condensate production systems | |
AU2017427811B2 (en) | Subsea system and method for pressurization of a subsea oil reserve by injecting at least one of water and gas | |
KR101924778B1 (ko) | 해양플랜트 | |
CN208381762U (zh) | 一种多功能油田原油输送单井管道系统 | |
US20240044435A1 (en) | Systems and methods for thermal management of subsea conduits using an interconnecting conduit and valving arrangement | |
US20210231250A1 (en) | Systems and methods for thermal management of subsea conduits using a self-draining jumper | |
BR102018068428B1 (pt) | Sistema não residente e método para despressurização de equipamentos e linhas submarinas | |
US10544630B1 (en) | Systems and methods for slug mitigation | |
KR20140055484A (ko) | 해저 생산플랜트에서의 해저 파이프라인 시스템 | |
US11767727B2 (en) | Mandrel multiplying device for subsea oil production apparatus | |
KR102113399B1 (ko) | 나선형 발열 해저 파이프라인 | |
US20120014751A1 (en) | Method of providing an outlet on a subsea pipeline | |
US11255165B2 (en) | Subsea arrangement | |
Giolo et al. | Subgas: A Dewpointing Solution To Improve Subsea Gas Fields Production | |
Basilio et al. | Flow Assurance With Water Heated Pipe-in-Pipe in Fields with High Gas Oil Ratio and High Wax Appearance Temperature | |
KR200480223Y1 (ko) | 원유 이송용 수평 수송관 | |
RU148609U1 (ru) | Подводная установка подготовки природного газа к транспорту |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
WWE | Wipo information: entry into national phase |
Ref document number: 201480031987.1 Country of ref document: CN |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application |
Ref document number: 14807984 Country of ref document: EP Kind code of ref document: A1 |
|
REEP | Request for entry into the european phase |
Ref document number: 2014807984 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2014807984 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 14895575 Country of ref document: US |
|
NENP | Non-entry into the national phase |
Ref country code: DE |
|
REG | Reference to national code |
Ref country code: BR Ref legal event code: B01A Ref document number: 112015030340 Country of ref document: BR |
|
ENP | Entry into the national phase |
Ref document number: 2014275020 Country of ref document: AU Date of ref document: 20140604 Kind code of ref document: A |
|
ENP | Entry into the national phase |
Ref document number: 112015030340 Country of ref document: BR Kind code of ref document: A2 Effective date: 20151203 |