EP0250162A2 - Déplacement des accumulations de liquides libres dans les canalisations - Google Patents

Déplacement des accumulations de liquides libres dans les canalisations Download PDF

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Publication number
EP0250162A2
EP0250162A2 EP87305168A EP87305168A EP0250162A2 EP 0250162 A2 EP0250162 A2 EP 0250162A2 EP 87305168 A EP87305168 A EP 87305168A EP 87305168 A EP87305168 A EP 87305168A EP 0250162 A2 EP0250162 A2 EP 0250162A2
Authority
EP
European Patent Office
Prior art keywords
foam
pipeline
fluid
pressurized
displace
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.)
Withdrawn
Application number
EP87305168A
Other languages
German (de)
English (en)
Other versions
EP0250162A3 (fr
Inventor
Joseph Dawson Fuller
Alan John Evett
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Nowsco Well Service Ltd
Texaco Ltd
Nowsco Well Service UK Ltd
Original Assignee
Nowsco Well Service Ltd
Texaco Ltd
Nowsco Well Service UK Ltd
Priority date (The priority date 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 date listed.)
Filing date
Publication date
Priority claimed from GB868615077A external-priority patent/GB8615077D0/en
Application filed by Nowsco Well Service Ltd, Texaco Ltd, Nowsco Well Service UK Ltd filed Critical Nowsco Well Service Ltd
Publication of EP0250162A2 publication Critical patent/EP0250162A2/fr
Publication of EP0250162A3 publication Critical patent/EP0250162A3/fr
Withdrawn legal-status Critical Current

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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
    • E21B21/14—Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using liquids and gases, e.g. foams
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17D—PIPE-LINE SYSTEMS; PIPE-LINES
    • F17D3/00—Arrangements for supervising or controlling working operations
    • F17D3/14—Arrangements for supervising or controlling working operations for eliminating water

Definitions

  • This invention relates to the displacement of free fluid accumulations left in generally horizontal portions of pipelines.
  • any offshore, hydrocarbon containing field such as one holding crude oil or gas
  • at least one platform or marine structure is installed at a judicious location within the known bounds of the field.
  • the primary functions of such a platform are at least twofold. Operationally, it serves as a base for drilling the neded number of wells into the subterranean reservoir to tap into the stored hydrocarbons. Secondly it functions to receive, treat, and store hydrocarbons which are conducted from other wells within the same field.
  • any productive field will usually contain numerous wells disposed about the ocean floor at various distancs from the main platform.
  • a number of pipelines are provided to extend across the seabed between the main platform and each satellite well site. These pipelines may include for each well a production pipeline, a test pipeline, a water injection pipeline, a gas lift pipeline and pipeline for utilities. After initial installation, at least some of these pipelines, in particular the gas lift pipeline, will require to be flushed out to remove water accumulated in sections of the pipeline extending generally horizontally across the seabed and filling a substantial proportion of the volume of such sections. Such sections may be inclined to the horizontal owing to the unevenness of the seabed so that there may be pockets of water accumulated at intervals spaced along the pipeline. It is also important to prevent the formation of hydrates which is likely to occur in subsequent use of the pipeline particularly in cold environments resulting in blockage of the pipeline especially at restricted sections thereof.
  • a pig Conventionally such accumulations of water are removed by introducing a pig into the pipeline and applying a pressurized liquid into the pipeline to move the pig therethrough to physically displace the water.
  • the pig may be mechanical or made of a gelled material to allow it to conform to the internal surface of the pipeline.
  • some pipelines are unsuitable for use of a pig, for example where the pipeline is formed with various internally extending obstructions which would tend to cause the pig to break up or where abrasives would cause an unacceptable loss of material.
  • the invention seeks to provide an expedient and economical method for removing free fluid accumulations in pipelines which can be applied to pipelines in which it is either not readily practicable to use a pig or where the invention offers a choice to using a conventional pig.
  • the invention provides a method for treating a pipeline which contains a residual amount of fluid in a generally horizontal section or sections therof, to displace the residual fluid therefrom, which method comprises:- injecting into the pipeline a pressurized, high expansion foam having a high refoamability and being compatible with said fluid in the pipeline section(s), which foam contains an amount of foaming agent in excess of the minimum amount thereof required to generate the foam; advancing the foam through the, or each, of said pipeline sections in contact with a layer of said fluid left therein to displace said fluid towards a remote end of the pipeline by entrainment caused by frictional pick-up of the layer by said foam and to effect mass transfer of said foaming agent from said foam to said fluid; discontinuing injection of said foam; and passing into the pipeline a pressurized gas to create turbulence in said fluid containing said foaming agent, which is left in the, or each, of said pipeline sections causing foaming of said fluid within the pipeline and to displace a substantial proportion of the foam left within the pipeline from a remote end thereof
  • high expansion foam we mean a foam having at least a 75% gas phase content by volume. Preferably the foam will have at least a 98% gas phase content.
  • high refoamability we mean the tendency to refoam to a foam volume greater than about 80% of the original. This is a measure of "repeatability" in foaming.
  • ком ⁇ онент we mean a foam which does not rapidly break down when put in direct contact with the fluid to be displaced at the temperatures and pressures existing in the pipeline during a treatment in accordance with the invention, and which has a foaming agent capable of foaming the fluid accumulation(s) in the pipeline.
  • the "first mechanism" is a condition where the foam passes above a layer of liquid in the pipeline and, as described above, entrains that layer of liquid and also transfers thereto a foaming agent contained in the foam to allow the fluid to be readily foamed by the subsequent passage of a pressurized gas through the pipeline which also serves to displace a substantial portion of the foam left within the pipeline.
  • the main bulk of such fluid may be initially removed by a mechanical "piston" displacement which will be referred to herein as a "second mechanism".
  • a transverse foam/fluid interface is established within the pipeline and is advanced through the pipeline at or above a minimum velocity which is required to maintain the interface so that the bulk of the fluid is removed from the remote end of the pipeline by physical displacement, leaving the above-mentioned residual amount of fluid in the pipeline which is thereafter treated in accordance with the "first mechanism".
  • the aforesaid minimum velocity required to maintain the transverse foam/fluid interface which will be referred to as the "critical velocity" depends on factors such as the pipe diameter, the viscosity and density of the phases and therefore varies from application to application.
  • critical velocity the aforesaid minimum velocity required to maintain the transverse foam/fluid interface
  • a relatively small amount of foaming agent for example 1 ⁇ 2% by volume, is required in the liquid phase of the foam in order to generate the foam when contacted with the gas phase but this concentration is variable depending on the nature of the gas and liquids in the system.
  • an excess amount of foaming agent is used in order to achieve foaming of the residual fluid left in the pipeline for removal thereof by the subsequent injection of pressurized gas, which may be the same gas as that used for the gaseous phase of the foam.
  • pressurized gas which may be the same gas as that used for the gaseous phase of the foam.
  • the foaming agent may be provided in an amount of about 1 - 4 % by volume of the liquid phase of the foam.
  • the foaming agent may be provided in an amount of about 5 - 15 % by volume of the liquid phase of the foam.
  • the invention makes it possible to displace a fluid which will usually, but not exclusively, be a Newtonian fluid from a pipeline using a high expansion foamed fluid of chosen rheological properties as an interface between the in-situ fluid to be displaced and the displacing medium when the fluid displacement speed is at or above a defined "critical velocity" for the particular application so that the in-situ fluid is maintained in a state of extreme excitation such that, despite gravity, momentum effects ensure that the fluid travels totally in the direction of displacment with a minimum amount of in-situ fluid draining back into the foam.
  • a fluid which will usually, but not exclusively, be a Newtonian fluid from a pipeline using a high expansion foamed fluid of chosen rheological properties as an interface between the in-situ fluid to be displaced and the displacing medium when the fluid displacement speed is at or above a defined "critical velocity" for the particular application so that the in-situ fluid is maintained in a state of extreme excitation such that,
  • a method according to the invention uses a high expansion foam in order to minimize the quantity of foam drain-off fluid left on the wall of the pipeline.
  • the use of low viscosity, very low surface tension foaming agents with good refoamability ensures refoaming of any residual drain-off fluid when using a compatible gaseous displacement medium at the specified critical velocity.
  • a method according to the invention is more widely applicable than to dewatering pipelines communicating between a main oil drill platform and associated satellite well sites. It could be used to remove other Newtonian or nearly Newtonian fluids from pipelines. For example, the method could be used to remove hydrocarbon condensates from other gas carrying pipelines having generally horizontal sections, or for removing solid particles carried in a free liquid accumulation left in other fluid pipelines.
  • nitrogen is the preferred gas used in the aforesaid method
  • other gases for example air or gaseous hydrocarbons, could be used in other applications provided that the gas is compatible with the fluid to be removed from the pipeline.
  • the method includes the further step of introducing a pressurized, turbulent flow of a foamed fluid containing the surface treatment medium to displace any residual foam left in the pipeline, and then allowing such foam to decompose in the pipeline.
  • a pressurized, turbulent flow of a foamed fluid containing the surface treatment medium to displace any residual foam left in the pipeline, and then allowing such foam to decompose in the pipeline.
  • Such a method could also be used to render inert pipelines which are no longer required after production at one site has been completed. All potentially harmful materials are thereby removed from the pipeline which can then be capped and buried in a safe condition.
  • the residual foam left in the pipeline is thereby displaced by the methanol or IPA foam enabling most of the water still present in the line to become mixed with the methanol or IPA, which will help to reduce hdyrate formation at a later date.
  • the front of methanol foam is displaced at least to the end of the line and all the foam is then allowed to decompose, having a short half life, thus ensuring that the methanol drops out and is distributed along the required length of the line.
  • Any loose debris in the free liquid contained in the pipeline is generally also carried and removed from the line.
  • Advantages of using such a method according to the invention for dewatering a pipeline over the above-­described conventional method include the facility to entrain in the foam and remove particulate debris in the pipeline, the economic use of a pressurized gas as the displacing medium as compared to pressurized liquid displacement of a pig and the facility to render inert the interior of a pipeline to prevent corrosion occurring after shutdown.
  • Possible applications of methods according to the invention include removing water from pipelines and vessels; removing condensate and crudes from pipelines and vessels; laying down an inhibitor coating along a pipeline; removing hydrocarbons from pipeline depressions during commissioning; and, purging of pipelines and vessels for field abandonment and decommissioning.
  • removing water from pipelines and vessels removing condensate and crudes from pipelines and vessels; laying down an inhibitor coating along a pipeline; removing hydrocarbons from pipeline depressions during commissioning; and, purging of pipelines and vessels for field abandonment and decommissioning.
  • As most fluids can be foamed there are a number of other possible applications, specifically in subsea multi-diameter systems.
  • a marine platform or structure 10 is positioned at an offshore body of water.
  • the structure is judiciously locatd to best produce a hydrocarbon containing field or reservoir within the underlying substrate.
  • the platform includes primarily a deck which is normally positioned 15 to 7 metres beyond the water level.
  • the deck in the usual manner, will accommodate the means for drilling wells, receiving and treating produced hydro­carbons, and housing personnel necessary to operate the facility.
  • the deck supports storage means such as tanks, separators, and other facilities whereby the liquid and gaseous hydrocarbons can be initially treated and stored before being transshipped to shore. The latter can be achieved through the use of pipelines which extend form the platform (10) to the shore. Alternatively, tankers and other cargo carrying vessels capable of loading at the platform can be utilized to convey the hydrocarbon fluid.
  • a subsea production facility (11) comprising an oil well drilling template having a fluid manifolding system including a ring main (50) for a passing gas lift fluid to the well (12) and a ring main (51) for passing production fluids from the well (12).
  • the subsea template (11) is connected to the main platform (10) by a series of pipelines extending along the bottom of the sea, of which only the main gas lift line (13) and the production test line (14) are illustrated in Fig. 1.
  • the gas lift line (13) communicates with the main platform (10) through a flexible riser (15). It communicates at its other end with the ring main (50) on the template through a disconnect assembly comprising a reducing spool (16), non-return valves (17,18) with a disconnect unit (19) therebetween, a manual gate isolation valve (20), and a flexible jumper lead (21).
  • FIG 2 illustrates equipment installed on the main platform (10) for supplying foamed liquids to the gas lift pipeline (13) for passing therethrough and via the ring mains (50,51) on the template (11) through the production pipeline (14) to dewater both pipelines.
  • the equipment in this case comprises a number of 150,000 scf nitrogen tanks (70) and a nitrogen pumping unit (71) connectable through gas lin (72) to a conventional foam generating T-piece (52).
  • a liquid line (53) is provided for supplying liquid to the foam generating device from a pump (54).
  • the pump (54) is connectable either through line (57) to a water storage tank (55) which in turn is connected to a storage tank (73) for a surfactant to deliver an aqueous liquid containing the surfactant for supply by the pump (54) to the foaming device (52).
  • the pump (54) is also selectively connectable to a further tank (56) for containing methanol.
  • the foam generating device (52) has a foam outlet line (60) connectable to supply foam to the main gas lift pipeline (13) at a pressure sufficient to effect displacement of residual water therein by a method in accordance with the invention.
  • Liquid surfactant and water is supplied to the foam generating device (52) to produce a pressurized, high expansion nitrogen foam which is introduced into the pipeline (13).
  • One of the characteristics of nitrogen foam is its ability to continually reform and regenerate itself. For this to occur though, the foam is displaced continuously in turbulent flow through the pipeline.
  • This mixture of displacement and entrainment is used to dewater the pipeline (13). Any small items of loose debris will also be carried forward and removed from the line by the viscous, turbulent flow. After completion of this process the pipeline is essentially filled with a water/surfactant foam. A pressurized high velocity flow of nitrogen gas is passed through the pipeline to foam up the liquid with surfactant therein and then to remove the bulk of the foam.
  • the residue of the foam is displaced by a methanol foam when methanol from tank (56) is supplied by pump (54) to the foam generating device (52).
  • This foam is injected down the length of the complete line, to create turbulence in some of the residual water causing it to foam and to be physically displaced.
  • the bulk of the foam remains in the pipeline and is then allowed to decompose into its liquid and gas constituents in the pipeline. Any trace water still present is dosed with the methanol, helping to prevent hydrate formation once hydrocarbon gases are injected into the line.
  • the required amount of methanol in the foam is influenced by the volume needed to dose the water remaining in the pipeline to a sufficiently high concentration in order that hydrates are prevented from forming under the pressure and temperature operating conditions of the pipeline.
  • the nitrogen foam can be injected in the line from the platform, immediately after the determination of free fluids has been undertaken. All of the equipment can be platform based subject to size limitations enabling this operation to be undertaken and the results evaluated prior to calling for a vessel with the relatively large quantities of methanol to be used.
  • a pig may be used in the pipeline to separate fluids and gases from the foam.
  • the gas lift pipeline is a multi-diameter pipeline.
  • the following table gives examples of diameter variations thereof:-
  • the sequence of the dewatering method in accordance with the method used to dewater the pipeline is as follows.
  • a first phase in which a nitrogen purge of the pipeline was carried out to purge hydrocarbons, to carry out pressure/volume correlations to indicate the volume of liquids left in the line, and to identify maximum flowrates through any chokes and see if this will be an obstacle to carrying out the planned foam displacement method.
  • a second phase in which dewatering of the pipeline is carried out using aqueous foam to effect bulk dewatering of the gas lift line.
  • a third phase in which methanol foam is passed through the line to dose the entire length of the gas lift line with methanol.
  • a fourth phase in which gas lift is commenced into the well (12) at the remote subsea production facility, leading to startup of production from the well (12).
  • the nitrogen purge was carried out at pressures of between 150 and 210 psia at the main platform end of the gas lift line. Flowrates averaged 300 scf/min. and the temperature of the pipeline was about 40°F (4°C).
  • the surfactant used was SF12 (NOWSCO) which is an ammonia salt of an alcohol ethyoxylate sulphate. This surfactant is available from NOWSCO WELL SERVICES (UK) Limited.
  • Figs. 3 and 4 graphically illustrate the pressure in the gas lift line at the main platform end thereof, during the two treatments respectively.
  • Figure 5 is a graph of recorded values and a clear change in gradient is seen which would be expected with a change in phase.
  • the gas lift line was vented to the sea. Foam generation was stopped and nitrogen at about 3000 scf/min for 20 minutes was pumped to try and maximize turbulence and achieve as much foam regeneration as possible.
  • the slug catcher was emptied in batch-mode four times during the aqueous foam treatments. Of these, the first two batches were all oil but the last two were nearly all water.
  • the base sediment and water (BS&W) readings were 0%, 3%, 100% and 98% respectively. An estimated 300 bbl of water was removed. Further water remained in the test line and was recovered in Phases 3 and 4.
  • the methanol foam was mixed and pumped at the lowest pressures the system would allow in order to maximise velocities for a given nitrogen injection rate and to ensure the flowrates were within the capacity of the gas lift chokes.
  • the starting pressure was about 100 psia and about 350 psia at the end of pumping.
  • the treatment was sufficiently controlled that no peaks occurred in the pressure response which was one indication that the line was substantially clear of liquids.
  • the surfactant used was a methanol foamer called FC431 available from the 3M Company. It is a fluoro-carbon methanol foamer.
  • the foaming agent is generally present in an amount of about 1-25% (vol), e.g. 5% (by vol), of the liquid phase of the foam.
  • Lift gas was introduced into the gas lift line at pressures up to 1750 psig.
  • a 12 bbl slug of methanol had been left at the base of the riser (15) at the conclusion of the methanol foam treatment phase.
  • a further slug of 20 bbls was introduced at the start of hydrocarbon gas pumping to further treat any liquids that may have collected, and also to fully saturate gas entering the line.
  • Methanol dosing of the gas was started at a higher-­than-normal rate of 5 gal/min. This lasted for just under 7 hours.
  • Pressure build-up in the gas line was at the rate of about 30 psi every 10 mins, with a gas flow rate of about 4 mmscfpd.
  • pressure was built up to about 650 psi against the valve in the gas lift line located where it goes onto the template and then against valve in the test line as it exits from the template up to about 1100 psi.
  • the gas lift valve position in the well (12) is at 4110 ft BKB (540 ft).

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  • Engineering & Computer Science (AREA)
  • Mechanical Engineering (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Fluid Mechanics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Physics & Mathematics (AREA)
  • General Engineering & Computer Science (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Pipeline Systems (AREA)
  • Application Of Or Painting With Fluid Materials (AREA)
  • Sampling And Sample Adjustment (AREA)
  • Vaporization, Distillation, Condensation, Sublimation, And Cold Traps (AREA)
EP19870305168 1986-06-20 1987-06-11 Déplacement des accumulations de liquides libres dans les canalisations Withdrawn EP0250162A3 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
GB8615077 1986-06-20
GB868615077A GB8615077D0 (en) 1986-06-20 1986-06-20 Removal of free fluid accumulations in pipelines
GB8622364 1986-09-17
GB8622364A GB2191841B (en) 1986-06-20 1986-09-17 Displacement of free fluid accumulations in pipelines

Publications (2)

Publication Number Publication Date
EP0250162A2 true EP0250162A2 (fr) 1987-12-23
EP0250162A3 EP0250162A3 (fr) 1991-02-20

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Family Applications (1)

Application Number Title Priority Date Filing Date
EP19870305168 Withdrawn EP0250162A3 (fr) 1986-06-20 1987-06-11 Déplacement des accumulations de liquides libres dans les canalisations

Country Status (6)

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EP (1) EP0250162A3 (fr)
CN (1) CN87104321A (fr)
AU (1) AU585453B2 (fr)
BR (1) BR8703089A (fr)
DK (1) DK315687A (fr)
NO (1) NO872553L (fr)

Cited By (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1059482A1 (fr) * 1999-06-08 2000-12-13 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Procédé et dispositif de mise en gaz d'une ligne de distribution de gaz corrosif
CN114575809A (zh) * 2022-03-28 2022-06-03 普斐特油气工程(江苏)股份有限公司 油气井口智能泡排系统装置

Families Citing this family (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
CN102698995B (zh) * 2012-06-28 2014-04-30 唐山三友化工股份有限公司 利用清洗气冲洗碳化塔水箱的方法
GB201414733D0 (en) * 2014-08-19 2014-10-01 Statoil Petroleum As Wellhead assembly
US20210340469A1 (en) * 2020-04-30 2021-11-04 Ashley Zachariah Method to remove explosive and toxic gases and clean metal surfaces in hydrocarbon equipment

Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3773110A (en) * 1972-08-14 1973-11-20 Continental Oil Co Method of removing liquids and small solids from well bores
US3819519A (en) * 1968-11-27 1974-06-25 Chevron Res Foam circulation fluids
GB2023270A (en) * 1978-06-13 1979-12-28 Vickers Ltd Drying cavities

Family Cites Families (2)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4133773A (en) * 1977-07-28 1979-01-09 The Dow Chemical Company Apparatus for making foamed cleaning solutions and method of operation
US4419141A (en) * 1982-04-05 1983-12-06 Weyerhaeuser Company Cleaning labyrinthine system with foamed solvent and pulsed gas

Patent Citations (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3819519A (en) * 1968-11-27 1974-06-25 Chevron Res Foam circulation fluids
US3773110A (en) * 1972-08-14 1973-11-20 Continental Oil Co Method of removing liquids and small solids from well bores
GB2023270A (en) * 1978-06-13 1979-12-28 Vickers Ltd Drying cavities

Cited By (5)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP1059482A1 (fr) * 1999-06-08 2000-12-13 L'air Liquide, Societe Anonyme Pour L'etude Et L'exploitation Des Procedes Georges Claude Procédé et dispositif de mise en gaz d'une ligne de distribution de gaz corrosif
FR2794844A1 (fr) * 1999-06-08 2000-12-15 Air Liquide Procede et dispositif de mise en gaz d'une ligne de distribution de gaz corrosif
US6499502B1 (en) 1999-06-08 2002-12-31 L'air Liquide, Societe Anonyme A Directoire Et Counseil De Surveillance Pour L'etude Et L'exploitation Des Procedes Georges Claude Method and device for filling a distribution line with corrosive gas
CN114575809A (zh) * 2022-03-28 2022-06-03 普斐特油气工程(江苏)股份有限公司 油气井口智能泡排系统装置
CN114575809B (zh) * 2022-03-28 2022-11-25 普斐特油气工程(江苏)股份有限公司 油气井口智能泡排系统装置

Also Published As

Publication number Publication date
BR8703089A (pt) 1988-03-08
DK315687A (da) 1987-12-21
EP0250162A3 (fr) 1991-02-20
NO872553L (no) 1987-12-21
AU7429887A (en) 1987-12-24
CN87104321A (zh) 1988-03-23
DK315687D0 (da) 1987-06-19
NO872553D0 (no) 1987-06-18
AU585453B2 (en) 1989-06-15

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