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US3559739A - Method and apparatus for providing continuous foam circulation in wells - Google Patents

Method and apparatus for providing continuous foam circulation in wells Download PDF

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Publication number
US3559739A
US3559739A US835268A US3559739DA US3559739A US 3559739 A US3559739 A US 3559739A US 835268 A US835268 A US 835268A US 3559739D A US3559739D A US 3559739DA US 3559739 A US3559739 A US 3559739A
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United States
Prior art keywords
foam
tubing string
chamber
tubing
well
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.)
Expired - Lifetime
Application number
US835268A
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English (en)
Inventor
Stanley O Hutchison
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Chevron USA Inc
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Chevron Research and Technology Co
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    • 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
    • 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
    • E21B19/00—Handling rods, casings, tubes or the like outside the borehole, e.g. in the derrick; Apparatus for feeding the rods or cables
    • E21B19/16—Connecting or disconnecting pipe couplings or joints
    • 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
    • E21B21/01—Arrangements for handling drilling fluids or cuttings outside the borehole, e.g. mud boxes
    • E21B21/019—Arrangements for maintaining circulation of drilling fluid while connecting or disconnecting tubular joints
    • 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
    • E21B21/02—Swivel joints in hose-lines
    • 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
    • E21B33/068—Well heads; Setting-up thereof having provision for introducing objects or fluids into, or removing objects from, 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
    • E21B37/00—Methods or apparatus for cleaning boreholes or wells

Definitions

  • tub- [56] References Cited ing string is held by slips with its open end in the lower portion V UNITED STATES PATENTS of the chamber.
  • the upper tubing section is lifted in the 1,586,923 6/1926 Townsend 166/77 chamber to above the valve.
  • the valve is closed and foam is 2,096,882 10/ 1937 Chernosky 166/81 circulated in the chamber through the foam entry port to pro- 2,522,444 9/1950 Grable 166/81 vide for continuous foam circulation while another section of 2,670,225 2/1954 McKinney 1 66/77X tubing is added or removed from the tubing string.
  • This invention relates to a method and apparatus for providing continuous foam circulation in a well during drilling or workover operations and, more particularly, this invention provides for maintaining continuous circulation in a segmented tubing string and the annulus between the tubing string and the well wall during makeup or breakup of the tubing string as it is lowered or raised in the well to accomplish well cleanout, drilling or the like.
  • Well cleanout which includes the removal of drill chips. sand or other unconsolidated materials and fluids from a well has long been a problem.
  • the removal from a well of drilled solids produced while penetrating a formation with a drilling string and also the removal of the solids which flow into the well during oil production have both continued to be a problem to the oil industry. This is particularly true when formations penetrated during drilling or from which fluids are produced, are unconsolidated low-pressure formations.
  • Various techniques, including the use of wire line bailers and various circulating fluids have heretofore been suggested for removing such material from wells.
  • One such circulating fluid found successful in such operations is a stable, low density foam. Foam of this type has proven quite successful in removing solids and fluids from wells. However, it has been found that certain techniques must be utilized to overcome problems encountered in the use of foam as a circulating fluid for removing sand and the like from a well.
  • One such technique is disclosed and claimed in the above noted application Ser. No. 807,766. In this technique, the foam in the tubing string is maintained for a period of time in a dynamic condition by certain one-way valve means provided in the tubing string. This method has proven successful. However, it has also been found that where delays may be encountered in changing tubing or if downtime is likely to occur it is desirable to provide for continuous circulation of foam during makeup or breakup of the tubing string.
  • a segmented tubing string is used to inject foam down a well to the position in the well from where it is desired to remove sand and/or produced fluids.
  • the foam picks up the sand or fluids and carries them out of the well via the tubing-well wall annulus.
  • a tubing string is made up of a plurality of individual pipe sections coupled together.
  • a rig or hoist is used to lower each successive pipe section into the well to approximately its full length. After the pipe section has been lowered to such a position, it is gripped near its upper end by various means such as slips to suspend it in the well.
  • the hoist is then released from the pipe section and a second pipe section is connected to the first section.
  • the hoist is then connected to the second pipe section and the slips released from the hanging tubing string and it is lowered further into the well to near the full extent of the second pipe section when the slips are again applied and the above sequence repeated.
  • successive pipe sections form a tubing string whichprogressively sively goes deeper and deeper into the well.
  • foam As foam is circulated, it carries up the fluids and/or sand and chips from the well.
  • the tubing string during this foaming period is progressively lowered deeper into the well. This necessitates, of course, adding additional pipe sections to the tubing string at the wellhead.
  • the flexible foam tube When such pipe sections are added, the flexible foam tube must be disconnected from the top pipe section forming the uppermost joint of the tubing string and reconnected to the top of the newly connected pipe section. Thus for a short time foam circulation down the tubing is stopped. It has been found necessary. however, to prevent backflow of foam up the tubing string and consequent collapse of foam in the tubing stringcasing annulus. lf foam is allowed to backflow up the tubing, uncomfortable and dangerous conditions will exist at the wellhead.
  • the present invention provides a method and apparatus for continuously circulating foam in a well through a segmented tubing string while the tubing string is being made up or broken up.
  • the invention permits maintaining continuous circulation during such makeup or breakup-normal circulation down the tubing string and up the well annulus or reverse circulation down the well annulus and up the tubing string.
  • a foam source is provided with a conduit connecting it to a tubing string through an appropriate coupling known as a pup joint.
  • a chamber is formed around the tubing string above the wellhead and is provided with a port through which foam can be injected into the chamber or, if circulation is reversed, from which foam can be removed from the chamber.
  • the ends of the chamber permit sliding movement of the tubing string therethrough while preventing escape of foam from the chamber.
  • the joint that is desired to disconnect is opened in the chamber while in the case of normal circulation foam is also injected into the chamber through the port provided for such purpose and then into the open end of the tubing string and then down the tubing string.
  • the port is opened to provide flow of foam from the chamber.
  • the pup joint is lifted up the chamber above the valve means and the lower half of the chamber is then isolated.
  • the foam is flowed out of the chamber through the port until the new tubing section is connected.
  • normal circulation foam injection is stopped from said foam source through the pup joint and the pup joint is removed from the chamber.
  • foam is continuously circulated through the foam entry port into the chamber and then into the open end of the tubing string and down the string into the well.
  • a new section of tubing is connected to the pup joint and is inserted into the upper half of the chamber and foam is injected therein.
  • the valve means is then opened to open the chamber and the new tubing is inserted and connected to the tubing string. After such connection is made, foam injection through the port in the chamber is stopped, the
  • the present invention provides for maintaining continuous foam circulation while connecting or disconnecting a pipe section to the tubing string.
  • a chamber is formed above the wellhead around the tubing string and the ends of the chamber are provided with resilient means which allow passage of the tubing string in both an up and down direction therethrough.
  • the resilient means frictionally engage against the tubing in a manner to prevent flow of foam from the chamber.
  • the chamber is provided with a foam port and a valve is provided for closing off the chamber to flow above such port.
  • the connection to be broken is positioned in the chamber below such valve and foam is injected through the foam entry port into the chamber at least the injection pressure of the foam circulating down the tubing.
  • connection is then broken by suitable means'such as a power swivel or power tongs, and the top section of pipe is raised up to above the valve.
  • the valve is closed to close off the upper portion of the chamber and foam injection through the top section of pipe is stopped.
  • This top section may then be removed from the chamber and a new pipe section added thereto. Meanwhile foam is continuously circulated from the chamber down the tubing.
  • foam leaves the chamber through the entry port while the tubing section is being made up.
  • the new section of pipe is connected to the top section. its lower end is inserted into the chamber and foam is injected therethrough.
  • the valve is opened to open the chamber and the new pipe section is lowered and connected into the tubing string. After such connection is made, foam injection into the chamber is stopped and the tubing string is lowered further into the hole while foam injection continues down the tubing.
  • the apparatus of the present invention provides continuous circulation through a tubing string extending into a well and the annulus formed between the exterior of the tubing string and the well casing during makeup of the tubing string.
  • the apparatus includes a tubular shell having a diameter greater than the diameter of tubing run in the well.
  • the tubular shell has an open upper end and an open lower end.
  • Resilient stripper means are fixedly connected in the ends of the tubular shell to slidably engage against the tubing string contained therein to cooperate with said tubing to close off the ends of said tubular shell to form a closed annular chamber.
  • Means for flowing foam into or out of the lower portion of the annular chamber are provided.
  • Gate valve means are located in the annular chamber above the foam entry means for closing off the annular chamber to longitudinal flow in the absence of tubing therein.
  • a wellhead having tubing hanging means and means for fixedly connecting the tubular shell to the wellhead in axially aligned, spaced apart relationship with the entry for tubing into said wellhead are also provided in accordance with the invention.
  • a particular object of the present invention is to provide for continuous circulation of foam in a well during foam cleanout or the like while a tubing string is being made up or broken up. Further objects and advantages of the present invention will become apparent from the following detailed description read in light of the accompanying drawings which are made a part of this specification.
  • FIG. 1 is a view, with parts broken away for clarity of presentation, of the preferred embodiment of apparatus assembled in accordance with the invention in which foam is injeeted through a tubing string into a well
  • FIG. 2 is a view, with parts broken away for clarity of presentation, of the preferred embodiment of apparatus in which foam is injected into the foam chamber and thence into the tubing string while a new section of tubing is being added.
  • FIG. 1 DESCRIPTION OF THE PREFERRED EMBODIMENT
  • the preferred embodiment is described with regard to maintaining normal circulation in the well.
  • normal circulation exists when fluid is injected down the tubing string and up the well annulus.
  • foam is being injected from a foam source 18 down a string of tubing 20 to a location in a well indicated generally by a number 22 from where it is desired to remove produced fluids and/or solids. This might be desirable, for example. in a well cleanout operation.
  • the circulating medium such as foam is circulated down the segmented tubing string 20 and up the well annulus 24 formed between the outside of the tubing string 20 and the well casing 26.
  • the foam carries the solids and fluids up the well annulus and out blooie line 28 to a suitable sump (not shown) at the surface.
  • a valve 30 is located on the blooie line 28 and is normally left open.
  • the wellhead 32 includes a suitable tubing head 34 having a collar 36 which contains a suitable fitting 38 for the blooie line and a fitting 40 for an emergency foam line 42 which is connected through valve 44.
  • the emergency foam line is located below the wellhead equipment and is intended for emergency use such as might be caused by a downhole fire.
  • a wellhead base plate 46 having a central opening for the tubing string therethrough is connected to the top of the collar 36.
  • a stripper rubber 48 is located in the collar 36 to frictionally engage the tubing string therein in a liquid-tight manner to prevent flow of foam through the wellhead collar past the tubing string.
  • Tubing hanging slips 50 are arranged around the tubing string 20 above the base plate 46.
  • the tubing slips are used to hang the tubing on the wellhead while it is disconnected from the pup joint and the power swivel.
  • a chamber is formed about the tubing string 20 above the wellhead by a tubular shell 52 which is larger in diameter than the tubing string 20.
  • the shell 52 is positioned around the tubing string and located above the slips 50 on the wellhead.
  • the tubular shell 52 thus forms a chamber around the tubing string above the wellhead.
  • the ends 53 and 55 of the tubular shell 52 contain stripper rubbers 54 and 56 which slidably engage the tubing string so as to prevent foam from leaving the chamber by passing along the outside of the tubing string.
  • a fluidtight chamber is formed about the tubing string by the cooperation of the shell and the sealed ends.
  • a foam entry is provided into the chamber by port 58 in the shell 52.
  • the entry port 58 is located near the lower end portion of the tubular shell 52.
  • a valve indicated generally by the number 60 is arranged intermediate the ends of the tubular shell 52 and has the capability of closing off flow up the chamber in the absence of the tubing string.
  • the chamber may thus be divided into two separate compartments.
  • the foam entry port 58 is connected to the foam source 18 by means of a suitable conduit 64.
  • Valve 66 controls flow of foam from the foam source 18 through line 64 to foam entry port 58. By controlling the valves foam may be injected as desired into the chamber formed about the tubing string.
  • the wellhead 32 and the tubular shell 52 which forms the chamber about the tubing string are connected in vertically aligned, spaced apart relationship by suitable means such as a plurality of centralizing and supporting arms 68.
  • the tubular shell 52 must be securely anchored in position while foam is injected therein under high pressure.
  • the centralizing and supporting arms 68 serve to align and to support the tubular shell 52 in such a manner by connecting the supporting arms 68 to the wellhead. In this mode the weight of the tubing string 20 hanging from the wellhead serves as an anchor for the tubular shell 52. It is usually preferred to have three spaced apart supporting arms 68 to connect the tubular shell to the wellhead.
  • foam is provided for injection down tubing string 20 by a suitable foam source 18.
  • foam source 18 is connected to a pup joint 70 located in power swivel 72 by means of a suitable flexible conduit 74.
  • Valve 75 controls foam flow through conduit 74.
  • a bleed down line 76 having valve 78 is provided on the conduit 74.
  • the foam in injected from the foam source 18 into the tubing string 20 down the well and up the annulus to the surface.
  • the tubing string 20 is progressively lowered into the well as the cleanout goes on to a point where the upper end of the tubing string 20 which is connected to the pup joint 70 at connection 80 is located in the lower portion of tubular shell 52.
  • connection 80 was at one time located well above the upper end 53 of the shell 52 and as the tubing string 20 was lowered by lowering the power swivel 72 the connection 80 was lowered to its present position.
  • connection 80 has reached such a position, it is time to disconnect the pup joint 70 from the tubing string and to add a new joint of tubing to the up pup joint 70 for connection to the top of the tubing string 20.
  • foam injection through the pup joint and thence into the tubing string 20 during this period must be stopped. Utilizing the apparatus of the present invention, however, foam injection through the tubing string 20 need not be halted during this period.
  • connection 80 is now located in the shell 80 in aposition where it should be broken.
  • foam under pressure must be supplied to the chamber formed by shell 52 about the upper end of the tubing string.
  • bleed down valve 82 on the alternate foam conduit 64 is closed.
  • alternate foam valve 66 is opened to cause foam to flow from foam source 18 through conduit 64 and entry port 58 into the chamber formed by shell 58 about the tubing string 20.
  • Bleed valve 84 on chamber bleed line 86 is also closed at this time.
  • the tubing hang slips 50 are set so as to be ready to hang the tubing string 20 on the wellhead when it is disconnected from the power swivel and hoist.
  • connection 80 between the upper end of tubing string 20 and the lower end of the pup joint 70 is now broken by suitable means such as reversing the power swivel to rotate the pup joint and unscrew the connection.
  • the power swivel 72 is then raised by a hoist means to lift the bottom of the pup joint 70 up the chamber to a position above gate valve 60. This position is illustrated in FIG. 2.
  • the end of the pup joint 70 is maintained in the chamber between gate valve 60 and the stripper rubber 54 in the upper end of tubular shell 52.
  • Valve 60 is now closed as indicated in FIG. 2 to close off the upper part of the chamber to the flow of foam.
  • Foam circulation in the well is maintained through the upper end of the tubing string 20 by the foam entering shell 52 through line 64.
  • valve 75 is closed to stop foam flow in the main foam line and pressure is bled from the pup joint system 70 through lines 76 and 86 by opening valves 78 and 84.
  • the dual bleed lines give additional assurance that complete bleed down will occur.
  • the pup joint 70 is now removed from the chamber formed by shell 52 and a new joint of tubing is connected to the lower end of the pup joint. The lower end of this new joint of tubing is then inserted through the upper stripper rubber 54 into the upper portion of the chamber fonned by shell 52. Bleed valves 78 and 84 are closed and main foam valve 75 is opened to inject foam into the upper portion of the chamber to equalized the pressure across gate valve 60.
  • gate valve 60 opened and the new lower end of the tubing joint is lowered to contact the open upper end of the tubing string 20 and the power swivel is rotated to connect the new tubing joint into the tubing string.
  • foam again flows down the tubing string 20 directly from the foam source.
  • foam injection through the alternate foam injection line 64 is stopped by closing valve 66.
  • Pressure is bled from the alternate foam conduit by opening valve 82.
  • the slips 50 are now released and the tubing string 20 is run another joint down into the well to continue circulating undesired debris therefrom.
  • the apparatus of the present invention is also effective in providing continuous circulation when the mode of operation requires reverse circulation.
  • Reverse circulation requires that foam be injected down the well annulus and up the tubing.
  • foam is injected in line 42 through valve 44 and down well annulus 24 to the lower end 22 of tubing string 20.
  • the foam then goes up tubing string 20 through pup joint 70 and is exhausted through conduit 74 which serves as the blooie line.
  • the foam source 18 and the valving therefore would be connected to line 42 and the blooie line 28 for normal circulation would be closed.
  • connection which is to be broken is positioned as shown in the lower portion of shell 52 and the tubing slips 50 are set to hang the tubing string 20 on the wellhead 32.
  • Valve 82 is opened and the connection 80 is then broken and the pup joint lifted above the gate valve 60.
  • gate valve 60 is closed, foam is exhausted from shell 52 via line 64.
  • a new tubing section is added to the pup joint and it is inserted back into the top of shell 52.
  • the gate valve is opened and the new tubing section is connected into the tubing string and operations are resumed.
  • circulation may be sequentially changed or refluxed from normal to reversed while the open tubing string is being held in the lower portion of the shell 52 by the tubing slips.
  • circulation may be refluxed.
  • Refluxing of the foam is useful for many purposes. It is particularly useful when cleaning a well liner with a cleaning fluid such as solvent, acid or the like. A slug of such a cleaning fluid is positioned in the well adjacent a liner and a column of foam is established in both the annulus and the tubing on both sides of the slug.
  • the tubing string 20 is hung in the shell 52 forming the closed chamber as shown in FIG. 2.
  • the cleaning slug is reciprocated up and down the well liner to provide a more thorough cleaning action. This operation is accomplished by injecting foam from the foam source 18 through valve 66 and line 64 into the shell 52 and then down the open tubing string 20 to the annulus 24'.
  • the foam in the annulus 24 above the cleaning slug is removed from the annulus through blooie line 28.
  • valve 30 on conduit 28 is closed as is valve 66 on the conduit from the foam source to the shell.
  • Valve 82 is opened to provide a vent to atmosphere through conduit 64.
  • Valve 44 on conduit 42 which is connected to the foam source is opened to cause foam to be injected down the well annulus 24 to reflux the cleaning slug while the foam which moves up the tubing string 20 is bled from shell 52 through conduit 64 and valve 82.
  • a method of providing continuous circulation of fluids in a segmented tubing string during makeup of such string comprising flowing fluid in or out of a well through a tubing string, forming a fluid-tight chamber about the upper end of said tubing string, providing a port in said chamber for flow of fluid in the same mode as the fluid flowing in said tubing string, opening said tubing string in said chamber, flowing fluid through said port and the open end of said tubing string to maintain circulation of fluid in said tubing string, adding another section of tubing to said tubing string and flowing fluid through said tubing string including the section added thereto.
  • a method of maintaining continuous circulation in a segmented tubing string and well annulus system comprising the steps of connecting a foam source to the upper end of a tubing string, injecting foam from said foam source down said tubing string and into a well, flowing foam up the well annulus between the tubing string and the well wall and exhausting the foam at the earths surface.
  • a method of maintaining continuous circulation in a segmented tubing string and well annulus system comprising the steps of injecting foam down a well annulus, flowing foam up a tubing string located in the well and exhausting the foam through a foam exhaust connected to such tubing string, forming a foam-tight chamber about the upper end of said tubing string, positioning said tubing string so that a connection between the foam exhaust and said tubing string is positioned in said chamber, hanging said tubing string below said connection in tension in the well, providing a port for exit of foam from said chamber, disconnecting said connection in said chamber to open the upper end of said tubing string in said chamber, raising the lower end of the foam exhaust to the upper portion of said chamber, closing off said chamber to flow between the lower end of said foam exhaust and the exit for foam from said chamber to cause foam from said tubing string to be exhausted from said chamber, through said port, removing the lower end of said foam exhaust from said chamber, connecting a new section of tubing to the lower end of said foam exhaust, inserting said newly connected section of tubing into said
  • a method of refluxing foam in a well annulus formed between a well wall and a tubing string located therein comprising establishing a foam source at the earths surface, forming a fluid-tight chamber about the upper end of a tubing string extending down a well providing a port in said chamber for flow of foam thereto, connecting said port with said foam source, connecting the well annulus with said foam source and alternately injecting foam down said tubing string and up said well annulus and injecting foam down said well annulus and up said tubing string 5.
  • Apparatus for use in a foam circulating system comprising a tubular shell of greater diameter than a tubing string to be used therewith, said tubular shell having an open upper end and an open lower end and a port for foam injection into the interior thereof or foam exhaust from the interior thereof, stripper rubber means in both the upper end and the lower end of said tubular shell, said stripper rubber means adapted to slidably engage tubing inserted through the ends of said tubular shell in a flow-tight manner to form with said shell a chamber about a tubing so inserted, valve means on said shell for closing off said shell to foam flow above said foam entry port and means for connecting said tubular shell in vertically spaced apart alignment with a wellhead.
  • Apparatus for use on a wellhead to provide continuous circulation in a tubing string extendin into a well and the annulus formed between the exterior of t e tubing strmg and the well casing comprising a tubing string, means for running said tubing string in a well, a foam source, conduit means for connecting said foam source to the upper end of said tubing string, a tubular shell arranged about the upper part of said tubing string and having a diameter greater than the diameter of said tubing string, said tubular shell having an open upper end and an open lower end, resilient stripper means fixedly connected in the ends of said tubular shell slidably engaged against the tubing string contained therein to cooperate with said tubing string to close off the ends of said tubular shell to form a closed annular chamber, means for flowing foam from said foam source into the lower portion of said annular chamber, valve means in said annular chamber above said foam entry means for closing off said annular chamber to longitudinal flow in the absence of a tubing section located adjacent thereto, a wellhead having tubing string

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  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Mechanical Engineering (AREA)
  • Cleaning Of Streets, Tracks, Or Beaches (AREA)
  • Extraction Or Liquid Replacement (AREA)
  • Pipe Accessories (AREA)
  • Earth Drilling (AREA)
US835268A 1969-06-20 1969-06-20 Method and apparatus for providing continuous foam circulation in wells Expired - Lifetime US3559739A (en)

Applications Claiming Priority (1)

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US83526869A 1969-06-20 1969-06-20

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US (1) US3559739A (da)
CA (1) CA935149A (da)
DE (1) DE2030169A1 (da)
DK (1) DK131739C (da)
FR (1) FR2046938B1 (da)
GB (1) GB1312841A (da)
NL (1) NL151772B (da)
NO (1) NO130736C (da)

Cited By (97)

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US3827487A (en) * 1973-04-30 1974-08-06 Baker Oil Tools Inc Tubing injector and stuffing box construction
US3840072A (en) * 1972-07-24 1974-10-08 Chevron Res Method and apparatus for use in well operations
US4468003A (en) * 1981-03-10 1984-08-28 Nonclerq Bernard Process for pulling cables into conduits
US4615564A (en) * 1985-02-11 1986-10-07 Hydrofoam Mining, Inc. Foam process for recovering underground rock fragments
WO1998016716A1 (en) * 1996-10-15 1998-04-23 Maris Internatinal Limited Continuous circulation drilling method
WO1999034090A1 (en) * 1997-12-24 1999-07-08 Well Engineering Partners B.V. Off-line mud circulation during lithosphere drilling
WO1999034091A1 (en) * 1997-12-24 1999-07-08 Well Engineering Partners B.V. Mud circulation for lithosphere drilling
WO2000023686A1 (en) 1998-10-19 2000-04-27 Well Engineering Partners B.V. Making up and breaking out of a tubing string in a well while maintaining continuous circulation
US6119772A (en) * 1997-07-14 2000-09-19 Pruet; Glen Continuous flow cylinder for maintaining drilling fluid circulation while connecting drill string joints
WO2000079092A2 (en) * 1999-06-22 2000-12-28 Shell Internationale Research Maatschappij B.V. Drilling system
US6216801B1 (en) 1998-04-03 2001-04-17 American Polywater Corporation Method and apparatus for providing proportional injection of additives into drilling fluids
US6217767B1 (en) 1992-02-03 2001-04-17 Clark Environmental Services Vacuum sparging process for treating contaminated groundwater and/or wastewater
WO2001066905A2 (en) * 2000-02-25 2001-09-13 Weatherford/Lamb, Inc Apparatus and method relating to tongs, continuous circulation and to safety slips
WO2001069034A2 (en) 2000-03-14 2001-09-20 Weatherford/Lamb, Inc. Wellbore circulation system, kelly bushing, kelly and tong
US20020189863A1 (en) * 1999-12-22 2002-12-19 Mike Wardley Drilling bit for drilling while running casing
EP1131533A4 (en) * 1998-09-25 2003-01-02 Gus Mullins & Associates Inc TUBULAR MATERIAL FILLING SYSTEM
US6527062B2 (en) 2000-09-22 2003-03-04 Vareo Shaffer, Inc. Well drilling method and system
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Also Published As

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NO130736B (da) 1974-10-21
FR2046938A1 (da) 1971-03-12
CA935149A (en) 1973-10-09
DK131739B (da) 1975-08-25
FR2046938B1 (da) 1974-02-01
DK131739C (da) 1976-01-26
NO130736C (da) 1975-01-29
NL151772B (nl) 1976-12-15
GB1312841A (en) 1973-04-11
DE2030169A1 (de) 1971-01-07
NL7009046A (da) 1970-12-22

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