WO1999053170A1 - Outils de fond revetus - Google Patents

Outils de fond revetus Download PDF

Info

Publication number
WO1999053170A1
WO1999053170A1 PCT/US1999/007852 US9907852W WO9953170A1 WO 1999053170 A1 WO1999053170 A1 WO 1999053170A1 US 9907852 W US9907852 W US 9907852W WO 9953170 A1 WO9953170 A1 WO 9953170A1
Authority
WO
WIPO (PCT)
Prior art keywords
downhole tool
coating
ethylene propylene
fluorinated ethylene
coated
Prior art date
Application number
PCT/US1999/007852
Other languages
English (en)
Inventor
Rashmi B. Bhavsar
Original Assignee
Camco International Inc., A Schlumberger Company
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
Application filed by Camco International Inc., A Schlumberger Company filed Critical Camco International Inc., A Schlumberger Company
Priority to GB0022726A priority Critical patent/GB2357529A/en
Priority to AU34876/99A priority patent/AU3487699A/en
Publication of WO1999053170A1 publication Critical patent/WO1999053170A1/fr

Links

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
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/02—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/101—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for equalizing fluid pressure above and below the valve
    • 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
    • E21B34/00—Valve arrangements for boreholes or wells
    • E21B34/06—Valve arrangements for boreholes or wells in wells
    • E21B34/10—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
    • E21B34/102—Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole with means for locking the closing element in open or closed position
    • 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
    • E21B43/121—Lifting well fluids
    • E21B43/122—Gas lift
    • E21B43/123—Gas lift valves
    • 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
    • E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
    • E21B2200/05—Flapper valves

Definitions

  • the present invention relates to subsurface or downhole tools used in onshore and offshore drilling and production. More specifically the present invention relates to downhole tools which are coated to reduce fouling on metallic parts by scale, solids deposition and other precipitates such as corrosion products, salts, clay, friable sands, paraffins, asphaltenes, and the like within a well bore.
  • a downhole tools such as safety valves, sliding sleeves, gas lift valves and subsurface locks
  • Subsurface safety valves are commonly used in wells to prevent uncontrolled fluid flow through the well in the event of an emergency, such as to prevent a well blowout.
  • Conventional safety valves use a flapper which is biased by a spring to a normally closed position, but is retained in an open position by the application of hydraulic fluid from the earth's surface. The hydraulic fluid actuates a piston which, in turn, forces a flow tube downwardly which actuates the flapper.
  • the piston when the hydraulic pressure applied to the piston exceeds the force needed to compress the spring, the piston is forced downwardly, causing the flow tube to contact and open the flapper, allowing the fluid to flow.
  • the hydraulic pressure applied when the hydraulic pressure applied is decreased, as by command from the earth's surface or by the control conduit being damaged, the spring forces the piston and the flow tube upward and away from the flapper. The flapper is then able to seat against an annular sealing surface and prevent fluid flow into the well conduit.
  • the metallic parts of the safety valve are carefully machined and designed to facilitate smooth operation. For example, sliding components such as the piston and flowtube which vertically slide along the outside diameter of the piston protector sleeve are optimized geometrically and have carefully designed clearances.
  • subsurface safety valves may optionally have a lock-out choke.
  • Lock-out chokes may be used to permanently lock a subsurface safety valve in the open position. The flowtube and lock-out choke slide vertically along each other. Scale and other deposits that may come out of solution or otherwise build up on the sliding metallic surfaces may result in sticking or galling that could prevent the operation of the lock-out choke.
  • sliding sleeve Another well-known downhole tool that can be selectively opened and closed, is a sliding sleeve.
  • Sliding sleeves allow communication between the well conduit and casing annulus.
  • Sliding sleeves may be connected in series with the tubing string to control fluid flow from the production zone to the earth's surface.
  • they may be used to control the flow of various fluids for stimulating or working a well from the earth's surface through the tubing string into the well annulus.
  • Sliding sleeves are generally controlled from the earth's surface by wireline tools, or by other mechanisms known to those of ordinary skill in the art. In order for the sliding sleeve to function properly it is very important that the sliding components have a clean surface free of scale or deposits.
  • Gas lift valves are downhole tools used to increase recovery of fluids from wells with decreased hydrostatic pressure.
  • the pressure of the producing formation is greater than the hydrostatic pressure of the fluid in the wellbore, allowing the well to flow without artificial lift.
  • a reduction in the formation pressure occurs. With this reduction in formation pressure, the hydrocarbon issuance therefrom is likewise reduced to a point where the well no longer flows without assistance, despite the presence of significant volumes of valuable product still in place in the oil bearing stratum.
  • artificial lift is commonly employed to enhance the recovery of oil from the formation.
  • subsurface locks Many times downhole tools, known as subsurface locks, are attached to subsurface control devices such as safety valves, blanking plugs and standing valves.
  • the subsurface lock anchors the valve or accessory in position in the tubing string.
  • the subsurface lock and accessory are landed in an appropriate nipple by standard wireline methods. It is important that the depth of the subsurface lock placement be accurate to enable the valve or accessory to preform properly. It is also important to be able to attach a pulling tool to the subsurface lock when anchored valves or accessories need maintenance or replacement. Therefore, it is important that the fishing neck, the expander tube, the lock housing and locking dogs remain clean and free of scale or deposits that could interfere with the subsurface lock being properly placed or retrieved.
  • Highly unconsolidated well formations may slough loose, friable sands into the well conduit.
  • Clays can be remineralized and deposit on surfaces. Bacterial growth can also occur, resulting in fouled surfaces.
  • Workover fluids or corrosive gas well conditions can produce high corrosion rates on metal surfaces, resulting in corrosion product deposition.
  • Operational problems such as ineffective or loss of viscosifying agents added to keep solids suspended in the produced fluids may result in solids deposition. Loss of annular velocity caused by the surface pump rate capability as well as torturous fluid paths or transient pressure drops within downhole tools may
  • the temperature and pressures found in the producing zone toward the bottom of the well are higher than those at the surface. Paraffins, waxes and asphaltenes may solidify when moving up the well conduit to the surface. Factors affecting the solidification or precipitation of these components as the oil moves toward the surface in the well conduit include their concentration in the produced oil, the temperature, the absolute pressure, and the rate of pressure drop through the well conduit which partially depends on the configuration and geometry of the fluid's flowpath. The point in the well conduit where the solidification or precipitation of these components generally occurs is broadly defined herein as the "deposition zone.” In addition, in-situ clays found in the fluid may remineralize and deposit on downhole equipment.
  • the art has sought a method for preventing, or reducing the rate of deposition of, scale, solids or other precipitates on downhole tool metallic surfaces and a downhole tool resistant to deposition of scale, solids, or other precipitates.
  • Vicosifiers, foams, and other solids washing programs have been used to combat scaling and solids deposition problems in the well conduit.
  • Specially formulated fluids which inhibit remineralization or hydration of in-situ clays have also been injected into the well.
  • Corrosion inhibitors and special metallurgies have also been used to combat deposit of corrosion products.
  • Pipe coatings have been used to control corrosion and to reduce friction losses.
  • Downhole tools have also been coated to improve lubricity, and friction reduction through antistick properties of the selected coatings.
  • the art continues to seek methods with the ability to prevent or reduce the rate of scaling and solids deposition, and downhole tools which are resistant to deposition of scale, solids, or other precipitates.
  • the present invention has been contemplated to prevent or reduce the rate of deposition of scale, solids or other precipitates on downhole tool metallic surfaces.
  • metallic surfaces, metallic parts or metallic portions in the specification and claims include, but is not limited to aluminum, steel, stainless steel, and nickel alloys.
  • the downhole tool of the present invention has a plurality of metallic parts, at least one of the metallic parts having a portion of the part coated by a fluorinated ethylene propylene coating in a sufficient amount to impart anti-deposition properties to the metallic portions coated.
  • the use of the term downhole tool in the specification and claims includes, but is not limited to, well completion tools, subsurface safety valves, gas lift valves, sliding sleeves, and subsurface locks.
  • a feature of the present invention includes use of a fluorinated ethylene propylene coating with the ability to prevent or retard scale and solids deposition.
  • the present invention may also include a resin primer, such as a perfluoroalkoxy copolymer resin primer containing a polyamide-imide binder to increase the ability of the anti-deposition coating to adhere to the metallic portions covered.
  • the fluorinated ethylene propylene coating may be applied over a perfluoroalkoxy copolymer resin primer to promote adhesion of the fluorinated ethylene propylene coating to the metallic part.
  • Another feature of the present invention is to thinly coat the metallic parts so that tool redesign is not required and so that coated replacement parts may be used with current designs.
  • This foregoing advantage is achieved by limiting the coating thickness to a range from about 0.8 to about 2.0 mils dry film thickness.
  • the fluorinated ethylene propylene coating is applied over a perfluoroalkoxy copolymer resin containing a polyamide-imide binder such that the total coating has a thickness ranging from
  • the downhole tool with a plurality of metallic parts may be coated first with fluorinated ethylene propylene over a portion of at least one of the metallic parts of the downhole tool, the first coating having a thickness ranging from about 0.7 to about 0.9 mils dry film thickness with a topcoat or second coat of fluorinated ethylene propylene over the first coating, the second coating having a thickness ranging from about 0.2 to about 0.5 mils dry film thickness.
  • the first coating may be of perfluoroalkoxy copolymer resin primer containing a polyamide-imide binder.
  • the metallic parts may be coated with polyphenylene sulfide (PPS) containing polytetrafluoroethylene (PTFE).
  • PPS polyphenylene sulfide
  • PTFE polytetrafluoroethylene
  • the thickness of the PPS and PTFE may be approximately 1.0 mil dry film thickness.
  • the present invention may be used with any downhole tool
  • another aspect of the present invention includes well completion tools, subsurface safety valves, gas lift valves, sliding sleeves, and subsurface locks.
  • Any metallic surface in the downhole tool may be coated as in the present invention.
  • a further feature of the present invention for downhole tools with metallic seals includes coating at least a portion of at least one surface of the metallic seal. The coating of the metallic seal surfaces in accordance with the present invention, increases both its lubricity and its anti-deposition performance.
  • a further advantage of the present invention is to selectively coat surfaces that are subject to scaling and/or deposition of solids or subject to performance degradation if fouled by the scaling and/or deposition of solids.
  • at least a portion of the flow tube, the lockout-choke and the piston protector sleeve of the subsurface safety valves may be coated, each piece alone or in combination with the others.
  • the valve body, the integral check valve in the nose of the valve body and the choke, if present, may be coated, each surface alone or in combination with the others.
  • the collet ribs and recesses may be coated, each surface alone or in combination with the others.
  • subsurface locks at least a portion of the fishing neck, the expander tube, the lock housing and locking dogs may be coated, each surface alone or in combination with the others.
  • the method of the present invention for controlling fluid production in a well conduit includes the steps of providing a downhole tool having a plurality of metallic parts; providing a fluorinated ethylene propylene coating over a portion of a least one of the metallic parts of the downhole tools wherein the coating is in a sufficient amount to impart anti-deposition properties to the metallic portions covered; and connecting the downhole tool to a tubing string forming a part of the well conduit.
  • Another feature of the present invention may include the step of using a well completion tool.
  • another feature of the present invention may include the step of locating the downhole tool in a deposition zone of the well conduit.
  • a further feature of the present invention may include the step of providing the fluorinated ethylene propylene coating over a perfluoroalkoxy copolymer resin primer containing a polyamide-imide binder.
  • the present invention may include the step of providing a coating of polyphenylene sulfide (PPS) containing polytetrafluoroethylene (PTFE).
  • Figure 1 is an elevational side view, partially in cross-section, showing a subsurface safety valve of the present invention
  • Figure 2 is an elevational side view, partially in cross-section, showing a lock-out choke, an option on a subsurface safety valve of the present invention
  • FIGS. 3A through 3C are partial cross-sectional elevation views which together show a sliding sleeve of the present invention in a run-in position;
  • Figures 4A and 4B are partial cross-sectional elevation views which together show a sliding sleeve of the present invention in an open position;
  • Figure 5 is an elevational side view, partially in cross-section, showing a gas lift valve of the present invention
  • Figure 6 is an elevational side view, partially in cross-section, showing a subsurface lock of the present invention in an unlocked position
  • Figure 7 is an elevational side view, partially in cross-section, showing a subsurface lock of the present invention in a locked position.
  • the present invention can be used in any commercially available downhole tool, whether it is tubing conveyed, wireline conveyed, hydraulically operated, or electrically operated.
  • the figures are not necessarily drawn to scale, and in some instances, have been exaggerated or simplified to clarify certain features of the invention.
  • the terms “upper” and “lower,” “up hole” and “downhole,” and “upwardly” and “downwardly” are relative terms to indicate position and direction of movement in easily recognized terms. Usually, these terms are relative to a line drawn from an upmost position at the surface to a point at the center of the earth, and would be appropriate for use in relatively straight, vertical wellbores.
  • a feature of the present invention includes use of a substantially pure fluorinated ethylene propylene coating, free of dispersion agents, with ability to prevent or retard scale and solids deposition.
  • the fluorinated ethylene propylene coating used may be, for example Xylan® 1756, available from Whitford Corporation headquartered in West Chester, Pennsylvania.
  • the present invention may also include a perfluoroalkoxy copolymer resin primer containing a polyamide- imide binder to increase the ability of the anti-deposition coating to adhere to the metallic portions covered. Examples of this primer, Xylan® 1220 or Xylan® 1700, are also available from Whitford Corporation.
  • the present invention may include use of a polyphenylene sulfide (PPS) coating containing polytetrafluoroethylene (PTFE), such as Xylan® 1331H, also available from Whitford Corporation.
  • PPS polyphenylene sulfide
  • PTFE polytetrafluoroethylene
  • the present invention may include a downhole tool for controlling fluid flow in a well conduit with a plurality of metallic parts and a fluorinated ethylene propylene coating over a portion of at least one of the metallic parts of the downhole tool formed by: applying a first coat of fluorinated ethylene propylene primer, the first coat having a thickness ranging from about 0.7 to about 0.9 mils dry film thickness; baking the primed tool at 400°F for five minutes; air cooling of the tool; applying a second coat of fluorinated ethylene propylene, the second coat having a thickness ranging from about 0.2 to about 0.5 mils dry film thickness; flashing the downhole tool at 200 °F for five minutes; baking the downhole tool at 750 °F for five minutes and air cooling the downhole tool.
  • a perfluoroalkoxy copolymer resin primer containing a polyamide-imide binder may be substituted for the first coat of fluorinated ethylene propylene primer.
  • embodiment comprises a generally tubular body 12 with a longitudinal bore 14 that extends
  • Each end of the body 12 includes mechanisms, such as threads 16, for interconnection with a pipe string (not shown) suspended within a wellbore (not shown).
  • a sleeve member 18, usually referred to as a flow tube, is disposed within the bore 14 and is adapted for axial movement therein.
  • the flow tube 18 has an outer surface 19 which is subject
  • the flow tube 18 includes a spring 20 disposed
  • the flapper mechanism 24 generally comprises a disc or
  • flapper valve closure member 26 with an arm 28 on a peripheral edge thereof that is hingedly
  • annular housing 30 mounted within the bore 14.
  • the annular housing 30 includes a metallic annular sealing surface 32 cooperable with an annular
  • annular housing 30 may further include a secondary annular sealing surface 38 formed from an annular body of pliable
  • sealing surface 32 is generally referred to as the "hard seat” and the pliable sealing surface 38 is generally referred to as the "soft seat.”
  • a rod-piston system may be provided to open the flapper 26, and may be comprised of a piston 40 sealably mounted for reciprocal movement within a cylinder 42 located within the wall of the tubular body 12.
  • the piston 40 is in contact with hydraulic fluid (not shown) provided thereto from the earth's
  • a second end 43 of the piston 40 is operatively connected, in any suitable manner, to the flow tube 18.
  • the piston 40 is guided by a piston protector sleeve 59 as it moves axially.
  • the outer surface 57 of the piston protector sleeve 59 is a surface subject to fouling by scaling or solids deposition.
  • a fluorinated ethylene propylene coating on the outer surface 19 of the flow tube 18 or the outer surface 57 of the piston protection sleeve 59 may eliminate or retard fouling with scale or deposited solids that could prevent the flapper 26 from actuating properly and
  • a lock-out choke 55 may be added to a subsurface safety valve to preform this function.
  • a choke sleeve member 56 is disposed within
  • a wire line shifting tool (not shown) is engaged with a profile 61 on the inner surface of the choke sleeve member 56 and used to mechanically apply downward forces to the choke sleeve member 56.
  • coating on the outer surface 68 of the choke sleeve member 56 and on the inner surface 70 of the flow tube 18 may prevent scaling and solids deposition that could interfere with the operation of
  • the sliding sleeve 110 of the present invention includes a housing 118 having a longitudinal bore 120 extending therethrough.
  • a piston 124 is associated
  • the piston 124 is a specific embodiment, the piston 124
  • the piston 124 is provided with an upper surface 124a, a lower surface 124b, an inner annular piston seal 124c, an outer upper annular piston seal 124d, and an outer lower
  • annular piston seal 124e The inner annular piston seal 124c is disposed between the inner sleeve
  • the outer annular piston seals 124d and 124e are disposed between the piston 124 and the housing 118.
  • At least one annulus pressure port 126 is provided through the
  • the housing 118 for example, by at least one shear pin 125; the upper surface 124a of the piston
  • the piston is displaced above an annular shoulder 129 within the longitudinal bore 120 of the
  • the housing 118; and the outer annular seals 124d and 124e are located above the at least one annulus pressure port 126.
  • the housing may also be provided with an annular housing seal 133 beneath the at least one shear pin 125 and above the annular shoulder 129.
  • the housing 118 is provided with at least one outer fluid flow
  • upper annular flow port seal 134 is disposed above the at least one outer fluid flow port 130 and
  • a coating of fluorinated ethylene propylene on a least a portion of the outer surface 131 of the inner sleeve 122 may prevent or retard scaling and solids deposition that could interfere with the operation of the sliding sleeve 110.
  • annular flow port seal 134 and the lower annular flow port seal 136, where the inner sleeve 122
  • the outer surface 131 is subject to scale and solids deposition could beneficially prevent or retard scaling and/or solids deposition.
  • the flow port seals 134 and 136 may be chevron packing, as well known to those of skill in the art.
  • the at least one outer fluid flow port 130 and the at least one inner fluid flow port 132 sealably cooperate to control fluid flow between the annulus (not shown) and a longitudinal bore
  • Figure 3B illustrates the fluid flow ports 130 and 132 in a closed or non-aligned relationship. In this position, fluid flow from the annulus (not shown) is prevented from flowing into the longitudinal bore 123 of the inner sleeve 122. Further, the upper and lower annular seals 134 and 136 prevent fluid from migrating upwardly or downwardly in
  • the inner sleeve 122 may
  • the lower end of the inner sleeve 122 is provided with a collet
  • the bore 120 may be provided with an upper annular recess 142 ( Figure 3B), an
  • bore 120 may also be provided with an equalizing recess 143 between the upper recess 142 and the intermediate recess 144.
  • the collet rib 140 is located in the intermediate recess 144 when
  • a fluorinated ethylene propylene coating on at least a portion, or preferably the entire surface, of the collet rib 140 and mating annular recesses 142-144, 146, may prevent scaling and solids deposition that could interfere with the operation of the sliding sleeve 110.
  • annulus pressure is applied to the piston 124 through the at least one annulus pressure port 126.
  • the annulus pressure is contained by the inner piston seal 124c, the outer
  • the force applied to the lower piston surface 124b by the annulus pressure should be sufficient to (a) release the piston from the housing, for example, by shearing the at least one shear pin 125, and (b)
  • sleeve 110 brings the flow ports 130 and 132 into alignment and establishes fluid communication between the annulus (not shown) and the longitudinal bore 123 of the inner sleeve 122. Fluids from the production zone (not shown) may then be produced to the earth's surface through the tubular conduit (not shown).
  • the collet rib 140 is located in the upper recess 142 when the sliding sleeve 110 is in its open position.
  • the collet rib 140 may be moved into, and held in, the equalizing
  • the inner sleeve 122 may then be moved upwardly until flow ports 130 and 132 are aligned, as more fully explained above.
  • shifting tool (not shown) is used to apply a downward impact force to the inner sleeve 122, in a
  • Fluid communication through the ports 130 and 132 will be fully terminated when the at least one flow port 132 in the inner sleeve 122 is moved below the lower flow port seal 136.
  • the sliding sleeve 110 will be fully closed, and
  • the gas lift valve 208 of this specific embodiment comprises a generally
  • tubular body 210 with a longitudinal bore 212 for sealable insertion in a side pocket mandrel (not
  • a fluorinated ethylene propylene coating on at least a portion, or preferably the entire surface of the integral check valve 224 may be useful in preventing or retarding scaling or solids deposition.
  • the gas lift valve body 210 may house a choke 228 to control the maximum
  • the optional choke 228 may be housed in the nose 226
  • the gas lift valve 208 as shown in Figure 5, or alternatively, it may be located within the port 214.
  • Control of the quantities of injection gas (not shown) is required to balance the need to lighten the fluid column and allow the natural reservoir pressure to push the fluid up the well conduit and the operational costs associated with use of excessive quantities of injection gas.
  • Careful sizing of the port 214 diameter in combination with use of a choke 228 or variable orifice facilitates this balance. Therefore, it is important to keep the gas flow path clean and free from scale or deposits in the areas designed to restrict and control the gas quantities.
  • the gas lift valve body 210 may optionally include a fishing neck
  • Running tool 320 is shown, having a shearable shear pin 342 or other retaining means 342 connecting the running tool to the housing 344 of the well lock 340.
  • a shearable shear pin 342 initially permits the well lock 340 to be lowered into the well bore 334 by lowering the running tool 320 attached thereto.
  • the well lock 340 is lowered into the
  • no-go shoulder 325 and nipple landing shoulder 335 provided in connection with the well locking device 310 and tubing 330, respectively, comprise bearing means, which prevent downhole
  • no-go shoulder 325 and nipple landing shoulder 335 can be placed in various locations in connection with the well locking device 310 and the tubing 330 and other bearing means could be used.
  • a particular embodiment of the well locking device 310 of the present invention could incorporate a selective lock (not shown) having matching
  • retractable no-go shoulders (not shown) on the well lock housing 344, which may be provided in a particular embodiment to eliminate undesirable stresses on the well lock housing 344.
  • an upward force may be
  • Shear pin 302 may be used to temporarily connect the running tool 320 to the well lock housing 344.
  • other retaining means may be provided, such as retractable fingers (not shown) provided in connection with the running tool 320, to engage an inner groove such as recess 346 formed within expander tube 343 of the well lock 340. In such an embodiment, when the running tool 320 is removed from the
  • the retractable fingers (not shown) may be retracted, thus disengaging the ruiining
  • a downward pressure force may be applied to the setting portion 326, or setting tool 326, of running tool 320, which may be resisted by abutment of the no-go shoulder 325 and nipple landing shoulder 335, provided on the running tool 320 and the tubing 330, respectively.
  • the device 310 is initially located within the tubing 330 in a running mode, in which the locking dogs 345 of the well lock 340 are permitted to remain within the well lock 340 for lowering of the well lock 340 within the tubing 330.
  • the well lock 340 is maintained in the running mode by use of
  • shear ring 350 is disposed in a recess 347 formed or otherwise provided in a lower portion of expander tube 343 and at least
  • shear ring 350 is disposed within a corresponding upper recess 341 formed or otherwise provided in an upper portion of well lock housing 344.
  • a continued downward force applied to expander tube 343 by setting portion 326, or setting tool 326, of running tool 320 may be applied to lower expander tube 343 to a second, locking, position, whereby outwardly biased shear ring 350, as described
  • shear ring 350 remains disposed within the recess 347 formed or otherwise provided in expander tube 343 and at least a portion of shear
  • ring 350 is disposed within a corresponding lower recess 342 formed or otherwise provided in a lower portion of well lock housing 344 of well lock 340, thereby fully engaging locking dogs
  • bore 334 of tubing 330, the running tool 320 and its associated setting portion 326, or setting tool 326, may be detached from the well lock 340 and removed from the bore 334 of tubing 330,
  • running tool 320 and well lock housing 344 are connected to one another by shear pin
  • the ranning tool 320 may be detached from the well lock 340 by providing an upward force on the running tool 320 sufficient to shear the shear pin 302 and thereby separate running tool 320 from well lock 340.
  • the upward force is resisted by the locking dogs 345 engaged within
  • running tool 320 may be easily removed from the downhole portion of the tubing 330, leaving the well lock 340 locked in place within tubing 330.
  • a running removal tool or pulling tool (not shown), may be provided having fingers adapted to remove the well lock 340 from within the bore 334 of tubing 330.
  • the running removal tool (not shown) may be lowered into the downhole portion of the well tubing bore 330 until it
  • the well lock 340 is operable in its third, or pulling, mode.
  • a continued upward force applied to the running removal tool causes the expander tube 343 to abut a flange 315 formed as part of the fishing neck 365, located or other portion provided on the well lock housing 344 so that continued upward movement of the expander tube
  • a coating of fluorinated ethylene propylene is applied on a portion, or preferably the entire outer surface 367, of the fishing neck 365, expander tube 343, well lock housing 344 and locking dogs 345.
  • any downhole tool that needs to be resistant to deposit of scale, solids or other precipitates may be coated, for example a landing nipple.
  • the coating of the present invention is so thin that metallic replacement parts may be coated and inserted into current downhole tool designs as desired to retard or prevent scale and solids deposition. Accordingly, the invention is therefore to be limited only by the scope of the appended claims.

Landscapes

  • Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Physics & Mathematics (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Earth Drilling (AREA)

Abstract

L'invention concerne des outils de fond revêtus (10, 110, 208, 310) qui permettent de réguler le débit des fluides à l'intérieur d'un tube de puits. Le revêtement, à base d'éthylène-propylène fluoré, empêche ou retarde le dépôt de tartre, de matières solides ou d'autres précipités sur les surfaces métalliques de l'outil de fond revêtu (19, 32, 68, 70, 131, 215, 230, 232, 235, 367).
PCT/US1999/007852 1998-04-09 1999-04-09 Outils de fond revetus WO1999053170A1 (fr)

Priority Applications (2)

Application Number Priority Date Filing Date Title
GB0022726A GB2357529A (en) 1998-04-09 1999-04-09 Coated downhole tools
AU34876/99A AU3487699A (en) 1998-04-09 1999-04-09 Coated downhole tools

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US8117098P 1998-04-09 1998-04-09
US60/081,170 1998-04-09

Publications (1)

Publication Number Publication Date
WO1999053170A1 true WO1999053170A1 (fr) 1999-10-21

Family

ID=22162528

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/US1999/007852 WO1999053170A1 (fr) 1998-04-09 1999-04-09 Outils de fond revetus

Country Status (2)

Country Link
AU (1) AU3487699A (fr)
WO (1) WO1999053170A1 (fr)

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2005093209A1 (fr) * 2004-03-22 2005-10-06 Shell Internationale Research Maatschappij B.V. Procede d'injection de gaz de poussee dans un tubage de production d'un puits de petrole et dispositif de commande d'ecoulement par ejection conçu pour ce procede
WO2006058271A2 (fr) * 2004-11-24 2006-06-01 E.I. Dupont De Nemours And Company Outils revetus utilises dans des tuyaux de puits de petrole
US8061429B2 (en) 2008-12-30 2011-11-22 Schlumberger Technology Corporation Systems and methods for downhole completions
US8383199B2 (en) 2003-12-17 2013-02-26 E. I. Dupont De Nemours And Company Process for lining the interior surface of a metal pipe for conveying oil
US8651188B2 (en) 2009-12-30 2014-02-18 Schlumberger Technology Corporation Gas lift barrier valve
WO2014055077A1 (fr) * 2012-10-04 2014-04-10 Halliburton Energy Services, Inc. Outil de puits à manchons coulissants comportant un joint d'étanchéité métal sur métal
WO2015084386A1 (fr) * 2013-12-06 2015-06-11 Halliburton Energy Services, Inc. Dépôt en phase vapeur d'un oxyde métallique sur des surfaces de puits ou de pipelines afin de réduire la paraffine brute
WO2020264326A1 (fr) * 2019-06-28 2020-12-30 Schlumberger Technology Corporation Revêtements hiérarchiques de dépôt antitartre pour applications de puits de forage
WO2022040252A1 (fr) * 2020-08-18 2022-02-24 Schlumberger Technology Corporation Clapet antiretour résistant au tartre

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4349050A (en) * 1980-09-23 1982-09-14 Carbide Blast Joints, Inc. Blast joint for subterranean wells
US4671833A (en) * 1984-09-24 1987-06-09 Freeport Minerals Company Process for applying a heat-shrinkable material over sulfur well piping
US4905760A (en) * 1987-10-26 1990-03-06 Ico, Inc. Sucker rod coupling with protective coating
US5105879A (en) * 1991-03-20 1992-04-21 Baker Hughes Incorporated Method and apparatus for sealing at a sliding interface

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4349050A (en) * 1980-09-23 1982-09-14 Carbide Blast Joints, Inc. Blast joint for subterranean wells
US4671833A (en) * 1984-09-24 1987-06-09 Freeport Minerals Company Process for applying a heat-shrinkable material over sulfur well piping
US4905760A (en) * 1987-10-26 1990-03-06 Ico, Inc. Sucker rod coupling with protective coating
US5105879A (en) * 1991-03-20 1992-04-21 Baker Hughes Incorporated Method and apparatus for sealing at a sliding interface

Cited By (21)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US8383199B2 (en) 2003-12-17 2013-02-26 E. I. Dupont De Nemours And Company Process for lining the interior surface of a metal pipe for conveying oil
US8776837B2 (en) 2003-12-17 2014-07-15 E I Du Pont De Nemours And Company Coated pipes for conveying oil
US7464763B2 (en) 2004-03-22 2008-12-16 Shell Oil Company Method of injecting lift gas and gas lift flow control device
WO2005093209A1 (fr) * 2004-03-22 2005-10-06 Shell Internationale Research Maatschappij B.V. Procede d'injection de gaz de poussee dans un tubage de production d'un puits de petrole et dispositif de commande d'ecoulement par ejection conçu pour ce procede
AU2005225752B2 (en) * 2004-03-22 2007-11-15 Shell Internationale Research Maatschappij B.V. Method of injecting lift gas into a production tubing of an oil well and gas lift flow control device for use in the method
NO342660B1 (no) * 2004-11-24 2018-06-25 Du Pont Belagte verktøy for bruk i oljebrønnledninger
US7347258B2 (en) 2004-11-24 2008-03-25 E.I. Du Pont De Nemours And Company Coated tools for use in oil well pipes
WO2006058271A3 (fr) * 2004-11-24 2006-10-05 Du Pont Outils revetus utilises dans des tuyaux de puits de petrole
WO2006058271A2 (fr) * 2004-11-24 2006-06-01 E.I. Dupont De Nemours And Company Outils revetus utilises dans des tuyaux de puits de petrole
US8061429B2 (en) 2008-12-30 2011-11-22 Schlumberger Technology Corporation Systems and methods for downhole completions
US8651188B2 (en) 2009-12-30 2014-02-18 Schlumberger Technology Corporation Gas lift barrier valve
GB2521951B (en) * 2012-10-04 2019-07-24 Halliburton Energy Services Inc Sliding sleeve well tool with metal-to-metal seal
GB2521951A (en) * 2012-10-04 2015-07-08 Halliburton Energy Services Inc Sliding sleeve well tool with metal-to-metal seal
WO2014055077A1 (fr) * 2012-10-04 2014-04-10 Halliburton Energy Services, Inc. Outil de puits à manchons coulissants comportant un joint d'étanchéité métal sur métal
US11193353B2 (en) 2012-10-04 2021-12-07 Halliburton Energy Services, Inc. Sliding sleeve well tool with metal-to-metal seal
GB2538368A (en) * 2013-12-06 2016-11-16 Halliburton Energy Services Inc Vapor-depositing metal oxide on surfaces for wells or pipelines to reduce scale
WO2015084386A1 (fr) * 2013-12-06 2015-06-11 Halliburton Energy Services, Inc. Dépôt en phase vapeur d'un oxyde métallique sur des surfaces de puits ou de pipelines afin de réduire la paraffine brute
WO2020264326A1 (fr) * 2019-06-28 2020-12-30 Schlumberger Technology Corporation Revêtements hiérarchiques de dépôt antitartre pour applications de puits de forage
US11643730B2 (en) 2019-06-28 2023-05-09 Schlumberger Technology Corporation Anti-scale deposition hierarchical coatings for wellbore applications
WO2022040252A1 (fr) * 2020-08-18 2022-02-24 Schlumberger Technology Corporation Clapet antiretour résistant au tartre
GB2611999A (en) * 2020-08-18 2023-04-19 Schlumberger Technology Bv Scale resistant backcheck valve

Also Published As

Publication number Publication date
AU3487699A (en) 1999-11-01

Similar Documents

Publication Publication Date Title
US7523787B2 (en) Reverse out valve for well treatment operations
US5090481A (en) Fluid flow control apparatus, shifting tool and method for oil and gas wells
US6216785B1 (en) System for installation of well stimulating apparatus downhole utilizing a service tool string
CA2043756C (fr) Bouchon de tige de forage
US7963334B2 (en) Method and apparatus for continuously injecting fluid in a wellbore while maintaining safety valve operation
US6505685B1 (en) Methods and apparatus for creating a downhole buoyant casing chamber
US4293034A (en) Well safety system method and apparatus
CA1246988A (fr) Methode et dispositif de garnissage d'un forage au gravier-filtre
US9303477B2 (en) Methods and apparatus for cementing wells
US6367551B1 (en) Monobore riser
US4057108A (en) Completing wells in deep reservoirs containing fluids that are hot and corrosive
WO2006028691A1 (fr) Alliage a memoire de forme pouvant empecher l'erosion d'outils de forage
EP2636840B1 (fr) Ensemble de fond de trou pour système d'injection capillaire
US20130062056A1 (en) Multiple annulus universal monitoring and pressure relief assembly for subsea well completion systems and method of using same
US9909389B2 (en) Dual torsion springs flapper valve closure mechanism
US20060076140A1 (en) Gas Lift Apparatus and Method for Producing a Well
EP0288239A2 (fr) Outil de mise à feu pour canon perforateur
WO1999053170A1 (fr) Outils de fond revetus
US10465478B2 (en) Toe valve
US11091982B2 (en) Equalizing device
US11352846B2 (en) Advanced pulling prong
Soepriyadi Operating Experience of Gas Lift Macaroni Safety Valves
Christman et al. Drillstem-Test Assemblies for Floating Vessels
CA2119386A1 (fr) Bouchon provisoire servant a sceller un tube d'une colonne de tubes

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AL AM AT AU AZ BA BB BG BR BY CA CH CN CU CZ DE DK EE ES FI GB GD GE GH GM HR HU ID IL IN IS JP KE KG KP KR KZ LC LK LR LS LT LU LV MD MG MK MN MW MX NO NZ PL PT RO RU SD SE SG SI SK SL TJ TM TR TT UA UG UZ VN YU ZW

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): GH GM KE LS MW SD SL SZ UG ZW AM AZ BY KG KZ MD RU TJ TM AT BE CH CY DE DK ES FI FR GB GR IE IT LU MC NL PT SE BF BJ CF CG CI CM GA GN GW ML MR NE SN TD TG

121 Ep: the epo has been informed by wipo that ep was designated in this application
DFPE Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed before 20040101)
ENP Entry into the national phase

Ref country code: GB

Ref document number: 200022726

Kind code of ref document: A

Format of ref document f/p: F

NENP Non-entry into the national phase

Ref country code: KR

REG Reference to national code

Ref country code: DE

Ref legal event code: 8642

122 Ep: pct application non-entry in european phase