WO2004027201A2 - Annular isolators for expandable tubulars in wellbores - Google Patents
Annular isolators for expandable tubulars in wellbores Download PDFInfo
- Publication number
- WO2004027201A2 WO2004027201A2 PCT/US2003/029566 US0329566W WO2004027201A2 WO 2004027201 A2 WO2004027201 A2 WO 2004027201A2 US 0329566 W US0329566 W US 0329566W WO 2004027201 A2 WO2004027201 A2 WO 2004027201A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- tubing
- sleeve
- borehole
- annular
- expansion
- Prior art date
Links
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
- E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
- E21B43/106—Couplings or joints therefor
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/124—Units with longitudinally-spaced plugs for isolating the intermediate space
- E21B33/1243—Units with longitudinally-spaced plugs for isolating the intermediate space with inflatable sleeves
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/12—Packers; Plugs
- E21B33/127—Packers; Plugs with inflatable sleeve
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
- E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP 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
- E21B43/02—Subsoil filtering
- E21B43/10—Setting of casings, screens, liners or the like in wells
- E21B43/103—Setting of casings, screens, liners or the like in wells of expandable casings, screens, liners, or the like
- E21B43/108—Expandable screens or perforated liners
Definitions
- This invention relates to isolating the annulus between tubular members in a borehole and the borehole wall, and more particularly to methods and apparatus for forming annular isolators in place in the annulus between a tubular member and a borehole wall.
- oil and gas wells pass through a number of zones other than the particular oil and/or gas zones of interest. Some of these zones may be water producing. It is desirable to prevent water from such zones from being produced with produced oil or gas. Where multiple oil and/or gas zones are penetrated by the same borehole, it is desirable to isolate the zones to allow separate control of production from each zone for most efficient production. External packers have been used to provide annular seals or barriers between production tubing and well casing to isolate various zones.
- Open hole completions are particularly useful in slant hole wells.
- the wellbore may be deviated and run horizontally for thousands of feet through a producing zone. It is often desirable to provide annular isolators along the length of the horizontal production tubing to allow selective production from, or isolation of, various portions of the producing zone.
- various steps are usually taken to prevent collapse of the borehole wall or flow of sand from the formation into the production tubing.
- Use of gravel packing and sand screens are common ways of protecting against collapse and sand flow. More modern techniques include the use of expandable solid or perforated tubing and/or expandable sand screens.
- tubular elements may be run into uncased boreholes and expanded after they are in position. Expansion may be by use of an inflatable bladder or by pulling or pushing an expansion cone through the tubular members. It is desirable for expanded tubing and screens to minimize the annulus between the tubular elements and the borehole wall or to actually contact the borehole wall to provide mechanical support and restrict or prevent annular flow of fluids outside the production tubing. However, in many cases, due to irregularities in the borehole wall or simply unconsolidated formations, expanded tubing and screens will not prevent annular flow in the borehole. For this reason, annular isolators as discussed above are typically needed to stop annular flow.
- annular seal or isolator in variable sized boreholes, adjustable or variable expansion tools have been used with some success. However it is difficult to achieve significant stress in the rubber with such variable tools and this type of expansion produces an inner surface of the tubing which follows the shape of the borehole and is not of substantially constant diameter. [0011] It would be desirable to provide equipment and methods for installing annular isolators in open boreholes, particularly horizontal boreholes, which may be carried on tubular elements as installed in a borehole and provide a good seal between production tubing and the wall of open boreholes.
- the present invention provides apparatus which may be carried on or in tubing as it is run into a wellbore and deployed to form an annular isolator between the tubing and borehole.
- the tubing is expandable tubing and the annular isolator is activated or deployed as a result of or in conjunction with expansion of the tubing.
- an annular isolator forming material is in a compartment carried with the tubing as it is installed in a borehole and is driven from the compartment to form an annular isolator in conjunction with tubing expansion.
- the annular isolator forming material may be placed into the annulus between the tubing and borehole wall where it acts as an annular isolator due to its inherent viscosity or as a result of a chemical reaction which converts the material into a viscous, semisolid or solid material in place in the annulus.
- the material may include several chemical components which react with each other, or may be a single or multiple chemical components, which also react with ambient fluids to form an annular isolator.
- the present invention includes an inflatable member carried on the outside of a tubing section. Any of the above described annular isolator forming materials may be flowed into the inflatable member inflate it and form an annular isolator.
- the inflatable member includes multiple sections, which inflate at progressively increasing pressure levels. A section which inflates at the lowest pressure level is designed to expand to fill the largest expected annulus, while the other sections inflate only after the low pressure section contacts a borehole wall.
- the inflatable member may be inflated with material carried with the tubing in a compartment and driven from the compartment into the inflatable member as a result of tubing expansion. It may also be inflated with material pumped down the tubing itself or through a work string positioned in the tubing.
- the annular isolator forming material is an elastomeric sleeve, band or ring carried on expandable tubing as it is installed in a borehole and deployed to act as an annular isolator in conjunction with expansion of the tubing.
- one, or preferably multiple, rings have radial and axial dimensions and shapes selected to form a fluid tight seal with a maximum borehole size after tubing expansion, and to form a seal after tubing expansion in a minimum sized borehole without exceeding maximum allowable stress.
- a sleeve has a reduced radial dimension as installed on tubing for running into a borehole where its radial dimension is increased prior to or in conjunction with tubing expansion.
- the sleeve is stretched axially as installed on the tubing and held in place by a slidable ring during tubing installation. Upon tubing expansion the ring is released and the sleeve is allowed to return to its original radial dimension.
- the slidable ring is driven by an expansion cone to axially compress an elastomeric sleeve and increase its radial dimension. Both mechanisms may be applied to the same elastomeric sleeve.
- the sleeve is designed to fold upon itself or into a circumferentially corrugated shape upon axial compression, to increase its radial dimension.
- Pairs of such elastomeric sleeves, bands or rings may be used to isolate a section of annulus into which annular isolator forming material carried with the tubing or conveyed down hole through tubing or a work string may be placed as discussed above.
- annular isolator forming material carried with the tubing or conveyed down hole through tubing or a work string may be placed as discussed above.
- Inflatable bladders may be used for primary expansion, or for overexpanding tubing sections which carry annular isolator forming materials including elastomeric sleeves, rings or bands.
- Adjustable or variable diameter expansion cone tools may be used to overexpand tubing sections which carry annular isolator forming materials including elastomeric sleeves, rings or bands. Internal pressure applied through the tubing or a work string may be used to overexpand selected tubing sections. Axial compression of the selected tubing sections may be used to aid over expansion of such selected tubing sections.
- Figure 1 is a cross-sectional view of a borehole in the earth with an open hole completion and a number of annular isolators according to the present invention.
- Figure 2 is a cross-sectional illustration of expandable tubing in an open hole completion carrying elastomeric rings or bands on the outer surface of the tubing.
- Figure 3 is a cross-sectional illustration of an elastomeric sleeve on the outer surface of expandable tubing, which has been prestretched to reduce its thickness during installation of the tubing in the borehole.
- Figure 4 is a cross-sectional illustration of the embodiment of Figure 3 after the prestretched sleeve has been released by an expansion cone.
- Figure 5 is an illustration of use of an adjustable expansion cone to expand expandable tubing and an elastomeric sleeve into an enlarged portion of an open borehole to form an annular isolator.
- Figures 6 and 7 are cross-sectional illustrations of an embodiment including elastomeric sleeves on the outer surface of an expandable tubing which are folded before tubing expansion to form an annular isolator in an enlarged portion of a borehole.
- Figures 8 and 9 are cross-sectional illustrations of latching mechanisms for holding the elastomeric sleeve of Figures 6 and 7 in place during installation of tubing in a borehole.
- Figure 10 is a cross-sectional illustration of expandable tubing carrying reactive chemicals in a matrix on its outer surface for installation in a borehole.
- Figure 11 is a cross-sectional illustration of expandable tubing carrying reactive chemicals in a reduced diameter portion for installation in a borehole.
- Figure 12 is a cross-sectional illustration of expandable tubing carrying a fluid within a reduced diameter portion and covered by an expandable sleeve having a pressure relief valve.
- Figure 13 is a cross-sectional illustration of expandable tubing having a reduced diameter corrugated section carrying a fluid and covered by an expandable sleeve having a pressure release valve.
- Figure 14 is a cross-sectional view of the Figure 13 embodiment which illustrates corrugated expandable tubing and the location of annular isolator forming material.
- Figure 15 is a partial cross-sectional illustration of another embodiment of the present invention having an annular isolator forming fluid carried within a recess in expandable tubing and arranged to inflate an elastomeric sleeve upon tubing expansion.
- Figure 16 illustrates the condition of the Figure 14 embodiment after the expandable tubing has been expanded.
- Figures 17, 18, and 19 are cross-sectional illustrations of an expandable tubing assembly having an elastomeric sleeve which can be expanded as part of the tubing expansion process.
- Figure 20 is a cross sectional illustration of an alternative form of the embodiment of
- Figures 21, 22, and 23 are cross-sectional illustrations of an elastomeric sleeve with an embedded spring that may be carried on an expandable tubing and released to form an annular isolator as a result of expansion of the tubing.
- Figures 24 and 25 are illustrations of expandable tubing having an inflatable bladder and a two part chemical system driven by a spring-loaded piston for inflating the bladder as part of expansion of the tubing.
- Figure 26 is a partially cross-sectional view of an expandable tubular element carrying a compressed foam sleeve held in position by a grid which may be released upon expansion of the tubing.
- Figure 27 is a cross-sectional illustration of expandable tubing carrying a sleeve which may be expanded by a chemical reaction driving a piston which is initiated by expansion of the tubing.
- Figures 28 and 29 are illustrations of expandable tubing carrying folded plates which may be expanded to form a basket upon expansion of the tubing.
- Figure 30 is a cross-sectional illustration of expandable tubing having an interior chamber carrying an annular isolator forming material which may be forced into an external inflatable sleeve upon passage of an expansion cone through the expandable tubing.
- Figure 31 is a cross-sectional illustration of expandable tubing carrying an inflatable rubber bladder on a recessed portion and an expansion string to fill the rubber bladder with fluid pumped from the surface prior to running of an expansion cone through the reduced diameter portion of the tubing.
- Figure 32 is a cross-sectional illustration of expandable tubing carrying an elastomeric sleeve and an expansion tool used to expand the tubing into contact with the borehole using pressure fluid pumped from the surface.
- Figures 33 and 34 are cross-sectional illustrations of system using an axial load and interior pressure to cause expansion of expandable tubing and an external sleeve into contact with a borehole wall to form an annular isolator.
- Figure 35 is a cross-sectional illustration of expanded tubing and an injection tool for placing an annular isolator forming material in the annulus between the expanded tubing and the borehole wall.
- Figure 36 is a cross sectional illustration of an alternate system for preexpanding an externally carried elastomeric sleeve of the type shown in Figures 6 to 9.
- Figure 37 is a cross sectional illustration of yet another system for preexpanding an externally carried elastomeric sleeve of the type shown in Figures 6 to 9.
- Figures 38, 39, 40 and 41 illustrate the deployment of an external sleeve having multiple sections which inflate at different internal pressure levels to form an annular isolator.
- Figure 42 is a cross sectional illustration of an embodiment having a conduit in the annulus passing through an inflatable isolator.
- Figure 43 is a more detailed illustration of a portion of Figure 42.
- Figure 44 is an illustration of a pair of conduits located in an annulus and bypassing an inflatable isolator element.
- Figure 45 is an illustration of a circumferentially corrugated elastomeric sleeve which may be used to form an annular isolator.
- annular isolator means a material or mechanism or a combination of materials and mechanisms which blocks or prevents flow of fluids from one side of the isolator to the other in the annulus between a tubular member in a well and a borehole wall or casing.
- An annular isolator acts as a pressure bearing seal between two portions of the annulus.
- annular isolators must block flow in an annular space, they may have a ring like or tubular shape having an inner diameter in fluid tight contact with the outer surface of a tubular member and having an outer diameter in fluid tight contact with the inner wall of a borehole or casing.
- An annular isolator could be formed by tubing itself if it could be expanded into intimate contact with a borehole wall to eliminate the annulus.
- An isolator may extend for a substantial length along a borehole.
- a conduit may be provided in the annulus passing through or bypassing an annular isolator to allow controlled flow of certain materials, e.g. hydraulic fluid, up or down hole.
- perforated means that the member has holes or openings through it.
- the holes can have any shape, e.g. round, rectangular, slotted, etc. The term is not intended to limit the manner in which the holes are made, i.e. it does not require that they be made by perforating, or the arrangement of the holes.
- Figure 1 With reference now to Figure 1 , there is provided an example of a producing oil well in which an annular isolator according to the present invention is useful. In Figure 1, a borehole 10 has been drilled from the surface of the earth 12.
- An upper portion of the borehole 10 has been lined with casing 14 which has been sealed to the borehole 10 by cement 16.
- an open hole portion 18 which extends downward and then laterally through various earth formations.
- the borehole 18 may pass through a water bearing zone 20, a shale layer 21, an oil bearing zone 22, a nonproductive zone 23 and into another oil bearing zone 24.
- the open hole 18 has been slanted so that it runs through the zones 20-24 at various angles and may run essentially horizontally through oil-bearing zone 24.
- Slant hole or horizontal drilling technology allows such wells to be drilled for thousands of feet away horizontally from the surface location of a well and allows a well to be guided to stay within a single zone if desired. Wells following an oil bearing zone will seldom be exactly horizontal, since oil bearing zones are normally not horizontal.
- Tubing 26 has been placed to run from the lower end of casing 14 down through the open hole portion of the well 18. At its upper end, the tubing 26 is sealed to the casing 14 by an annular isolator 28. Another annular isolator 29 seals the annulus between tubing 26 and the wall of borehole 18 within the shale zone 21. It can be seen that isolators 28 and 29 prevent annular flow of fluid from the water zone 20 and thereby prevent production of water from zone 20. Within oil zone 22, tubing 26 has a perforated section 30. Section 30 may be a perforated liner and may typically carry sand screens or filters about its outer circumference. A pair of annular isolators 31 prevents annular flow to, from or through the nonproductive zone 23.
- the isolators 31 may be a single isolator extending completely through the zone 23 if desired.
- the combination of isolator 29 and isolators 31 allow production from oil zone 22 into the perforated tubing section 30 to be selectively controlled and prevents the produced fluids from flowing through the annulus to other parts of the borehole 18.
- tubing 26 is illusfrated as having two perforated sections 32 and 33. Sections 32 and 33 may be perforated and may typically carry sand screens or filters about their outer circumference.
- Annular isolators 36 and 38 are provided to seal the annulus between the tubing 26 and the wall of open borehole 18.
- the isolators 31, 36 and 38 allow separate control of flow of oil into the perforated sections 32 and 33 and prevent annular flow of produced fluids to other portions of borehole 18.
- the horizontal section of open hole 18 may continue for thousands of feet through the oil bearing zone 24.
- the tubing 26 may likewise extend for thousands of feet within zone 24 and may include numerous perforated sections which may be divided by numerous annular isolators, such as isolators 36 and 38, to divide the zone 24 into multiple areas for controlled production.
- tubing 26 It is becoming more common for the tubing 26 to comprise expandable tubular sections. Both the solid sections of the tubing 26 and the perforated sections 32 and 33 are now often expandable.
- expandable tubing provides numerous advantages. The tubing is of reduced diameter during installation which facilitates installation in offset, slanted or horizontal boreholes. Upon expansion, solid, or perforated tubing and screens provide support for uncased borehole walls while screening and filtering out sand and other produced solid materials which can damage tubing. After expansion, the internal diameter of the tubing is increased improving the flow of fluids through the tubing.
- annular flow cannot be prevented merely by use of expandable tubing 26, including expandable perforated sections and screens 32 and 33.
- annular barriers or isolators 36 and 38 are needed. Typical annular isolators such as inflatable packers have not been found compatible with the type of production installation illustrated in Figure 1 for various reasons including the fact that the structural members required to mount and operate such packers are not expandable along with the tubing string 26.
- annular isolators such as elements 36 and 38 shown in Figure 1
- an expandable tubing 42 positioned within an open borehole 40.
- the tubing is shown in its unexpanded state and carries on it outer surface a ring or band of elastomeric material 44, for example rubber.
- the ring 44 has fairly short axial dimensions, i.e. its length along the axial length of the tubing 42, but has a relatively long radial dimension, i.e. the distance it extends from the tubing in the radial direction towards the borehole wall 40.
- the rings are preferably tapered radially as illustrated to have a longer axial dimension where bonded to the outer surface of the tubing and shorter axial dimension on the end which first contacts the borehole wall.
- the tubing 42 carries ring 44 and a similar ring 46 which together may form a single annular isolator such as isolator 36 in Figure 1.
- the rings 44 and 46 may be installed on the tubing 42 by being cast in a mold positioned around the tubing 42.
- the tubing may also be covered by a continuous sleeve of elastomer between rings 44 and 46 which may be formed in the same casting and curing process.
- FIG. 2 Also shown in Figure 2 is an expansion cone 48 which has been driven into the expandable tubing 42 from the left side as indicated by arrow 50. As the cone passes through the tubing from left to right, the tubing is expanded to a larger diameter as indicated at 52. As the expansion cone passed through the ring 46, the ring 46 was forced into contact with the wall 40. Expansion of the tubing 52 reduced the radial dimension and increased the axial dimension of the ring 46, since the total volume must remain constant.
- each annular isolator 36, 38 of Figure 1 may comprise two or more such rubber rings 44 and 46 carried on expandable tubing as illustrated in
- conduit 45 extending along the outer surface of tubing
- the lines may be copper or other conductive wires for conducting electrical power down hole or for sending control signals down hole and signals from pressure, temperature, etc. sensors up hole. Fiber optic lines may also be used for signal transmissions up or down hole.
- the lines may be hydraulic lines for providing hydraulic power to down hole valves, motors, etc. Hydraulic lines may also be used to provide control signals to down hole equipment.
- the conduit 45 may be any other type of line, e.g. a chemical injection line, used in a down hole environment. It is usually preferred to route these lines on the outside of the tubing rather than in the production flow path up the center of the tubing.
- the lines can be routed through the rubber rings 44 and 46 as illustrated while maintaining isolation of the annulus with the rings 44, 46.
- FIG. 2 embodiment solves several problems of prior art devices.
- Such devices have included relatively thin rubber sleeves on the outside of expandable screens, which sleeves extend for substantial distances axially along the tubing.
- such sleeves typically do not make contact with the borehole and thus do not form an effective annular isolator.
- prior art sleeves may contact the borehole wall before the expandable tubing is fully expanded creating excessive forces in the expansion process. Due to their axial length, the forces required to extrude or flow such sleeves axially in the annulus cannot be generated by an expansion tool and, if they could, would damage the borehole or the tubing.
- the elastomeric rings 44 and 46 have radial and axial dimensions selected to achieve several requirements.
- One requirement is for the rings to contact a borehole wall with sufficient stress to conform to the borehole wall and act as an effective annular isolator.
- the radial dimension or height of the ring therefore is selected to be greater than the width of the annulus between expanded tubing and the wall of the largest expected borehole. The ring will therefore be compressed radially and will expand axially in the annulus as a result of tubing expansion.
- Another requirement is to avoid damage which may result from excessive stress in the rings 44, 46.
- Excessive stresses may be encountered when tubing is expanded in a borehole having a nominal or less than nominal diameter. Such excessive stress may damage the borehole wall, i.e. the formation, by overstressing and crushing the borehole wall. In some cases, some compression of the borehole wall is acceptable or even desirable.
- Excessive stress can also cause collapse or compression of the tubing after an expansion tool has passed through the rings. That is, the stress in the elastomeric rings may be sufficient to reduce the tubing diameter after an expansion tool has passed through the tubing or been removed.
- Excessive stress may damage or stop movement of an expansion tool itself. That is, the stress may require forces greater than those available from a given expansion tool.
- the elastomeric rings When expanding tubing in minimum diameter boreholes, the elastomeric rings must be capable of axial expansion at internal stresses which are below levels which would cause damage to the borehole wall, tubing or expansion tool.
- the radial dimension of the rings is selected as discussed above. Based on any given radial dimension and the characteristics of the selected elastomer, the axial dimension of the ring is selected to allow expansion of the tubing in the smallest expected borehole without generating excessive pressures. The smaller the axial dimension, the less force is required to compress the elastomeric ring radially from its original radial dimension to the thickness of the annulus between the expanded tubing and the smallest expected borehole.
- the tapered shape of the rings 44, 46 is one way in which the requirements can be achieved. As is apparent from the above discussion, the amount of force required to radially compress the rings 44, 46 is related to the axial length of the rings. With a tapered shape as shown in Figure 2 (or the tapers shown in Figures 10 and 11), the ring does not have a single axial dimension, but instead has a range of axial dimensions. The shortest axial dimension is on the outer circumference which will first contact a borehole wall. The force required to cause radial compression and axial expansion is therefore smallest at the outer circumference. That is, the deformation of the ring during tubing expansion effectively begins with the portion which first contacts the borehole wall.
- annular isolator according to the Figure 2 embodiment include two or more of the illustrated rings 44, 46. It is also preferred that the axial dimensions of the rings be selected to allow annular expansion or extrusion of the elastomer as the ring is compressed radially. This assumes, of course, that there is available annular space into which the elastomer may expand without restriction. If adjacent rings are spaced too closely, they could contact each other as they expand axially in the annulus. Upon making such contact, the forces required for further radial compression may increase substantially. It is therefore preferred that adjacent rings
- FIG. 3 With reference the Figures 3 and 4, another embodiment of an external annular isolator is illustrated.
- Figure 3 is shown a portion of an unexpanded expandable tubular member 54.
- a pre-stretched elastomeric sleeve 56 Carried on the outside of expandable member 54 is a pre-stretched elastomeric sleeve 56.
- sleeve 56 has been stretched axially to increase its axial dimension and reduce its radial dimension from the dimensions it has when free of such external forces.
- One end of sleeve 56 is attached to a ring
- a sliding ring 60 which is captured in a recess 62 in the tubing 54.
- the elastomeric sleeve 56 is illustrated in its relaxed or unsfretched condition free of the stretching force.
- the expansion cone 64 has been forced into the expandable member 54 from the left side and has moved past the locking recess 62. As it did so, the tubing 54 including recess 62 was expanded to final expanded diameter. When this happened, the sliding member 60 was released and the elastomeric sleeve 56 was allowed to return to its unsfretched dimensions.
- expandable tubing it is desirable for expandable tubing to reduce the annulus between the tubing string and the borehole wall as much as possible.
- the tubing may be expanded only a limited amount without rupturing. It is therefore desirable for the tubing to have the largest possible diameter in its unexpanded condition as it is run into the borehole. That is, the larger the tubing is before expansion, the larger it can be after expansion.
- Elements carried on the outer surface of tubing as it is run in to a borehole increase the outer diameter of the string.
- the total outer diameter must be sized to allow the string to be run into the borehole.
- the total diameter is the sum of the diameter of the actual tubing plus the thickness or radial dimension of any external elements. Thus external elements effectively reduce the allowable diameter of the actual expandable tubing elements.
- sleeve 56 The relaxed shape of sleeve 56 is selected so that for the largest expected diameter of borehole, the sleeve will contact the borehole wall upon tubing expansion and be compressed radially with sufficient internal stress to form a good seal with the borehole wall. Upon radial compression, the sleeve 56 will expand or extrude to some extent axially along the annulus since the volume of the elastomer remains constant.
- the annular isolator of Figures 3 and 4 is positioned in a competent borehole which is at the nominal drilled size or is even undersized due to swelling of the borehole wall on contact with drilling fluid.
- the relaxed thickness of sleeve 56 may be sufficient to contact the borehole wall 57 before expansion of tubing 54.
- the sliding ring 60 can be adapted so that, after expansion, it can slide on the expanded tubing 54 at a preselected force level.
- the ring 58 can be attached to the tubing 54 with a crimp or similar bond which releases and allows limited movement at axial force above a preselected level. In either case, the maximum force exerted by the expansion of tubing 54 under the sleeve 56 can be limited while maintaining a significant stress on the sleeve 56 to achieve a seal with a borehole wall.
- ring 58 is used as a pressure relief device, it is desirable to provide a locking mechanism to prevent further sliding after the expanding tool 64 has passed through the ring 58.
- the locking device can be one or more slip type teeth 59 on the ring 58 which will bite into the tubing 54 when it expands under the ring 58.
- Other mechanisms may be used to allow limited pressure relief while retaining sufficient stress in the compressed sleeve 56 to maintain a good seal to a borehole.
- FIG. 5 there is illustrated a partially expanded expandable tubing section 66.
- Section 66 carries fixed elastomeric sleeves 68 and 70 on its outer circumference.
- the borehole wall 72 is shown with an enlarged portion 74 at the location of elastomeric sleeve 70.
- an adjustable or variable diameter expanding cone 76 is employed to expand the tubing 66.
- the diameter of the cone 76 has been increased to overexpand tubing 66 causing sleeve 70 to make a firm contact with borehole wall in region 74.
- sleeve 68 will make contact with normal expansion of tubing 66.
- variable expansion cone 76 may be used in conjunction with a fixed expansion cone such as cone 48 of Figure 2 or cone 64 of Figure 4. Both cones can be carried on one expansion tool string, or the adjustable cone can be carried down hole with the tubing as it is installed and picked up by the expansion tool when it reaches the end of the tubing string. After expansion of the tubing, screens, etc., by a fixed cone, the adjustable cone 76 may be used to further expand the sections with external sleeves 70 to ensure making a seal with the borehole. This can be done on a single trip into the borehole. For example, the fixed cone can expand the entire tubing string as the tool is run down the borehole and the adjustable cone can be deployed at desired locations as the tool is run back up hole.
- Figures 6, 7, 8 and 9 illustrate another embodiment having an external elastomeric sleeve which has a variable radial dimension which is increased before tubing is expanded.
- an elastomeric sleeve 80 is illustrated in its position as installed for running tubing into a borehole.
- the sleeve 80 is connected at one end to a fixed ring 82 on the tubing 78.
- the ring 82 holds the sleeve 80 in place.
- a sliding ring 84 is connected to the other end of sleeve 80.
- Elastomeric sleeve 80 is notched or grooved at 86 to generate hinge or flexing sections.
- a second sleeve 88 is illustrated in two stages of deployment on the left sides of Figures 6 and 7.
- Sleeve 88 was essentially identical to sleeve 80 when tubing 78 was run into a borehole.
- an expansion tool 90 has moved into the left side of tubing 78 and expanded a portion of tubing 78 up to a sliding ring 92 connected to the left end of sleeve 88.
- the ring is pushed to the right and folds the sleeve 88 into the accordion shape as illustrated.
- the sleeve 88 has an increased radial dimension, i.e.
- the sleeves 80, 88 may fold into shapes other than that shown in Figures 6 and 7. In alternative embodiments, the sleeves 80 and 88 may be unnotched or otherwise configured for folding and may simply be compressed by the sliding rings 84, 92 into a shape like that shown in Figure 4.
- the expansion tool 90 has passed completely under the sleeve 88 and expanded the tubing 78 and expanded sleeve 88 so that the sleeve 88 has contacted a borehole wall at 94.
- the sliding ring 92 moved to the right until the sleeve 88 was completely folded and stopped further movement of ring 92. At that point the tool 90 passed under the ring
- FIG. 8 and 9 means for holding sliding rings, such as rings 84 and 92 in Figures 6 and 7, in place during installation of the tubing are illustrated.
- an elastomeric sleeve 96 and fixed ring 98 may be the same as parts 80 and 82 shown in Figures 6 and 7.
- expandable tubing 100 is provided with a recess 102 for holding a sliding ring in place.
- a sliding ring 104 has a matching recess 106 near its center which extends into recess 102 to lock the sliding ring in place.
- a sliding ring 108 has an edge 110 shaped to fit within recess 102.
- the recesses 102 will be removed or flattened as an expansion cone is forced through expandable tubing 100. When this occurs, the sliding rings 104 and 108 will no longer be locked into place and will be free to slide along the expandable tubing 100 as it is expanded. After tubing expansion, the elastomeric sleeve
- Figures 8 and 9 may take the form of sleeve 88 shown in Figure 7.
- expandable tubing 112 is essentially the same as expandable tubing shown in the previous Figures.
- two elastomeric rings 114 and 116 which may be essentially the same as rings 44 and 46 shown in Figure 2, are carried on an outer surface of the tubing 112.
- Tubing 112 may have a fluid tight wall between the rings 114 and 116 and may be perforated on the ends of the portion which is illustrated.
- a cylindrical coating or sleeve 118 of various chemical materials carried on the outer wall of tubing 112.
- the layer 118 includes solid particles of magnesium oxide and monopotassium phosphate 120 encapsulated in an essentially inert binder 122, for example dried clay.
- the chemicals magnesium oxide and monopotassium phosphate will react in the presence of water and liquefy. The liquid will then go to a gel phase and eventually crystallize into a solid ceramic material magnesium potassium phosphate hexahydrate.
- This material is generally known as an acid-base cement and is sometimes referred to as a chemically bonded ceramic. It normally hardens in about twenty minutes and binds well to a variety of substrates. Other acid-base cement systems may be used if desired. Some require up to twenty-two waters of hydration and may be useful where larger void spaces need to be filled.
- any other material or packaging arrangement which separates the individual chemical particles during installation of tubing 112 in a well bore and prevents liquids in the borehole from contacting chemical materials may be used.
- the individual chemical components may be encapsulated in microcapsules, tubes, bags, etc. which separate and protect them during installation of tubing in a bore hole.
- the elastomeric rings 114 and 116 are used primarily to hold the chemical reactants 120 in position until the chemical reaction has been completed. As the reaction occurs, the volume of chemical materials expands by the reaction with and incorporation of water and the final annular isolator is formed by the reacted chemicals.
- the elastomeric rings 114 and 116 are optional, but are preferred to ensure proper placement of the chemicals as they react. It is desirable that the rings 114 and 116 be designed to allow release of material in the event the chemical reaction results in excessive pressure which might damage the tubing 112. In many cases it may be desirable for one or both of the rings 114, 116 to be sized to not form a total seal with the borehole.
- the rings 114 and 116 will diminish outflow of more viscous materials such as the gel at lower pressures, while allowing some flow of more fluid materials or of the gel at excessive pressures.
- the chemicals may be encapsulated in a heat sensitive material and released by running a heater into the tubing 112 to the desired location.
- conduit 115 passing through the rings 114, 116 and the chemical coating 118.
- This conduit 115 is provided for power, control, communication signals, etc. like conduit 45 discussed above with reference to Figure 2.
- the conduit 115 is also illustrated in Figure 10 for power, control, communication signals, etc. like conduit 45 discussed above with reference to Figure 2.
- the conduit 115 is also illustrated in Figure 10.
- Figure 11 illustrates another embodiment using various chemical materials for forming an annular isolator.
- An expandable tubing section 124 preferably carries a pair of elastomeric rings
- tubing 124 Between the locations of rings 126 and 128, the tubing 124 has an annular recessed area 130. Within the recess 130 is carried a swellable polymer 132 such as cross-linked polyacrylamide in a dry condition. A rupturable sleeve 134 is carried on the outer wall of tubing
- the sleeve 134 protects the swellable polymer 132 from fluids during installation of the tubing 124 into a borehole.
- the material 132 may be in the form of powder or fine or small particles which are held in place by the sleeve 134.
- the material 132 may also be made in solid blocks or sheets which may fracture on expansion. It may also be formed into porous or spongy sheets. If solid or spongy sheet form is used, the sleeve 134 may not be needed or may simply be a coating or film adhered to the outer surface of the material 132.
- the protective sheath 134 is designed to split or shatter instead of expanding thus exposing the polymer 132 to fluids in the wellbore.
- annular isolator thus formed remains flexible and will conform to uneven borehole shapes and sizes and will continue to conform if the shape or size of the borehole changes.
- the swellable polymer may be formed into sheets or solid shapes which may be carried on the tubing 124.
- the 10 embodiment could be carried within the recess 130 and protected by the sheath 134 during installation of the tubing 124.
- the elastomeric rings 126 and 128 are optional, but preferred to hold materials in place while reactions occur and are preferably designed to limit the amount of pressure that can be generated by the swelling materials.
- FIG. 12 there is illustrated another embodiment of the present invention in which a fluid may be used to inflate a sleeve.
- expandable tubing 136 is formed with a reduced diameter portion 138 providing a recess in which a flowable annular isolator forming material 140 may be stored.
- An outer inflatable metal sheath or sleeve 142 forms a fluid tight chamber or compartment with the reduced diameter section 138.
- This sheath 142 as installed has an outer diameter greater than the expandable member 136 to increase the amount of material 140 which may be carried down hole with the tubing 136.
- the outer sheath 142 is bonded by welding or otherwise to the tubing 136 at up hole end 144. At its down hole end 146, the sheath
- a retainer sleeve 150 has one end welded to the tubing 136 and an opposite end extending over end 146 of the outer sleeve 142.
- the retainer sleeve 150 preferably includes at least one vent hole 152 near its center.
- a portion 143 of outer sleeve 142 is predisposed to expand at a lower pressure than the remaining portion of sleeve 142.
- the portion 143 may be made of a different material or may be treated to expand at lower pressure.
- the portion 143 may be corrugated and annealed before assembly into the form shown in Figure 11.
- Portion 143 is preferably adjacent the end 146 of sleeve 142 which would be expanded last by an expansion tool.
- the metallic outer sleeve 142 may be covered by an elastomeric sleeve or layer 154 on its outer surface.
- An elastomeric sleeve 154 is preferred on portion 143 if it is corrugated to help form a seal with a borehole wall in case the corrugations are not completely removed during the expansion process.
- the elastomeric sleeve 154 would also be preferred on any portion of the sleeve 142 which is perforated.
- the inflatable sleeve 142 and other inflatable sleeves discussed below are referred to as "metal" sleeves or sheaths primarily to distinguish from elastomeric materials. They may be formed of many metallic like substances such as ductile iron, stainless steel or other alloys, or a composite including a polymer matrix composite or metal matrix composite. They may be perforated or heat-treated, e.g. annealed, to reduce the force needed for inflation. [0078] In operation, the embodiment of Figure 12 is ran into a wellbore in the condition as illustrated in Figure 12. Once properly positioned, an expander cone is forced through the tubing 136 from left to right as illustrated in Figure 2.
- the pressure of material 140 is increased.
- the outer sleeve 142 is inflated outwardly towards a borehole wall. Inflation begins with the portion 143 which inflates at a first pressure level.
- the pressure of material 140 increases until a second pressure level is reached at which the rest of outer sleeve 142 begins to inflate. If proper dimensions have been selected, the inflatable outer sleeve 142 and elastomeric layer 154 will be pressed into conforming contact with the borehole wall. To ensure that such contact is made, it is desirable to have an excess of material 140 available.
- the material 140 may be any of the reactive or swellable materials disclosed herein so that the extra material vented at 152 may react, e.g. with ambient fluids, to form an additional annular isolator between the tubing 136 and the borehole wall.
- the outer sleeve 142 is shown to have an expanded initial diameter to allow more material 140 to be carried into the borehole. As discussed above, this arrangement results in a smaller maximum unexpanded diameter of tubing 136. It would be possible to form a fluid compartment or reservoir with only the outer sleeve 142, that is without the reduced diameter tubing section 138. However, to achieve the same volume of stored fluid, the sleeve 142 would have to extend farther from tubing 136 and the maximum unexpanded diameter of tubing 136 would be further reduced.
- Figure 13 illustrates an alternative embodiment which allows a greater unexpanded diameter of an expandable tubing 156.
- an outer sleeve 158 has a cylindrical shape and has essentially the same outer diameter as the tubing 156. Otherwise, the outer sleeve
- this embodiment includes a pressure relief arrangement 157 which may be identical to the one used in the Figure 12 embodiment.
- the sleeve 158 preferably has a portion 159 predisposed to expand at a lower pressure than the remaining portion of sleeve 158, like the portion 143 of outer sleeve
- Sleeve 158 may carry an outer elastomeric sleeve like sleeve 154 in Figure 12.
- a reduced diameter portion 160 of tubing 156 is corrugated as illustrated in Figure 14. It is preferred that the portion 160 be formed from tubing having a larger unexpanded diameter than the unexpanded diameter of tubing 156. During corrugation of the portion 160, the tubing wall may be stretched to have a larger total circumference after corrugation and then annealed to relieve stress. Each of these arrangements helps reduce total stresses in the section 160 which result from unfolding the corrugations and expanding to final diameter. As can be seen from Figure 14, the crimping or corrugation of the section 160 of tubing
- the pressure relief arrangements shown in Figures 12 and 13, and in many of the following embodiments, are preferred in expandable tubing systems which use a fixed diameter cone for expansion. It is often desirable that the inner diameter of an expandable tubing string be the same throughout its entire length after expansion. Use of a fixed diameter expansion tool provides such a constant internal diameter.
- the pressure relief mechanism provides several advantages in such systems. It is desirable that a large enough quantity of expansion material be carried down hole with the expandable tubing to ensure formation of a good annular isolator in an oversized, e.g. washed out, and irregularly shaped portion of the borehole. If the borehole is of nominal size or undersized, there will then be more fluid than is needed to form the annular isolator.
- FIGs 15 and 16 illustrate another embodiment of the present invention in which a material carried with expandable tubing as installed in a borehole is used to inflate an annular isolator.
- an expandable tubular member 164 includes a reduced diameter section 166 providing a compartment for storage of an isolator forming material, preferably a fluid 168.
- the fluid 168 is held in place by an elastomeric sleeve 170 which completely covers the fluid 168 and extends a substantial additional distance along the outer surface of the expandable tubing 164.
- a first section of perforated metallic shroud 172 is connected at a first end 174 to the expandable tubing 164.
- the shroud 172 extends around the elastomeric sleeve 170 for a distance at least equal to the length of the reduced diameter section 166 of the tubing 164.
- shroud 176 has one end 178 connected to the tubular member 164.
- Shroud 176 covers and holds in place one end of the elastomeric sleeve 170. Between shroud section 172 and 176, a portion of the elastomeric sleeve 170 is exposed. The shroud section 176 and a portion 180, adjacent the exposed portion of sleeve 170, of shroud 172 are highly perforated and therefore designed to expand relatively easily. The remaining portion 182 of shroud 172 has only minimal slotting (or in some embodiments no slotting) and requires greater pressure to expand. If desired, both shroud sections
- 172 and 176 may be covered by a second elastomeric sleeve to improve sealing between a borehole wall and the shrouds after they are expanded.
- Figure 16 illustrates the condition of this embodiment after an expander cone has been driven through the expandable tubing 164 from left to right in Figures 15 and 16.
- the fluid 168 is first forced to flow under the exposed portion of the elastomeric sleeve 170. As illustrated in Figure 16, it will expand until it contacts and conforms to a borehole wall 184.
- the reduced diameter section 166 of the tubing 164 be considerably longer than the exposed portion of the rabber sleeve 170. By a proper selection of the ratio of these lengths, sufficient material 168 is available to provide a very large expansion of the rubber sleeve 170.
- portion 182 therefore provides a pressure relief or limiting function. It is also desirable to include a relief mechanism as shown in Figures 12 and 13 to provide an additional pressure limiting mechanism, in case the borehole is of nominal size or undersized.
- FIG. 17 With reference now to Figures 17, 18, and 19, there is shown an annular isolator system which provides pre-compression of an external elastomeric sleeve before expansion of the tubing on which the sleeve is carried.
- expandable tubing 190 is shown having been partially expanded by an expansion tool 192 carried on a pilot expansion mandrel 194.
- the expanded portion 196 may carry an external screen expanded into contact with a borehole wall
- the threaded portion 202 is connected to a reduced diameter section 206 of the expandable tubing into which a portion 208 of the expansion mandrel 194 has been pushed to form an interference fit.
- the mandrel portion 208 is preferably splined on its outer surface to form a tight grip with reduced diameter section 206.
- a rotating bearing 210 is provided between the elastomeric sleeve 204 and the lower tubing section 202.
- the expansion cone 192 may be forced through the tubing string 190 past the tubing sections 200 and
- FIG. 20 an alternative form of the embodiment of Figures 17, 18 and 19 is illustrated.
- the same expansion tool including expansion cone 192, mandrel 194 and splined end 208 may be used.
- Two expandable tubing sections 209 and 210 are connected by an internal sleeve 211.
- the sleeve 211 has external threads on each end which mate with internal threads on sections 209 and 210.
- the sleeve has an external flange 212 and an internal flange 213 near its center.
- An elastomeric sleeve 214 is carried on sleeve 211 between the external flange 212 and the tubing section 209.
- the internal flange 213 is sized to mate with the splined end 208 of mandrel 194.
- This Figure 20 system operates in essentially the same way as the system shown in Figures 17, 18 and 19.
- the expansion cone 192 is passing through and expanding the tubing section 209, the splined end 208 engages the internal flange 213.
- Expansion cone downward movement is stopped and mandrel 194 is rotated to turn the sleeve 211 relative to both tubing sections 209 and 210.
- FIG. 21 With reference now to Figures 21, 22 and 23, there is illustrated an embodiment of the present invention in which a coil spring is used to expand an external elastomeric sleeve to form an annular isolator.
- an elastomeric sleeve 220 is illusfrated in its relaxed or natural shape as it would be originally manufactured, sleeve 220 is made up of two parts. It includes a barrel shaped elastomeric sleeve 222. That is, the sleeve 222 has a diameter at each end corresponding to the outer diameter of an unexpanded tubular member and a larger diameter in its center.
- a coil spring 224 Embedded within the elastomeric sleeve 222 is a coil spring 224 having generally the same shape in its relaxed condition.
- the sleeve 220 is shown as installed on a section of unexpanded expandable tubing 226 for ranning into a borehole.
- the member 220 has been stretched lengthwise causing it to conform to the outer diameter of the tubing 226.
- the sleeve 220 may be held onto the tubing 226 by a fixed ring 228 on its down hole end and a sliding ring 230 on its up hole end.
- the rings 228 and 230 may be essentially the same as the rings 58 and 60 illustrated in Figure 3.
- Sliding ring 230 would be releasably latched into a recess formed on the outer surface of expandable tubing 226 to keep the sleeve 220 in its reduced diameter shape for running into the tubing in the same manner as shown in Figure 3.
- Figure 23 illustrates the shape and orientation of the elastomeric sleeve 220 after the tubing 226 has been placed in an open borehole 232 and an expansion cone has been driven through the tubing 226 from left to right.
- the expansion cone expands the tubing 226 including a recess holding sliding ring 230 which releases the sliding ring 230 and allows the sleeve 220 to return to its natural shape shown in Figure 21.
- the sleeve 220 contacts the borehole wall 232 forming an annular isolator.
- FIG. 24 and 25 there is illustrated a system including an external elastomeric bladder which is inflated by fluid in conjunction with expansion of expandable tubing section 240.
- An expandable bladder 242 is carried on the outside of the expandable tubing 240.
- a fluid 246 and in the other end is a compressed spring 248. Between the fluid 246 and spring 248 is a sliding seal 250.
- a spring retainer 252 within the chamber 244 holds the spring 248 in a compressed state by means of a release weld 254.
- a port 256 between the chamber 244 and the bladder 242 is initially sealed by a rupture disk 258.
- an expansion cone 260 is shown moving from right to left expanding the tubing 240.
- the release weld 254 breaks free from spring retainer 252 releasing the spring 248 to drive the sliding piston 250 to the left which injects the fluid 246 through the rupture disk 258 into the bladder 242.
- the bladder 242 is thus expanded before the expansion cone 260 reaches that part of the expandable tubing 240 which carries the bladder 242.
- the expansion cone continues from right to left and expands the tubing 240, it further drives the inflated bladder 242 in firm contact with borehole wall 262.
- the bladder 242 is partly filled with a chemical compound
- the spring 248 can be replaced with other stored energy devices, such as a pneumatic spring.
- This embodiment can also be operated without a stored energy device.
- the spring 248, retainer 252 and the piston 250 may be removed.
- the entire volume of chamber 244 may then be filled with fluid 246.
- the expansion cone 260 moves from right to left, it will collapse the chamber 244 and squeeze the fluid 246 through port 256 into the bladder 242.
- the bladder would be filled before the cone 20 moves under it and expands it further as tubing 240 is expanded.
- the bladder 242 is installed in a nominal or undersized portion of a borehole, it is possible that excessive pressure may be experienced as the expansion cone passes under the bladder.
- the outer wall of chamber 244 may be designed to expand at a pressure low enough to prevent damage to the bladder 242 or the expansion tool 260.
- a pressure relief valve may also be included in the chamber 244 to vent excess fluid if the chamber 244 itself expands into contact with a borehole wall.
- an expandable tubing section 266 on which is carried a compressed open cell foam sleeve 268 which may be expanded to form an annular isolation device.
- the foam 268 is a low or zero permeability open cell foam product which restricts flow in the annular direction. It is elastically compressible to at least 50% of it initial thickness and reversibly expandable to its original thickness.
- the foam sleeve 268 is placed over the tubing and compressed axially and held in place by a cage 270 formed of a series of longitudinal members 272 connected by a series of circular rings 274.
- the cage 270 or at least the rings 274, are formed of a brittle or low tensile strength material which cannot withstand the normal expansion of tubing 266 which occurs when an expansion cone passes through the tubing. Therefore, as the tubing is expanded, for example as illustrated in Figure 2, the cage 270 fails and releases the foam 268 to expand to its original thickness or radial dimension. As this is occurring, the tubing 266 itself is expanded pressing the foam 268 against the borehole wall to form an annular isolator.
- the foam 268 may be made with reactive or swellable compounds carried in dry state within the open cells of the foam.
- reactive or swellable compounds carried in dry state within the open cells of the foam.
- Figure 11 may be used to protect the chemicals from fluid contact during installation. After expansion of the tubing 266, the chemicals would be exposed to formation fluids and react to form a cement or swellable mass to obtain structural rigidity and impermeability of the expanded foam.
- the plastic film can be prestretched to its limit, so that upon further expansion by a tubing expansion tool, the film splits, releasing the foam 268 to expand and exposing chemicals to the ambient fluids.
- FIG. 27 there is illusfrated an annular isolator system using a chemical reaction to provide power to forcibly drive a sleeve into an expanded condition.
- a section of expandable tubing 280 carries a sleeve 282 on its outer surface.
- One end 284 of the sleeve 282 is fixed to the tubing 280.
- On the other end of the sleeve 282 is connected a cylindrical piston 286 carried between a sleeve 288 and the tubing 280.
- piston 286 On the end of piston 286 is a seal 290 between the piston 286 and the sleeve 288 on one side and the expandable tubing 280 on the other side.
- the sleeve 282 may be elastomeric or metallic or may be an expandable metallic sleeve with an elastomeric coating on its outer surface.
- Two chemical chambers 292 and 294 are formed between a portion of the sleeve 288 and the expandable tubing 280.
- a rupture disk 296 separates the chemical chamber 292 from the piston 286.
- a frangible separator 298 separates the chemical chamber 292 from chamber 294.
- an expansion cone is driven from left to right expanding the diameter of the tubing 280.
- the separator is broken allowing the chemicals in chambers 292 and 294 to mix and react.
- the chemicals would produce a hypergolic reaction generating considerable force to break the rupture disk 296 and drive the piston 286 to the right in the figure.
- the sleeve 282 will buckle and fold outward to contact the borehole wall 300.
- a forcing cone passes under the sleeve 282, it will further compress the sleeve 282 against borehole wall 300 forming an annular isolator.
- FIG. 29 there is illustrated an embodiment of the present invention using petal shaped plates to form an annular isolator.
- a series of plates 310 carried on an expandable tubing section 312.
- Each plate has one end attached to the outer surface of tubing 312 along a circumferential line around the tubing.
- the plates are large enough to overlap in the expanded condition shown in Figure 29.
- the plates 310 form a conical barrier between the tubing 312 and a borehole wall. For rurming into the borehole, the plates 310 are folded against the tubing 312 and held in place by a strap 314.
- the strap or ring 314 is made of brittle material which breaks upon any significant expansion. As an expansion cone is driven through the tubing 312 from left to right, the strap 314 is broken, releasing the plates 310 to expand back toward their free state position like an umbrella or flower until they contact a borehole wall.
- One or more sets of the plates 310 may be used in conjunction with other embodiments of the present invention such as those shown in Figures 10 and 11.
- the plates 310 may be used in place of the annular elastomeric rings 114, 116, 126 and 128 shown in those figures.
- the plates 310 may be made of metal and may be coated with an elastomeric material to improve sealing between the individual plates and between the plates and the borehole wall.
- the plates may be permeable to fluids, but impermeable to gels or to particulates.
- permeable plates may be used to trap or filter out fine sand occurring naturally in the annulus or which is intentionally placed in the annulus to form an annular isolator.
- annular isolator forming material on the outer surface of expandable tubing.
- the material may be a somewhat solid elastomeric material or a fluid material which is injected into the annular space between a section of tubing and a borehole wall to form an annular isolator.
- the overall diameter of the tubing itself must typically be reduced to allow the tubing to be ran into a borehole.
- any material carried on the outside surface of the tubing are subject to damage during installation in a borehole.
- FIG. 30 there is illustrated an embodiment in which the annular isolator forming material is carried on the inner surface of an expandable tubing section.
- a section 320 of expandable tubing in its unexpanded condition.
- a cylindrical sleeve 322 attached at each end to the inner surface of tubing 320.
- the space between sleeve 322 and the tubing 320 defines a compartment in which is carried a quantity of isolator forming material 324.
- the inner sleeve 322 may be of any desired length, preferably less than one tubing section, and may thus carry a considerable quantity of material 324.
- Port 326 preferably includes a check valve which allows material to flow from the inside of tubing 320 to the outside, but prevents flow from the outside to the inside. If desired, various means can be provided to limit the annular flow of material 324 after it passes through the ports 326. Annular elastomeric rings 328 may be placed on the outer surface of tubing 320 to limit the flow of the material 324.
- an expandable bladder 330 may be attached to the outer surface of expandable tubing 320 to confine material which passes through the ports 326.
- the expandable bladder 330 may be formed of an expandable metal sleeve or elastomeric sleeve or a combination of the two.
- the embodiment of Figure 30 will be installed in an open borehole at a location which needs an annular isolator.
- An expansion cone is then driven through expandable tubing 320 from left to right.
- the expansion cone reaches the inner sleeve 322
- the sleeve 322 is expanded against the inner wall of tubing 320 applying pressure to material 324 which then flows through the ports 326 to the outer surface of expandable tubing 320.
- the sleeve 322 may be designed so that the ends of sleeve 322 slide on or are torn away from the inner surface of tubing 320 by the expansion cone. As the cone moves, it can compress the sleeve and squeeze the material 324 through the ports 326.
- the compressed inner sleeve 322 would then be forced down hole with the expansion tool.
- the material 324 may be any type of liquid, gas, or liquid like solid (such as glass or other beads) which will inflate the sleeve 330 to form a seal with the borehole wall. If sleeve 330 is used, it is prefe ⁇ ed to provide a pressure relief mechanism like arrangement 157 shown in Figure 13.
- the material 324 may be any liquid or liquid/solid mix that will solidify or have sufficient viscosity that it will stay where placed, or reactive materials such as acid-base cement or cross linked polyacrylamide taught with reference to Figures 10 and 11 above which may be injected through the port 326 to contact borehole fluids and form an annular isolator. If the rings 328 are used to control positioning of reactive materials, it is prefe ⁇ ed that the rings 328 be designed to limit the maximum pressure of such reactive materials.
- the fluid placed in the annulus to form an isolator be very viscous or be able to change properties when exposed to available fluids in the well annulus.
- Thixotropic materials which are more viscous when stationary than when being pumped may also provide advantages.
- Various silicone materials are available with these desirable properties. Some are cured by contact with water and become essentially solid. With further reference to Figure 30, such a condensate curing silicone material may be injected into the annulus without use of the sleeve 330 and with or without the use of rings 328.
- Such a curable viscous silicone material will conform to any formation wall contour and will fill micro fractures and porosity some distance into the borehole wall which may cause leakage past other types of isolators.
- This type of curable silicone material may also provide advantages in the embodiments illusfrated in Figures 11, 12, 13 and 35. In the Figures 12 and 13 embodiments, such a material provides a good material for inflating the sleeves 154 and 158 and any excess fluid vented into the annulus will cure and form a solid isolator.
- a section of expandable tubing 336 has a reduced diameter section 338.
- several ports 340 each preferably including a check valve allowing fluid to flow from inside the tubing 336 to the outside.
- bladder 342 On the outer surface of the tubing 336 in the reduced diameter section 338 is carried an inflatable bladder 342 sealed at each end to the tubing 336.
- Bladder 342 is preferably an elastomeric material. Since bladder 342 is carried on the reduced diameter section 338, its uninflated outer diameter is no greater than the outer diameter of tubing 336.
- An expansion cone tool 344 is shown expanding tubing 336 from left to right.
- mandrel 346 are carried external seals 348 sized to produce a fluid tight seal with the inner surface of the reduced diameter section 338 of the tubing 336.
- the mandrel 346 includes ports 345 from its inner fluid passageway to its outer surface. When the expansion tool 344 reaches the point illustrated in Figure 31, the seals 348 form a fluid tight seal with the inner surface of reduced diameter tubing section 338.
- the expandable bladder 342 may be replaced with one or more solid elastomeric rings.
- two or more of the rings shown in Figure 2 may be mounted in the recess 338.
- the benefit of larger unexpanded tubing diameter is achieved by this arrangement.
- the ports 340 may be eliminated or may be used to inject a fluid, preferably reactive, into the annulus between the rings before or after expansion of tubing 336.
- an expandable tubing 356 is shown in place within a borehole 358.
- the expandable tubing 356 carries an elastomeric sleeve 360 on its outer surface. In place of the sleeve 360, several elastomeric rings such as shown in Figure 2 may be used if desired.
- a pressure expansion tool 362 is shown having been run in from the surface location to the location of the sleeve 360.
- the tool 362 includes seals 364 which form a fluid tight seal with the inner wall of tubing 356.
- the tool 362 includes side ports 366 located between seals 364. It preferably includes a pressure relief valve 367. After the expansion tool 362 is positioned as shown, fluid is pumped from the surface into the tool 362 at sufficient pressure to expand and overexpand the tubing 356.
- the relief valve limits the pressure to avoid rupturing the tubing 356.
- the tool 362 may be moved on through the tubing 356 to other locations where external sleeves such as 360 are carried and expand them into contact with the borehole wall 358 to form other annular isolators.
- the expansion system shown in Figure 32 may be used either before or after normal expansion of the tubing 356. If it is performed before normal expansion, the tool 362 may carry an adjustable expansion cone or may pick up a cone from the bottom of the tubing string for expansion as the tool 362 is withdrawn from the tubing 356. If performed after normal expansion of the tubing 356, the seals 364 may be inflatable seals allowing isolation of the zones which need over expansion after the normal expansion process is performed.
- FIG. 33 a system for over expansion of expandable tubing using hydroforming techniques is illustrated.
- a section of expandable tubing 370 carrying an elastomeric sleeve 372 on its outer surface is illustrated.
- a pair of slips 374 are positioned on the inside of tubing 370 on each side of the barrier 372. Forces are then applied driving the slips towards one another and placing the portion of tubing 370 under the rubber sleeve 372 in compression.
- the axial compression reduces the internal pressure required to expand tubing 370 and allows it to expand to a larger diameter without rupturing.
- the pressure within the tubing 370 may be then raised to expand the section which is in axial compression caused by the slips 374.
- the tubing will expand as shown in Figure 34 until the rubber sleeve 372 contacts the borehole wall 376. This will cause an increase of pressure which indicates that an annular isolator has been formed.
- the slips 374 may then be released and moved to other locations for expansion to form other annular isolators.
- the expansion tool shown in Figure 32 may be used in conjunction with the slips shown in Figures 33 and 34 so that the expansion pressure may be isolated to the annular barrier area of interest.
- a conduit 378 may be positioned through the rabber sleeve 372 for providing power, confrol, communications signals, etc. to and from down hole equipment as discussed above with reference to conduit 45 in Figure 2.
- FIG. 35 there is illustrated an embodiment of the present invention which allows formation of a conforming annular isolator after expansion of expandable tubing.
- a section of expandable tubing 380 positioned within an open borehole 382.
- the tubing 380 carries a pair of elastomeric rings 384 and 386. This is the same a ⁇ angement as illustrated in Figure 2.
- the expansion ring 386 has been compressed between the borehole wall 382 and the tubing 380 to form a seal while the expansion ring 384 may not be tightly sealed against the borehole wall since it has been expanded into an enlarged portion of the borehole 382.
- Expanded tubing 380 includes one or more ports 388 which may preferably include check valves.
- a fluid injection string 390 which may be similar to the device 362 shown in Figure 32, is shown in place within expanded tubing 380.
- Injection string 390 includes seals 392 on either side of a port 394 through the injection tool 390. With the injection tool 390 in position as illustrated, various annular isolator forming materials may be pumped from the surface through ports 394 and 388 into the annular space between expanded tubing 380 and the borehole wall 382.
- the elastomeric rings 384 and 386 tend to keep the injected material from flowing along the annulus.
- a conduit 394 may be positioned through the rings 384 and 386 for providing power, control, communications signals, etc. to and from down hole equipment as discussed above with reference to conduit 45 in Figure 2.
- Crosslinkable polymer systems such as those provided in Halliburton's H2Zero TM and PermSeal TM services would also be suitable.
- Emulsion polymers such as those provided in Halliburton's Matrol TM service may also create a highly viscous gel in place.
- Various cements may also be injected into the annulus with this system.
- the system of Figure 35 is particularly useful if the surrounding formation has excessive porosity.
- the injected fluid may be selected to penetrate into the formation away from the borehole wall 382 to prevent fluids from bypassing the annular isolator by flowing through the formation itself.
- the petal plate embodiment of Figure 28 and 29 may be used in place of the rings 384 and 386 shown in Figure 35.
- a premixed slurry of fine sand can be pumped outside tubing 380 between a pair of the petal plate sets 310.
- the plates 310 should filter out and dehydrate the sand as pressure is increased. It is believed that such a sand pack several feet long would provide a good annular isolator blocking the annular flow of produced fluids.
- This embodiment may also form a sand annular isolator by catching or filtering out naturally occurring sand which is produced from the formations and flows in the annulus.
- FIG. 36 there is illustrated another system for preexpanding an externally carried elastomeric sleeve of the type shown in Figures 6 to 9.
- a section of expandable tubing 400 is shown being expanded from left to right by an expansion tool 402.
- a foldable elastomeric sleeve 404 which may be identical to sleeve 80 of Figure 6, is carried on the outer surface of tubing 400.
- On the right end of sleeve 404 is a stop ring 406 which may be identical to the ring 82 of Figure 6.
- An outer metal sleeve 408 is carried on tubing 400 adjacent the left end of the sleeve 404, and has sliding seals 410 between the inner surface of sleeve 408 and the outer surface of tubing 400.
- An inner sliding sleeve 412 is positioned at the location of the outer sleeve 408 and connected to it by one or more bolts or pins 414. The pins 414 may slide axially in co ⁇ esponding slots 416 through the tubing 400.
- the leading edge 418 of expansion tool 402 is sized to fit within the unexpanded inner diameter of tubing 400 and to push the inner sleeve 412 to the right.
- the expansion tool As the expansion tool is driven to the right, it pushes the sleeve 412, which in turn pushes outer sleeve 408 to the right by means of the pins 414 which slide to the right in slots 416.
- the pins 414 reach the right end of the slots 416, the sleeve 404 will have been folded as illustrated in Figure 6. Further movement of expansion tool 402 shears off the pins 414 so that the inner sleeve 412 may be pushed on down the tubing 400.
- outer sleeve 408 and the sleeve 404 all of these parts are further expanded as illustrated in Figure 7.
- the inner surface of sleeve 408 preferably carries a toothed gripping surface 420, like the surface 59 of Figure 4.
- gripping surface 420 will be adjacent the outer surface of tubing 400.
- the ring 406 may be adapted to slide in response to excessive expansion pressures created by undersized boreholes as discussed above with reference to Figures 3 and 4.
- FIG. 37 there is illustrated yet another system for preexpanding an externally carried elastomeric sleeve of the type shown in Figures 6 to 9.
- a section of expandable tubing 500 is shown being expanded from left to right by an expansion tool 502.
- On the right end of sleeve 504 is a stop ring 506 which may be identical to the ring 82 of Figure 6.
- On the left end of sleeve 504 is attached a slidable ring 508.
- a sleeve 510 is slidably carried on the inner surface of tubing 500.
- a pair of sliding seals 512 provide fluid tight seal between sleeve 510 and the inner surface of tubing 500.
- One or more pins 514 are connected to and extend radially from the inner sleeve 510.
- the pins 514 extend through corresponding slots 516 in the tubing 500 and are positioned adjacent the left end of the ring 508.
- the ring 508 preferably carries gripping teeth 518 on its inner surface.
- the expansion tool 502 is forced from left to right through the tubing 500.
- the tool 502 reaches an edge 520 of the inner sleeve 510, it will begin to push the sleeve 510 to the right.
- the sleeve 510 through pins 514, pushes the outer ring 508 to the right compressing and folding sleeve 504 into the shape shown in Figure 6.
- the pin 514 reaches the end of slot 516, the sleeve 510 stops moving to the right.
- the edge 520 of inner sleeve 510 is preferably sloped to match the shape of expansion tool 502 and limit the amount of force which can be applied axially before the sleeve 510 stops and is expanded by the tool 502.
- the tool 502 then passes through sleeve 510 expanding it, the tubing 500, the outer ring 508 and the sleeve 504. As this occurs, the teeth 518 grip the outer surface of tubing 500 to resist further slipping of the ring 508.
- the ring 506 may be adapted to slide in response to excessive expansion pressures created by undersized boreholes as discussed above with reference to Figures 3 and 4.
- FIG. 12 through 16 and 30 share several functional features and advantages. These are illustrated in a more generic form in figures 38 through 41.
- Each of these embodiments provides a recess or compartment in an expandable tubing in which a flowable material used to form an annular isolator is carried with the expandable tubing when it is run into a borehole.
- a flowable material used to form an annular isolator is carried with the expandable tubing when it is run into a borehole.
- an expandable outer sleeve has certain characteristics which make this multifunction capability possible.
- a section of expanded tubing 530 is shown in an open borehole 532 having an enlarged or washed out portion 534.
- An inflatable sleeve 536 is shown having a first portion 538 inflated into contact with the enlarged borehole portion 534.
- the sleeve portion 538 is designed to allow great expansion at a first pressure level to form an annular isolator in an enlarged borehole wall 534. It may be made of elastomeric material or expandable metal which is corrugated or perforated or otherwise treated to allow greater expansion. If sleeve 536 is corrugated or perforated, it is preferably covered with an elastomeric sleeve.
- Other portions 540
- the sleeve 536 are designed to inflate at pressures higher than the pressure required to inflate the section 538.
- the volume of fluid carried in the tubing 530 as it is ran in or installed in the borehole 532 is selected to be sufficient to inflate sleeve section 538 to its maximum allowable size.
- the borehole section 534 may not only be enlarged, but may have an irregular shape, width greater than height and the bottom may be filled with cuttings making it flatter than the top.
- the volume of inflating fluid carried in the tubing 530 should be sufficient to inflate the sleeve 536 into contact with such rrregular shaped holes so long as it does not exceed the maximum allowable expansion of the sleeve.
- Figure 40 is illusfrated the same tubing 530 and sleeve 536 is a borehole section 544 which is enlarged, but less enlarged than the washed out section 534 of Figure 38.
- the sleeve section 538 has expanded into contact with the borehole wall at a smaller diameter than was required in Figure 38. Only part of the fluid volume carried in the tubing 530 was required to expand sleeve section 538. As the tubing 530 was expanded after the section 538 contacted the borehole wall, the expansion fluid pressure increased to a higher level at which the sleeve section
- the section 540 expands.
- the section 540 has also expanded into contact with the borehole wall 544. In this
- the volume of expansion fluid required to expand both sections 538 and 540 into contact with the borehole wall is the same as the amount carried down hole with the tubing 530. Complete expansion of the tubing 530 therefore does not cause further inflation of the sleeve 536.
- the expanded tubing 530 is shown installed in a borehole 546 which is not washed out. Instead the borehole 546 is of nominal drilled diameter or may actually be undersized due to swelling on contact with drilling fluid.
- the outer sleeve section 538 first expanded into contact with the borehole at a first pressure level. The expansion fluid pressure then increased causing the sleeve section 540 to expand into contact with the borehole wall 546.
- An inflatable sleeve as illustrated in Figures 38-41 may have two, three or more separate sections which expand at different pressures and may or may not include pressure relief valves.
- the embodiments of Figures 12 and 13 have two sleeve sections which expand at different pressures and a relief valve which opens at a third higher pressure.
- the embodiment of Figures 15 and 16 has three sleeve sections, each of which expands at a different pressure level, and as illustrated does not have a pressure relief valve.
- the Figure 15, 16 embodiment may be provided with a pressure relief valve to protect the system from excessive pressure if desired.
- An outer inflatable sleeve 554 extends across the recess 552 to form a compartment for carrying an isolator forming material.
- An external conduit 556 passes through the sleeve 554.
- the conduit 556 may have an opening 557 into the compartment between recess 552 and sleeve 554.
- Figure 43 provides a more detailed view of a sealing a ⁇ angement between the sleeve 554 and the conduit 556 of Figure 42.
- a rubber gasket 558 may be positioned in an opening 560 through each end of the sleeve 554 as illustrated.
- the conduit 556 may be inserted through the gasket 558.
- the gasket forms a fluid tight seal between the conduit 556 and the sleeve 554 to prevent flow of fluids between the annulus and the compartment between sleeve 554 and the tubing recess 552.
- Figure 44 illustrates another a ⁇ angement for providing one or more conduits in the annulus where an annular isolator is positioned.
- An inflatable sleeve 561 is carried on an expandable tubing 562, forming a compartment in which an annular isolator forming material may be carried down hole with the tubing 562.
- the sleeve 561 has a longitudinal recess 564 in which is carried two conduits 566.
- a rabber gasket 568 has external dimensions matching the recess 564 and two holes for carrying the two conduits 566.
- the gasket 568 When the sleeve 561 is expanded into contact with a borehole wall to form an annular isolator, the gasket 568 will act as an annular isolator for that portion of the annulus between the conduits 566 and the sleeve 561 and will protect the conduits 566.
- conduits 556 and 566 may carry various copper or other conductors or fiber optics or may carry hydraulic fluid or other materials.
- the side port 557 may be used to carry fluid for inflating the sleeve 554 if desired.
- the conduit may pass through a series of sleeves 554 and they may all be inflated to the same pressure with a single conduit 556 having side ports 557 in each sleeve.
- the conduit 556 may be used to deliver one part of a two part chemical system with the other part carried down hole with the tubing.
- the conduit 556 may be used to couple electrical power to heaters to activate chemical reactions. Either electrical power or hydraulic fluid may be used to open and close valves which may control inflation of annular isolators during installation of a production string, or may be used during production to control flow of produced fluids in each of the isolated producing sections.
- the dual conduit arrangement of Figure 44 may provide two hydraulic lines which can be used to control and power a plurality of down hole control systems.
- the sleeve 580 is illustrated in an unrestrained or as-molded shape.
- Each end 582 is a simple cylindrical elastomeric sleeve.
- Between the ends 582 are a series of circumferential corrugations 584.
- the corrugations 584 have inner curved portions 586 having an inner diameter corresponding to the inner diameter of end portions 582. This inner diameter is sized to fit on the outer surface of an unexpanded expandable tubing section.
- the maximum diameter of corrugations 584 is sized to contact or come close to the wall of a washed out borehole section without tubing expansion.
- wire bands 588 may be used to to maintain the corrugated shape when the sleeve 580 is compressed as discussed below.
- the sleeve 580 is attached to expandable tubing with a sliding ring like ring 60 and a fixed ring like ring 58 of Figure 3.
- the sleeve 580 is then stretched axially until the corrugations are substantially flattened against the tubing and the sliding ring is latched into a restraining recess. Note that axial stretching of the elastomer is not essential to flattening the corrugations.
- the flattened sleeve 580 is then carried with the tubing as it is installed in a borehole. Upon expansion of the tubing in the borehole, the sliding ring will be released as shown in Figure 4 and will tend to return to its corrugated shape. As expansion continues the sliding ring will be pushed by the expansion cone as shown in Figures 6 and 7 to axially compress the sleeve
- the sleeve 580 will take the form shown in Figure 45 and then be further compressed until the corrugations 584 are tightly pressed together.
- the wire bands 588 are prefe ⁇ ed to maintain the shape after full compression.
- the alternative axial compression and radial expansion systems shown in Figures 36 and 37 may be used with the sleeve 580 if desired. It can be seen that by molding the sleeve 580 in the form shown in Figure 45, the sleeve will have a small radial height as run into the borehole and a very predictable radial height after it has been released and returned to its corrugated shape. As with other embodiments described herein, the sleeve 580 will then be further expanded with the expandable tubing as the expanding tool passes under the sleeve 580.
- various fluids may be used in the present invention to inflate an external sleeve, bladder, etc. to form an annular isolator or may be injected directly into the annulus between tubing and a borehole wall to form an annular isolator by itself or in combination with external elastomeric rings, sleeves, etc. carried on the tubing.
- These fluids may include a variety of single parts liquids which are viscous or thixotropic as carried down hole in the tubing. They may include chemical systems which react with ambient fluids to become viscous, semisolid or solid. They may also include flowable solid materials such a glass beads.
- annular isolator is formed of a viscous or semisolid material either directly in contact with a borehole wall or used as a fluid to inflate a metallic and/or elastomeric sleeve.
- elastomeric materials By proper selection of elastomeric materials, it can swell upon contact with well bore fluids or setting fluids carried in or injected into production tubing. For example, low acrylic-nitrile swells by as much as fifty percent when contacted by xylene. Simple EPDM compounds swell when contacted by hydrocarbons. This approach may provide additional expansion and isolation in the embodiments shown in Figures 2, 4, 5, 6, 12, 15, 19, 22, 25, 30, 31, 32, 34 and 35. It may be desirable to encase the swellable elastomer inside a nonswellable elastomer. Elastomers which have been expanded by this method may lose some physical strength. A nonswellable outer layer would also prevent loss of the swelling agent and shrinkage of the swellable material.
- the elastomeric sleeve 330 can be made of two layers, with the inner layer swellable and the outer layer not swellable.
- the fluid 324 can be selected to cause the inner layer to swell.
- the fluid 324 and inner layer of elastomer would tend to fill the expanded member 330 with a solid or semisolid mass.
- the inflating fluids described herein it is often desirable for the inflating fluids described herein to be of low viscosity while being used to inflate a sleeve or being pumped directly into an annulus.
- Low viscosity fluids allow some of the fluid to flow into microfractures or into the formation to help stop fluids from bypassing the annular isolator.
- Many two part chemical systems are available for creating such viscous, semisolid, rubbery or solid materials. Some, for example the silicone materials or the polyacrylamide materials, react with available water to form a thick fluid. Others require a two part chemical system or a catalyst to cause the chemicals to react.
- the Figure 10 embodiment delivers two chemical components in dry condition to be reacted together with ambient water.
- the Figure 24 embodiment delivers and mixes a two part chemical system to the location where an annular isolator is needed.
- the corrugated tubing section 160 provides four separate compartments in which various chemical systems may be carried with the tubing as installed to be mixed upon expansion of the tubing.
- the delivery system includes a single recess or compartment.
- a two part chemical system can be used by encapsulating one part of the chemical system, or a catalyst, in bags, tubes, microspheres, microcapsules, etc. carried in the other part of the chemical system.
- the port 326 can be shaped to cause rapturing of such bags, tubes, microcapsules, etc. and mixing of the materials as they pass through the port.
- any one of the annular isolators 28, 30, 36, 38 shown in Figure 1 may actually comprise two or more of the individual isolators illustrated in other figures. If desired, pairs of such individual isolators may be a ⁇ anged closely to provide separate recesses or storage compartments for carrying each part of a two part chemical system in the tubing, to be mixed only after tubing expansion.
- an embodiment according to Figure 12 or 13 could be spaced a short distance up hole from an embodiment like Figure 11.
- the Figure 11 embodiment could carry a catalyst for the material carried in the Figure 12 or 13 embodiment.
- Figure 30 embodiment could include two internal sleeves 322 each carrying one part of a two part chemical system and each having a port 326 located between the pair of elastomeric rings 328. Upon expansion, both parts of the chemical system would be injected into the annulus and isolated between rings 328 to mix and react.
- any one of the described individual isolators may include one of the one-component chemicals or swellables to be ejected from the relief system and form an annular isolator on contact or reaction with the ambient fluids in the annulus.
- a mechanical isolator or isolators e.g. the inflatable member(s)
- a chemical or swellable isolator formed as a result of the materials ejected through the relief systems into the annulus
- annular isolator forming material is preferably carried down hole in a reservoir or compartment formed in part by a tubing wall.
- the inflation fluid compartment is formed between a reduced diameter portion of the tubing and an outer sleeve.
- a compartment is formed between an inner sleeve and the inside surface of a tubing. In either case, the material is carried down hole with the tubing as it is run in or installed in the borehole. It is prefe ⁇ ed that the compartment be entirely, or at least in part, located within the outer diameter of the tubing as it is ran in the borehole.
- an expandable bladder in addition to a cone type expansion tool. For example, if a good annular isolator is not achieved after expansion with a cone type tool, an expandable bladder may be used to further expand the isolator to achieve sealing contact with a borehole wall.
- An expandable bladder may also be used for pressure or leak testing an installed tubing string. For example, an expandable bladder may be expanded inside the tubing at the location where an annular isolator has been installed according to one of the embodiments disclosed herein. The tubing may be pressured up to block flow in the tubing itself to allow detection of annular flow past the installed isolator. If excessive leakage is detected, the bladder pressure may be increased to further expand the isolator to better seal against the borehole wall.
- the system is illustrated using an expansion tool which travels down hole as it expands expandable tubing and deploys an annular isolator.
- Each of these systems may operate equally well with an expansion tool which travels up hole during the tubing expansion process.
- the locations of various ports and relief valves may be changed if the direction of travel of the expansion tool is changed.
- the term up hole means in the direction of the surface location of a well.
Abstract
Description
Claims
Priority Applications (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU2003270795A AU2003270795A1 (en) | 2002-09-23 | 2003-09-18 | Annular isolators for expandable tubulars in wellbores |
BRPI0314637-5A BR0314637B1 (en) | 2002-09-23 | 2003-09-18 | Systems for forming an annular insulator between an expandable pipe and a borehole, for forming an annular insulator between a pipe and a borehole, and for forming an annular insulator between a pipe and a borehole that has a minimum expected diameter and a maximum expected diameter, and methods for forming an annular insulator between a pipe and a borehole |
EP03752507A EP1552105A4 (en) | 2002-09-23 | 2003-09-18 | Annular isolators for expandable tubulars in wellbores |
NO20051246A NO20051246L (en) | 2002-09-23 | 2005-03-10 | Annular insulators for expandable pipe laying in wellbores |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US10/252,621 US6854522B2 (en) | 2002-09-23 | 2002-09-23 | Annular isolators for expandable tubulars in wellbores |
US10/252,621 | 2002-09-23 |
Publications (2)
Publication Number | Publication Date |
---|---|
WO2004027201A2 true WO2004027201A2 (en) | 2004-04-01 |
WO2004027201A3 WO2004027201A3 (en) | 2005-03-24 |
Family
ID=31992977
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2003/029566 WO2004027201A2 (en) | 2002-09-23 | 2003-09-18 | Annular isolators for expandable tubulars in wellbores |
Country Status (8)
Country | Link |
---|---|
US (11) | US6854522B2 (en) |
EP (1) | EP1552105A4 (en) |
CN (1) | CN1708631A (en) |
AU (1) | AU2003270795A1 (en) |
BR (1) | BR0314637B1 (en) |
GB (2) | GB2456082B (en) |
NO (1) | NO20051246L (en) |
WO (1) | WO2004027201A2 (en) |
Cited By (7)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
GB2418692A (en) * | 2003-05-30 | 2006-04-05 | Baker Hughes Inc | Expansion set packer |
GB2432383A (en) * | 2003-09-05 | 2007-05-23 | Enventure Global Technology | Radial expansion of a tubular patch to repair a tubular assembly |
US7712522B2 (en) | 2003-09-05 | 2010-05-11 | Enventure Global Technology, Llc | Expansion cone and system |
US7793721B2 (en) | 2003-03-11 | 2010-09-14 | Eventure Global Technology, Llc | Apparatus for radially expanding and plastically deforming a tubular member |
US7819185B2 (en) | 2004-08-13 | 2010-10-26 | Enventure Global Technology, Llc | Expandable tubular |
US7886831B2 (en) | 2003-01-22 | 2011-02-15 | Enventure Global Technology, L.L.C. | Apparatus for radially expanding and plastically deforming a tubular member |
NO338447B1 (en) * | 2015-01-19 | 2016-08-15 | Archer Oiltools As | A casing annulus cement foundation system and a method for forming a flange collar constituting a cement foundation |
Families Citing this family (414)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7552776B2 (en) * | 1998-12-07 | 2009-06-30 | Enventure Global Technology, Llc | Anchor hangers |
US20070151725A1 (en) * | 1998-12-07 | 2007-07-05 | Shell Oil Company | Expanding a tubular member |
GB9920936D0 (en) * | 1999-09-06 | 1999-11-10 | E2 Tech Ltd | Apparatus for and a method of anchoring an expandable conduit |
US7228915B2 (en) * | 2001-01-26 | 2007-06-12 | E2Tech Limited | Device and method to seal boreholes |
US6932161B2 (en) * | 2001-09-26 | 2005-08-23 | Weatherford/Lams, Inc. | Profiled encapsulation for use with instrumented expandable tubular completions |
US7066284B2 (en) * | 2001-11-14 | 2006-06-27 | Halliburton Energy Services, Inc. | Method and apparatus for a monodiameter wellbore, monodiameter casing, monobore, and/or monowell |
US7040404B2 (en) * | 2001-12-04 | 2006-05-09 | Halliburton Energy Services, Inc. | Methods and compositions for sealing an expandable tubular in a wellbore |
US20050217869A1 (en) * | 2002-04-05 | 2005-10-06 | Baker Hughes Incorporated | High pressure expandable packer |
NO334636B1 (en) * | 2002-04-17 | 2014-05-05 | Schlumberger Holdings | Completion system for use in a well, and method for zone isolation in a well |
US7055598B2 (en) * | 2002-08-26 | 2006-06-06 | Halliburton Energy Services, Inc. | Fluid flow control device and method for use of same |
US6935432B2 (en) * | 2002-09-20 | 2005-08-30 | Halliburton Energy Services, Inc. | Method and apparatus for forming an annular barrier in a wellbore |
US6854522B2 (en) * | 2002-09-23 | 2005-02-15 | Halliburton Energy Services, Inc. | Annular isolators for expandable tubulars in wellbores |
US7828068B2 (en) * | 2002-09-23 | 2010-11-09 | Halliburton Energy Services, Inc. | System and method for thermal change compensation in an annular isolator |
US7152687B2 (en) * | 2003-11-06 | 2006-12-26 | Halliburton Energy Services, Inc. | Expandable tubular with port valve |
US9109429B2 (en) | 2002-12-08 | 2015-08-18 | Baker Hughes Incorporated | Engineered powder compact composite material |
US8403037B2 (en) | 2009-12-08 | 2013-03-26 | Baker Hughes Incorporated | Dissolvable tool and method |
US9682425B2 (en) | 2009-12-08 | 2017-06-20 | Baker Hughes Incorporated | Coated metallic powder and method of making the same |
US9101978B2 (en) | 2002-12-08 | 2015-08-11 | Baker Hughes Incorporated | Nanomatrix powder metal compact |
US9079246B2 (en) | 2009-12-08 | 2015-07-14 | Baker Hughes Incorporated | Method of making a nanomatrix powder metal compact |
US6834725B2 (en) * | 2002-12-12 | 2004-12-28 | Weatherford/Lamb, Inc. | Reinforced swelling elastomer seal element on expandable tubular |
GB0230189D0 (en) * | 2002-12-27 | 2003-02-05 | Weatherford Lamb | Downhole cutting tool and method |
US20040129431A1 (en) * | 2003-01-02 | 2004-07-08 | Stephen Jackson | Multi-pressure regulating valve system for expander |
US7004248B2 (en) * | 2003-01-09 | 2006-02-28 | Weatherford/Lamb, Inc. | High expansion non-elastomeric straddle tool |
US7178603B2 (en) * | 2003-01-29 | 2007-02-20 | Baker Hughes Incorporated | Method and apparatus for ECP element inflation utilizing solid laden fluid mixture |
GB0303152D0 (en) * | 2003-02-12 | 2003-03-19 | Weatherford Lamb | Seal |
GB2398582A (en) * | 2003-02-20 | 2004-08-25 | Schlumberger Holdings | System and method for maintaining zonal isolation in a wellbore |
US7870898B2 (en) * | 2003-03-31 | 2011-01-18 | Exxonmobil Upstream Research Company | Well flow control systems and methods |
US6823943B2 (en) * | 2003-04-15 | 2004-11-30 | Bemton F. Baugh | Strippable collapsed well liner |
GB0412131D0 (en) * | 2004-05-29 | 2004-06-30 | Weatherford Lamb | Coupling and seating tubulars in a bore |
US7104322B2 (en) * | 2003-05-20 | 2006-09-12 | Weatherford/Lamb, Inc. | Open hole anchor and associated method |
US6994170B2 (en) * | 2003-05-29 | 2006-02-07 | Halliburton Energy Services, Inc. | Expandable sand control screen assembly having fluid flow control capabilities and method for use of same |
GB0320252D0 (en) * | 2003-08-29 | 2003-10-01 | Caledyne Ltd | Improved seal |
MY137430A (en) * | 2003-10-01 | 2009-01-30 | Shell Int Research | Expandable wellbore assembly |
IL159838A0 (en) | 2004-01-13 | 2004-06-20 | Yehuda Binder | Information device |
GB2428264B (en) * | 2004-03-12 | 2008-07-30 | Schlumberger Holdings | Sealing system and method for use in a well |
US7735566B2 (en) * | 2004-04-06 | 2010-06-15 | Baker Hughes Incorporated | One trip completion system |
US10316616B2 (en) * | 2004-05-28 | 2019-06-11 | Schlumberger Technology Corporation | Dissolvable bridge plug |
US8211247B2 (en) * | 2006-02-09 | 2012-07-03 | Schlumberger Technology Corporation | Degradable compositions, apparatus comprising same, and method of use |
US7478686B2 (en) * | 2004-06-17 | 2009-01-20 | Baker Hughes Incorporated | One trip well drilling to total depth |
SE527426C2 (en) * | 2004-07-08 | 2006-02-28 | Atlas Copco Rocktech Ab | Device for attaching an expandable packer to a hole |
US7478687B2 (en) * | 2004-07-19 | 2009-01-20 | Baker Hughes Incorporated | Coiled tubing conveyed milling |
GB0417328D0 (en) * | 2004-08-04 | 2004-09-08 | Read Well Services Ltd | Apparatus and method |
US20060042801A1 (en) * | 2004-08-24 | 2006-03-02 | Hackworth Matthew R | Isolation device and method |
US7322412B2 (en) * | 2004-08-30 | 2008-01-29 | Halliburton Energy Services, Inc. | Casing shoes and methods of reverse-circulation cementing of casing |
US7469750B2 (en) * | 2004-09-20 | 2008-12-30 | Owen Oil Tools Lp | Expandable seal |
GB2419148B (en) * | 2004-10-12 | 2009-07-01 | Weatherford Lamb | Methods and apparatus for manufacturing of expandable tubular |
CN101076652A (en) * | 2004-12-15 | 2007-11-21 | 国际壳牌研究有限公司 | Wellbore system extending through a salt layer |
CA2530969C (en) * | 2004-12-21 | 2010-05-18 | Schlumberger Canada Limited | Water shut off method and apparatus |
US7422071B2 (en) * | 2005-01-31 | 2008-09-09 | Hills, Inc. | Swelling packer with overlapping petals |
US7117941B1 (en) | 2005-04-11 | 2006-10-10 | Halliburton Energy Services, Inc. | Variable diameter expansion tool and expansion methods |
US20060232019A1 (en) * | 2005-04-19 | 2006-10-19 | Garrison Hubert F | Encapsulated back-up system for use with seal system |
US7360590B2 (en) * | 2005-04-29 | 2008-04-22 | Baker Hughes Incorporated | Energized thermoplastic sealing element and method of use |
EP1719873A1 (en) * | 2005-05-04 | 2006-11-08 | Services Petroliers Schlumberger | Expandable sleeve |
US7730941B2 (en) * | 2005-05-26 | 2010-06-08 | Baker Hughes Incorporated | Expandable tool with enhanced expansion capability |
US7431078B2 (en) * | 2005-05-27 | 2008-10-07 | Baker Hughes Incorporated | Using pipe shrinkage upon expansion to actuate a downhole tool |
US7870909B2 (en) * | 2005-06-09 | 2011-01-18 | Schlumberger Technology Corporation | Deployable zonal isolation system |
US20070000664A1 (en) * | 2005-06-30 | 2007-01-04 | Weatherford/Lamb, Inc. | Axial compression enhanced tubular expansion |
CN100432369C (en) * | 2005-07-06 | 2008-11-12 | 中国石油大学(北京) | Rotary expansion tool for expansible pipe |
US7441605B2 (en) * | 2005-07-13 | 2008-10-28 | Baker Hughes Incorporated | Optical sensor use in alternate path gravel packing with integral zonal isolation |
US7373991B2 (en) * | 2005-07-18 | 2008-05-20 | Schlumberger Technology Corporation | Swellable elastomer-based apparatus, oilfield elements comprising same, and methods of using same in oilfield applications |
GB2442393B (en) * | 2005-07-22 | 2010-01-27 | Shell Int Research | Apparatus and methods for creation of down hole annular barrier |
CA2555563C (en) * | 2005-08-05 | 2009-03-31 | Weatherford/Lamb, Inc. | Apparatus and methods for creation of down hole annular barrier |
US7407007B2 (en) * | 2005-08-26 | 2008-08-05 | Schlumberger Technology Corporation | System and method for isolating flow in a shunt tube |
US8567494B2 (en) * | 2005-08-31 | 2013-10-29 | Schlumberger Technology Corporation | Well operating elements comprising a soluble component and methods of use |
US7543640B2 (en) * | 2005-09-01 | 2009-06-09 | Schlumberger Technology Corporation | System and method for controlling undesirable fluid incursion during hydrocarbon production |
US8231947B2 (en) * | 2005-11-16 | 2012-07-31 | Schlumberger Technology Corporation | Oilfield elements having controlled solubility and methods of use |
US20070114034A1 (en) * | 2005-11-18 | 2007-05-24 | Chevron U.S.A. Inc. | Controlling pressure and static charge build up within an annular volume of a wellbore |
FR2893973B1 (en) * | 2005-11-30 | 2008-02-15 | Saltel Ind Soc Par Actions Sim | METHOD AND DEVICE FOR CEMENTING A WELL OR PIPING |
US7661471B2 (en) * | 2005-12-01 | 2010-02-16 | Baker Hughes Incorporated | Self energized backup system for packer sealing elements |
US7392841B2 (en) * | 2005-12-28 | 2008-07-01 | Baker Hughes Incorporated | Self boosting packing element |
US7552777B2 (en) * | 2005-12-28 | 2009-06-30 | Baker Hughes Incorporated | Self-energized downhole tool |
US7387158B2 (en) * | 2006-01-18 | 2008-06-17 | Baker Hughes Incorporated | Self energized packer |
BRPI0621246C8 (en) * | 2006-02-03 | 2018-11-27 | Exxonmobil Upstream Res Co | method to operate a well |
US8770261B2 (en) | 2006-02-09 | 2014-07-08 | Schlumberger Technology Corporation | Methods of manufacturing degradable alloys and products made from degradable alloys |
US8220554B2 (en) | 2006-02-09 | 2012-07-17 | Schlumberger Technology Corporation | Degradable whipstock apparatus and method of use |
AU2007243920B2 (en) * | 2006-04-03 | 2012-06-14 | Exxonmobil Upstream Research Company | Wellbore method and apparatus for sand and inflow control during well operations |
US7699112B2 (en) * | 2006-05-05 | 2010-04-20 | Weatherford/Lamb, Inc. | Sidetrack option for monobore casing string |
EP2267268A3 (en) * | 2006-05-22 | 2016-03-23 | Weatherford Technology Holdings, LLC | Apparatus and methods to protect connections |
CN101605963B (en) * | 2006-05-26 | 2013-11-20 | 欧文石油工具有限合伙公司 | Configurable wellbore zone isolation system and related methods |
US7703533B2 (en) * | 2006-05-30 | 2010-04-27 | Baker Hughes Incorporated | Shear type circulation valve and swivel with open port reciprocating feature |
US7452161B2 (en) * | 2006-06-08 | 2008-11-18 | Halliburton Energy Services, Inc. | Apparatus for sealing and isolating pipelines |
US7575062B2 (en) * | 2006-06-09 | 2009-08-18 | Halliburton Energy Services, Inc. | Methods and devices for treating multiple-interval well bores |
US7478676B2 (en) * | 2006-06-09 | 2009-01-20 | Halliburton Energy Services, Inc. | Methods and devices for treating multiple-interval well bores |
US7441596B2 (en) * | 2006-06-23 | 2008-10-28 | Baker Hughes Incorporated | Swelling element packer and installation method |
US7717180B2 (en) * | 2006-06-29 | 2010-05-18 | Halliburton Energy Services, Inc. | Swellable elastomers and associated methods |
US8211248B2 (en) * | 2009-02-16 | 2012-07-03 | Schlumberger Technology Corporation | Aged-hardenable aluminum alloy with environmental degradability, methods of use and making |
US7562704B2 (en) * | 2006-07-14 | 2009-07-21 | Baker Hughes Incorporated | Delaying swelling in a downhole packer element |
US7552767B2 (en) * | 2006-07-14 | 2009-06-30 | Baker Hughes Incorporated | Closeable open cell foam for downhole use |
US7828055B2 (en) * | 2006-10-17 | 2010-11-09 | Baker Hughes Incorporated | Apparatus and method for controlled deployment of shape-conforming materials |
US7484565B2 (en) * | 2006-10-25 | 2009-02-03 | Halliburton Energy Services, Inc. | Methods and apparatus for injecting fluids at a subterranean location in a well |
US20080110643A1 (en) * | 2006-11-09 | 2008-05-15 | Baker Hughes Incorporated | Large bore packer and methods of setting same |
US7650945B2 (en) * | 2006-11-13 | 2010-01-26 | Baker Hughes Incorporated | Inflatable closure system |
WO2008060297A2 (en) * | 2006-11-15 | 2008-05-22 | Halliburton Energy Services, Inc. | Well tool including swellable material and integrated fluid for initiating swelling |
US7661476B2 (en) * | 2006-11-15 | 2010-02-16 | Exxonmobil Upstream Research Company | Gravel packing methods |
WO2008062187A1 (en) | 2006-11-21 | 2008-05-29 | Swelltec Limited | Downhole apparatus and method |
GB2444060B (en) * | 2006-11-21 | 2008-12-17 | Swelltec Ltd | Downhole apparatus and method |
US7909088B2 (en) * | 2006-12-20 | 2011-03-22 | Baker Huges Incorporated | Material sensitive downhole flow control device |
US8485265B2 (en) * | 2006-12-20 | 2013-07-16 | Schlumberger Technology Corporation | Smart actuation materials triggered by degradation in oilfield environments and methods of use |
US7467664B2 (en) * | 2006-12-22 | 2008-12-23 | Baker Hughes Incorporated | Production actuated mud flow back valve |
US7367391B1 (en) * | 2006-12-28 | 2008-05-06 | Baker Hughes Incorporated | Liner anchor for expandable casing strings and method of use |
BRPI0721215B1 (en) | 2007-02-06 | 2018-05-08 | Halliburton Energy Services Inc | shutter unit, and, method for building a shutter unit |
US7934559B2 (en) * | 2007-02-12 | 2011-05-03 | Baker Hughes Incorporated | Single cycle dart operated circulation sub |
US20080220991A1 (en) * | 2007-03-06 | 2008-09-11 | Halliburton Energy Services, Inc. - Dallas | Contacting surfaces using swellable elements |
US7918281B2 (en) * | 2007-03-06 | 2011-04-05 | Baker Hughes Incorporated | Method of treating flow conduits and vessels with foamed composition |
US8678350B2 (en) | 2007-03-15 | 2014-03-25 | Baker Hughes Incorporated | Valve and method for controlling flow in tubular members |
US8186428B2 (en) * | 2007-04-03 | 2012-05-29 | Baker Hughes Incorporated | Fiber support arrangement for a downhole tool and method |
DE602007007726D1 (en) * | 2007-04-06 | 2010-08-26 | Schlumberger Services Petrol | Method and composition for zone isolation of a borehole |
BRPI0810617A2 (en) * | 2007-04-27 | 2015-09-15 | Mi Llc | use of curable liquid elastomers to produce gels to treat a wellbore |
US20080290603A1 (en) * | 2007-05-24 | 2008-11-27 | Baker Hughes Incorporated | Swellable material and method |
US7857078B2 (en) * | 2007-05-29 | 2010-12-28 | Baker Hughes Incorporated | Cutting tools and methods of making the same |
US7717172B2 (en) * | 2007-05-30 | 2010-05-18 | Schlumberger Technology Corporation | Methods and apparatus to sample heavy oil from a subteranean formation |
US7703542B2 (en) * | 2007-06-05 | 2010-04-27 | Baker Hughes Incorporated | Expandable packer system |
CN101730785B (en) * | 2007-06-25 | 2013-07-17 | 维斯塔斯风力系统集团公司 | A sealing device for a tubing arrangement, tubing structure and method for sealing the tubing structure |
GB0712345D0 (en) * | 2007-06-26 | 2007-08-01 | Metcalfe Paul D | Downhole apparatus |
US7647966B2 (en) | 2007-08-01 | 2010-01-19 | Halliburton Energy Services, Inc. | Method for drainage of heavy oil reservoir via horizontal wellbore |
BRPI0815539B8 (en) * | 2007-08-17 | 2019-08-20 | Shell Int Research | method for controlling the inflow of crude oil, natural gas and / or other effluents. |
US7779923B2 (en) * | 2007-09-11 | 2010-08-24 | Enventure Global Technology, Llc | Methods and apparatus for anchoring and expanding tubular members |
US7832468B2 (en) * | 2007-10-03 | 2010-11-16 | Pine Tree Gas, Llc | System and method for controlling solids in a down-hole fluid pumping system |
DK178464B1 (en) * | 2007-10-05 | 2016-04-04 | Mærsk Olie Og Gas As | Method of sealing a portion of annulus between a well tube and a well bore |
MY160808A (en) * | 2007-10-16 | 2017-03-31 | Exxonmobil Upstream Res Co | Fluid control apparatus and methods for production and injection wells |
US7913755B2 (en) | 2007-10-19 | 2011-03-29 | Baker Hughes Incorporated | Device and system for well completion and control and method for completing and controlling a well |
WO2009053343A2 (en) * | 2007-10-23 | 2009-04-30 | Shell Internationale Research Maatschappij B.V. | Method of radially expanding a tubular element in a wellbore provided with a control line |
US7789140B2 (en) * | 2007-11-16 | 2010-09-07 | Enventure Global Technology, Llc | System and method for radially expanding and plastically deforming a wellbore casing |
WO2009073538A1 (en) * | 2007-11-30 | 2009-06-11 | Baker Hughes Incorporated | Downhole tool with capillary biasing system |
GB0724122D0 (en) * | 2007-12-11 | 2008-01-23 | Rubberatkins Ltd | Sealing apparatus |
US7832489B2 (en) * | 2007-12-19 | 2010-11-16 | Schlumberger Technology Corporation | Methods and systems for completing a well with fluid tight lower completion |
US7832477B2 (en) * | 2007-12-28 | 2010-11-16 | Halliburton Energy Services, Inc. | Casing deformation and control for inclusion propagation |
US20090176667A1 (en) * | 2008-01-03 | 2009-07-09 | Halliburton Energy Services, Inc. | Expandable particulates and methods of their use in subterranean formations |
US8555961B2 (en) * | 2008-01-07 | 2013-10-15 | Halliburton Energy Services, Inc. | Swellable packer with composite material end rings |
US7703520B2 (en) * | 2008-01-08 | 2010-04-27 | Halliburton Energy Services, Inc. | Sand control screen assembly and associated methods |
US7712529B2 (en) * | 2008-01-08 | 2010-05-11 | Halliburton Energy Services, Inc. | Sand control screen assembly and method for use of same |
SE531913C2 (en) * | 2008-01-18 | 2009-09-08 | Fumex Ab | Ventilation arm, ventilation system, and device comprising in a ventilation system |
WO2009097189A1 (en) * | 2008-01-28 | 2009-08-06 | Schlumberger Canada Limited | Well thermal insulation for formation sampling of viscous fluids |
US20090194949A1 (en) * | 2008-02-04 | 2009-08-06 | Tamar Technological Development Ltd. | Shaft for viscous sealant systems |
GB0802237D0 (en) * | 2008-02-07 | 2008-03-12 | Swellfix Bv | Downhole seal |
US9004182B2 (en) * | 2008-02-15 | 2015-04-14 | Baker Hughes Incorporated | Expandable downhole actuator, method of making and method of actuating |
US9551201B2 (en) | 2008-02-19 | 2017-01-24 | Weatherford Technology Holdings, Llc | Apparatus and method of zonal isolation |
WO2009105575A1 (en) * | 2008-02-19 | 2009-08-27 | Weatherford/Lamb, Inc. | Expandable packer |
US7891432B2 (en) * | 2008-02-26 | 2011-02-22 | Schlumberger Technology Corporation | Apparatus and methods for setting one or more packers in a well bore |
DK178243B1 (en) * | 2008-03-06 | 2015-09-28 | Mærsk Olie Og Gas As | Fremgangsmåde til forsegling af en ringformet åbning i et borehul |
DK178742B1 (en) | 2008-03-06 | 2016-12-19 | Maersk Olie & Gas | Method and apparatus for injecting one or more treatment fluids down into a borehole |
DK178489B1 (en) * | 2008-03-13 | 2016-04-18 | Maersk Olie & Gas | Tools and methods for sealing openings or leaks in a wellbore |
US20090255691A1 (en) * | 2008-04-10 | 2009-10-15 | Baker Hughes Incorporated | Permanent packer using a slurry inflation medium |
GB2459457B (en) * | 2008-04-22 | 2012-05-09 | Swelltec Ltd | Downhole apparatus and method |
EP2119867B1 (en) * | 2008-04-23 | 2014-08-06 | Weatherford/Lamb Inc. | Monobore construction with dual expanders |
EP2113546A1 (en) | 2008-04-28 | 2009-11-04 | Schlumberger Holdings Limited | Swellable compositions for borehole applications |
US7806184B2 (en) * | 2008-05-09 | 2010-10-05 | Wavefront Energy And Environmental Services Inc. | Fluid operated well tool |
US7861791B2 (en) * | 2008-05-12 | 2011-01-04 | Halliburton Energy Services, Inc. | High circulation rate packer and setting method for same |
US8555958B2 (en) | 2008-05-13 | 2013-10-15 | Baker Hughes Incorporated | Pipeless steam assisted gravity drainage system and method |
US8171999B2 (en) | 2008-05-13 | 2012-05-08 | Baker Huges Incorporated | Downhole flow control device and method |
US20090292172A1 (en) * | 2008-05-21 | 2009-11-26 | Boston Scientific Scimed, Inc. | Expandable Delivery Devices and Methods of Use |
EP2133509A1 (en) * | 2008-06-12 | 2009-12-16 | Tech Holdings Limited Flo | Open hole packer and seal |
EP2143876A1 (en) * | 2008-07-11 | 2010-01-13 | Welltec A/S | Method for sealing off a water zone in a production well downhole and a sealing arrangement |
US8579047B2 (en) * | 2008-07-11 | 2013-11-12 | Norman DeVerne Houston | Downhole reservoir effluent column pressure restraining apparatus and methods |
US7866383B2 (en) * | 2008-08-29 | 2011-01-11 | Halliburton Energy Services, Inc. | Sand control screen assembly and method for use of same |
US7814973B2 (en) * | 2008-08-29 | 2010-10-19 | Halliburton Energy Services, Inc. | Sand control screen assembly and method for use of same |
US7841409B2 (en) * | 2008-08-29 | 2010-11-30 | Halliburton Energy Services, Inc. | Sand control screen assembly and method for use of same |
US20100052263A1 (en) * | 2008-09-03 | 2010-03-04 | Baker Hughes Incorporated | Electroplated resilient seal |
US8020294B2 (en) | 2008-09-03 | 2011-09-20 | Schlumberger Technology Corporation | Method of constructing an expandable packer |
GB0817149D0 (en) * | 2008-09-19 | 2008-10-29 | Swellfix Bv | Downhole seal |
US7866406B2 (en) * | 2008-09-22 | 2011-01-11 | Baker Hughes Incorporated | System and method for plugging a downhole wellbore |
AU2008362504A1 (en) * | 2008-10-03 | 2010-04-08 | Pine Tree Gas, Llc | System and method for delivering a cable downhole |
MX2011004043A (en) * | 2008-10-17 | 2011-09-26 | Archon Technologies Ltd | Well liner segments for in situ petroleum upgrading and recovery, and method of in situ upgrading and recovery. |
CA2742365C (en) * | 2008-11-03 | 2014-03-18 | Exxonmobil Upstream Research Company | Well flow control systems and methods |
US8794310B2 (en) * | 2008-11-12 | 2014-08-05 | Schlumberger Technology Corporation | Support tube for a swell packer, swell packer, method of manufacturing a swell packer, and method for using a swell packer |
US8113293B2 (en) * | 2008-11-20 | 2012-02-14 | Schlumberger Technology Corporation | Single packer structure for use in a wellbore |
EP2206879B1 (en) | 2009-01-12 | 2014-02-26 | Welltec A/S | Annular barrier and annular barrier system |
US8051913B2 (en) * | 2009-02-24 | 2011-11-08 | Baker Hughes Incorporated | Downhole gap sealing element and method |
US7997338B2 (en) | 2009-03-11 | 2011-08-16 | Baker Hughes Incorporated | Sealing feed through lines for downhole swelling packers |
WO2010107812A1 (en) * | 2009-03-16 | 2010-09-23 | Baker Hughes Incorporated | Rolling sleeve through tubing bridge plug |
US8047298B2 (en) | 2009-03-24 | 2011-11-01 | Halliburton Energy Services, Inc. | Well tools utilizing swellable materials activated on demand |
US8087459B2 (en) * | 2009-03-31 | 2012-01-03 | Weatherford/Lamb, Inc. | Packer providing multiple seals and having swellable element isolatable from the wellbore |
DE102009016820B4 (en) * | 2009-04-09 | 2012-05-24 | Baumann Gmbh | Line system for transporting a liquid |
BRPI1013547A2 (en) | 2009-04-14 | 2016-04-12 | Exxonmobil Upstream Res Co | tubular assembly adapted for downhole use, and method for operating a hydrocarbon-related well |
NO332488B1 (en) * | 2009-04-17 | 2012-10-01 | Reelwell As | Downhole gasket seal |
EP2425093B1 (en) * | 2009-05-01 | 2018-09-12 | Weatherford Technology Holdings, LLC | Wellbore isolation tool using sealing element having shape memory polymer |
GB0909086D0 (en) | 2009-05-27 | 2009-07-01 | Read Well Services Ltd | An active external casing packer (ecp) for frac operations in oil and gas wells |
US8132624B2 (en) * | 2009-06-02 | 2012-03-13 | Baker Hughes Incorporated | Permeability flow balancing within integral screen joints and method |
US8151881B2 (en) * | 2009-06-02 | 2012-04-10 | Baker Hughes Incorporated | Permeability flow balancing within integral screen joints |
US8807216B2 (en) | 2009-06-15 | 2014-08-19 | Halliburton Energy Services, Inc. | Cement compositions comprising particulate foamed elastomers and associated methods |
US8360142B2 (en) * | 2009-06-15 | 2013-01-29 | Enventure Global Technology, Llc | High-ratio tubular expansion |
US8100186B2 (en) * | 2009-07-15 | 2012-01-24 | Enventure Global Technology, L.L.C. | Expansion system for expandable tubulars and method of expanding thereof |
WO2011014666A1 (en) | 2009-07-31 | 2011-02-03 | Bp Corporation North America Inc. | Method to control driving fluid breakthrough during production of hydrocarbons from a subterranean reservoir |
US8522866B2 (en) * | 2009-08-28 | 2013-09-03 | Enventure Global Technology, Llc | System and method for anchoring an expandable tubular to a borehole wall |
BR112012004483A2 (en) | 2009-08-28 | 2016-03-22 | Shell Internationale Reseach Mij B V | system for anchoring an expandable tubular to a borehole wall |
CA2770455C (en) | 2009-08-28 | 2016-06-28 | Shell Internationale Research Maatschappij B.V. | System and method for anchoring an expandable tubular to a borehole wall |
CN102482933A (en) | 2009-08-28 | 2012-05-30 | 国际壳牌研究有限公司 | System and method for anchoring an expandable tubular to a borehole wall |
US8474525B2 (en) | 2009-09-18 | 2013-07-02 | David R. VAN DE VLIERT | Geothermal liner system with packer |
US8297368B2 (en) * | 2009-10-28 | 2012-10-30 | Chevron U.S.A. Inc. | Systems and methods for initiating annular obstruction in a subsurface well |
US20110094755A1 (en) * | 2009-10-28 | 2011-04-28 | Chevron U.S.A. Inc. | Systems and methods for initiating annular obstruction in a subsurface well |
AU2010321679A1 (en) * | 2009-11-19 | 2012-05-31 | Ian Gray | External casing packer |
US20120227969A1 (en) * | 2009-11-19 | 2012-09-13 | Ian Gray | External Casing Packer |
MY164284A (en) * | 2009-11-20 | 2017-11-30 | Exxonmobil Upstream Res Co | Open-hole packer for alternate path gravel packing, and method for completing an open-hole wellbore |
PL2330706T3 (en) | 2009-12-03 | 2017-09-29 | CommScope Connectivity Belgium BVBA | Gel sealing device |
US8261842B2 (en) * | 2009-12-08 | 2012-09-11 | Halliburton Energy Services, Inc. | Expandable wellbore liner system |
US10240419B2 (en) | 2009-12-08 | 2019-03-26 | Baker Hughes, A Ge Company, Llc | Downhole flow inhibition tool and method of unplugging a seat |
US9243475B2 (en) | 2009-12-08 | 2016-01-26 | Baker Hughes Incorporated | Extruded powder metal compact |
US9127515B2 (en) | 2010-10-27 | 2015-09-08 | Baker Hughes Incorporated | Nanomatrix carbon composite |
US8371388B2 (en) * | 2009-12-08 | 2013-02-12 | Halliburton Energy Services, Inc. | Apparatus and method for installing a liner string in a wellbore casing |
US8408317B2 (en) * | 2010-01-11 | 2013-04-02 | Tiw Corporation | Tubular expansion tool and method |
US8464787B2 (en) * | 2010-01-14 | 2013-06-18 | Baker Hughes Incorporated | Resilient foam debris barrier |
US8919433B2 (en) | 2010-01-14 | 2014-12-30 | Baker Hughes Incorporated | Resilient foam debris barrier |
US8839871B2 (en) * | 2010-01-15 | 2014-09-23 | Halliburton Energy Services, Inc. | Well tools operable via thermal expansion resulting from reactive materials |
US8444346B2 (en) * | 2010-02-12 | 2013-05-21 | United Air Temp Heating & Air-Conditioning, Inc. | Method of installing geothermal heat pump system and device for installation |
US8636066B2 (en) * | 2010-03-12 | 2014-01-28 | Baker Hughes Incorporated | Method of enhancing productivity of a formation with unhydrated borated galactomannan gum |
US10989011B2 (en) | 2010-03-12 | 2021-04-27 | Baker Hughes, A Ge Company, Llc | Well intervention method using a chemical barrier |
US9920609B2 (en) | 2010-03-12 | 2018-03-20 | Baker Hughes, A Ge Company, Llc | Method of re-fracturing using borated galactomannan gum |
US8302696B2 (en) | 2010-04-06 | 2012-11-06 | Baker Hughes Incorporated | Actuator and tubular actuator |
EP2381065B1 (en) | 2010-04-20 | 2016-11-16 | Services Pétroliers Schlumberger | System and method for improving zonal isolation in a well |
EP2404975A1 (en) | 2010-04-20 | 2012-01-11 | Services Pétroliers Schlumberger | Composition for well cementing comprising a compounded elastomer swelling additive |
US8857526B2 (en) * | 2010-04-26 | 2014-10-14 | Schlumberger Technology Corporation | Mechanically deployable well isolation mechanism |
WO2011149597A1 (en) | 2010-05-26 | 2011-12-01 | Exxonmobil Upstream Research Company | Assembly and method for multi-zone fracture stimulation of a reservoir using autonomous tubular units |
EP2402554A1 (en) * | 2010-06-30 | 2012-01-04 | Welltec A/S | Fracturing system |
US20120012343A1 (en) * | 2010-07-13 | 2012-01-19 | Wilkin James F | Downhole Packer Having Swellable Sleeve |
US20120012342A1 (en) * | 2010-07-13 | 2012-01-19 | Wilkin James F | Downhole Packer Having Tandem Packer Elements for Isolating Frac Zones |
US8393388B2 (en) * | 2010-08-16 | 2013-03-12 | Baker Hughes Incorporated | Retractable petal collet backup for a subterranean seal |
US9464500B2 (en) | 2010-08-27 | 2016-10-11 | Halliburton Energy Services, Inc. | Rapid swelling and un-swelling materials in well tools |
GB2483856A (en) * | 2010-09-21 | 2012-03-28 | Caledyne Ltd | Inflatable packer |
EP2436874B1 (en) * | 2010-09-30 | 2013-07-31 | Welltec A/S | Drill pipe |
EP3216976A1 (en) * | 2010-10-07 | 2017-09-13 | Welltec A/S | An annular barrier |
WO2012045355A1 (en) * | 2010-10-07 | 2012-04-12 | Welltec A/S | An annular barrier |
US9090955B2 (en) | 2010-10-27 | 2015-07-28 | Baker Hughes Incorporated | Nanomatrix powder metal composite |
US8584753B2 (en) * | 2010-11-03 | 2013-11-19 | Halliburton Energy Services, Inc. | Method and apparatus for creating an annular barrier in a subterranean wellbore |
GB201019358D0 (en) | 2010-11-16 | 2010-12-29 | Darcy Technologies Ltd | Downhole method and apparatus |
US9429236B2 (en) | 2010-11-16 | 2016-08-30 | Baker Hughes Incorporated | Sealing devices having a non-elastomeric fibrous sealing material and methods of using same |
US8561699B2 (en) * | 2010-12-13 | 2013-10-22 | Halliburton Energy Services, Inc. | Well screens having enhanced well treatment capabilities |
AU2011341592B2 (en) | 2010-12-16 | 2016-05-05 | Exxonmobil Upstream Research Company | Communications module for alternate path gravel packing, and method for completing a wellbore |
EA032493B1 (en) | 2010-12-17 | 2019-06-28 | Эксонмобил Апстрим Рисерч Компани | Crossover joint for connecting eccentric flow paths to concentric flow paths |
US9404348B2 (en) | 2010-12-17 | 2016-08-02 | Exxonmobil Upstream Research Company | Packer for alternate flow channel gravel packing and method for completing a wellbore |
EP2636843B1 (en) * | 2010-12-17 | 2014-10-08 | Welltec A/S | Well completion |
BR112013013148B1 (en) | 2010-12-17 | 2020-07-21 | Exxonmobil Upstream Research Company | well bore apparatus and methods for zonal isolation and flow control |
CN103534436B (en) | 2010-12-17 | 2018-01-19 | 埃克森美孚上游研究公司 | Autonomous type downhole conveyance system |
EA026663B1 (en) | 2010-12-17 | 2017-05-31 | Эксонмобил Апстрим Рисерч Компани | Wellbore apparatus and methods for multi-zone well completion, production and injection |
SG190875A1 (en) | 2010-12-17 | 2013-07-31 | Exxonmobil Upstream Res Co | Method for automatic control and positioning of autonomous downhole tools |
EP2469016A1 (en) * | 2010-12-22 | 2012-06-27 | Shell Internationale Research Maatschappij B.V. | System and method for sealing a space in a wellbore |
US8739408B2 (en) | 2011-01-06 | 2014-06-03 | Baker Hughes Incorporated | Shape memory material packer for subterranean use |
US8490707B2 (en) | 2011-01-11 | 2013-07-23 | Schlumberger Technology Corporation | Oilfield apparatus and method comprising swellable elastomers |
US9004184B2 (en) * | 2011-02-02 | 2015-04-14 | Shell Oil Company | Method and wellbore system |
US11215021B2 (en) | 2011-02-16 | 2022-01-04 | Weatherford Technology Holdings, Llc | Anchoring and sealing tool |
EP2675989B1 (en) | 2011-02-16 | 2023-05-17 | Weatherford Technology Holdings, LLC | Stage tool |
US20120205092A1 (en) | 2011-02-16 | 2012-08-16 | George Givens | Anchoring and sealing tool |
US9528352B2 (en) | 2011-02-16 | 2016-12-27 | Weatherford Technology Holdings, Llc | Extrusion-resistant seals for expandable tubular assembly |
CA2827462C (en) | 2011-02-16 | 2016-01-19 | Weatherford/Lamb, Inc. | Anchoring seal |
US20120211226A1 (en) * | 2011-02-17 | 2012-08-23 | Baker Hughes Incorporated | Screen, method of expanding a screen and method of conforming a screen to a borehole |
US8561690B2 (en) * | 2011-03-04 | 2013-10-22 | Halliburton Energy Services, Inc. | Expansion cone assembly for setting a liner hanger in a wellbore casing |
US8584759B2 (en) * | 2011-03-17 | 2013-11-19 | Baker Hughes Incorporated | Hydraulic fracture diverter apparatus and method thereof |
US9850726B2 (en) | 2011-04-27 | 2017-12-26 | Weatherford Technology Holdings, Llc | Expandable open-hole anchor |
US8631876B2 (en) | 2011-04-28 | 2014-01-21 | Baker Hughes Incorporated | Method of making and using a functionally gradient composite tool |
US9080098B2 (en) | 2011-04-28 | 2015-07-14 | Baker Hughes Incorporated | Functionally gradient composite article |
US8869898B2 (en) * | 2011-05-17 | 2014-10-28 | Baker Hughes Incorporated | System and method for pinpoint fracturing initiation using acids in open hole wellbores |
WO2012161854A2 (en) | 2011-05-23 | 2012-11-29 | Exxonmobil Upstream Research Company | Safety system for autonomous downhole tool |
US8955606B2 (en) | 2011-06-03 | 2015-02-17 | Baker Hughes Incorporated | Sealing devices for sealing inner wall surfaces of a wellbore and methods of installing same in a wellbore |
US8905149B2 (en) | 2011-06-08 | 2014-12-09 | Baker Hughes Incorporated | Expandable seal with conforming ribs |
US9139928B2 (en) | 2011-06-17 | 2015-09-22 | Baker Hughes Incorporated | Corrodible downhole article and method of removing the article from downhole environment |
EP2538018A1 (en) | 2011-06-23 | 2012-12-26 | Welltec A/S | An annular barrier with external seal |
US9120898B2 (en) | 2011-07-08 | 2015-09-01 | Baker Hughes Incorporated | Method of curing thermoplastic polymer for shape memory material |
US9707739B2 (en) | 2011-07-22 | 2017-07-18 | Baker Hughes Incorporated | Intermetallic metallic composite, method of manufacture thereof and articles comprising the same |
US9833838B2 (en) | 2011-07-29 | 2017-12-05 | Baker Hughes, A Ge Company, Llc | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9643250B2 (en) | 2011-07-29 | 2017-05-09 | Baker Hughes Incorporated | Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle |
US9057242B2 (en) | 2011-08-05 | 2015-06-16 | Baker Hughes Incorporated | Method of controlling corrosion rate in downhole article, and downhole article having controlled corrosion rate |
US9033055B2 (en) | 2011-08-17 | 2015-05-19 | Baker Hughes Incorporated | Selectively degradable passage restriction and method |
US9090956B2 (en) | 2011-08-30 | 2015-07-28 | Baker Hughes Incorporated | Aluminum alloy powder metal compact |
US9856547B2 (en) | 2011-08-30 | 2018-01-02 | Bakers Hughes, A Ge Company, Llc | Nanostructured powder metal compact |
US9109269B2 (en) | 2011-08-30 | 2015-08-18 | Baker Hughes Incorporated | Magnesium alloy powder metal compact |
US9643144B2 (en) | 2011-09-02 | 2017-05-09 | Baker Hughes Incorporated | Method to generate and disperse nanostructures in a composite material |
US9347119B2 (en) | 2011-09-03 | 2016-05-24 | Baker Hughes Incorporated | Degradable high shock impedance material |
US9133695B2 (en) | 2011-09-03 | 2015-09-15 | Baker Hughes Incorporated | Degradable shaped charge and perforating gun system |
US8596370B2 (en) | 2011-09-07 | 2013-12-03 | Baker Hughes Incorporated | Annular seal for expanded pipe with one way flow feature |
US8939222B2 (en) | 2011-09-12 | 2015-01-27 | Baker Hughes Incorporated | Shaped memory polyphenylene sulfide (PPS) for downhole packer applications |
DK2570588T3 (en) | 2011-09-13 | 2015-06-29 | Welltec As | An annular barrier with aksialkraftmekanisme |
US9470059B2 (en) | 2011-09-20 | 2016-10-18 | Saudi Arabian Oil Company | Bottom hole assembly for deploying an expandable liner in a wellbore |
WO2013043477A2 (en) | 2011-09-20 | 2013-03-28 | Saudi Arabian Oil Company | Through tubing pumping system with automatically deployable and retractable seal |
WO2013043489A2 (en) | 2011-09-20 | 2013-03-28 | Saudi Arabian Oil Company | Permeable lost circulation drilling liner |
US8829119B2 (en) | 2011-09-27 | 2014-09-09 | Baker Hughes Incorporated | Polyarylene compositions for downhole applications, methods of manufacture, and uses thereof |
US9593559B2 (en) | 2011-10-12 | 2017-03-14 | Exxonmobil Upstream Research Company | Fluid filtering device for a wellbore and method for completing a wellbore |
EP2599956A1 (en) * | 2011-11-30 | 2013-06-05 | Welltec A/S | Annular barrier system with flow lines |
DK2607614T3 (en) * | 2011-12-21 | 2015-02-02 | Welltec As | Annular barrier with an expansion detection device |
US9144925B2 (en) | 2012-01-04 | 2015-09-29 | Baker Hughes Incorporated | Shape memory polyphenylene sulfide manufacturing, process, and composition |
US9010416B2 (en) | 2012-01-25 | 2015-04-21 | Baker Hughes Incorporated | Tubular anchoring system and a seat for use in the same |
US20130199798A1 (en) * | 2012-02-03 | 2013-08-08 | Baker Hughes Incorporated | Temporary protective cover for operative devices |
US9068428B2 (en) | 2012-02-13 | 2015-06-30 | Baker Hughes Incorporated | Selectively corrodible downhole article and method of use |
US9169724B2 (en) | 2012-02-23 | 2015-10-27 | Halliburton Energy Services, Inc. | Expandable conical tubing run through production tubing and into open hole |
EP2644819A1 (en) * | 2012-03-30 | 2013-10-02 | Welltec A/S | An annular barrier having expansion tubes |
EP2644821A1 (en) * | 2012-03-30 | 2013-10-02 | Welltec A/S | An annular barrier having a flexible connection |
EP2644820A1 (en) * | 2012-03-30 | 2013-10-02 | Welltec A/S | An annular barrier with a seal |
US9297228B2 (en) | 2012-04-03 | 2016-03-29 | Halliburton Energy Services, Inc. | Shock attenuator for gun system |
US9243468B2 (en) | 2012-04-17 | 2016-01-26 | Baker Hughes Incorporated | Expandable annular isolator |
US9260926B2 (en) | 2012-05-03 | 2016-02-16 | Weatherford Technology Holdings, Llc | Seal stem |
US9605508B2 (en) | 2012-05-08 | 2017-03-28 | Baker Hughes Incorporated | Disintegrable and conformable metallic seal, and method of making the same |
US20130309011A1 (en) * | 2012-05-15 | 2013-11-21 | Steven Glodack | Absorbent bag for building temporary barriers |
US8839874B2 (en) | 2012-05-15 | 2014-09-23 | Baker Hughes Incorporated | Packing element backup system |
WO2013191679A1 (en) * | 2012-06-19 | 2013-12-27 | Halliburton Energy Services, Inc. | Systems and methods of supporting a multilateral window |
AU2012386229B2 (en) * | 2012-07-25 | 2017-03-23 | Weatherford Technology Holdings, Llc | Flow restrictor |
BR122020007412B1 (en) * | 2012-08-28 | 2021-05-04 | Halliburton Energy Services, Inc | METHOD FOR COMPLETING A WELL, AND, WELL HOLE PIPING CONNECTION |
US8978749B2 (en) | 2012-09-19 | 2015-03-17 | Halliburton Energy Services, Inc. | Perforation gun string energy propagation management with tuned mass damper |
WO2014046656A1 (en) | 2012-09-19 | 2014-03-27 | Halliburton Energy Services, Inc. | Perforation gun string energy propagation management system and methods |
MY191882A (en) * | 2012-10-01 | 2022-07-18 | Halliburton Energy Services Inc | Well tools having energized seals |
WO2014055077A1 (en) * | 2012-10-04 | 2014-04-10 | Halliburton Energy Services, Inc. | Sliding sleeve well tool with metal-to-metal seal |
US20140110118A1 (en) * | 2012-10-24 | 2014-04-24 | Geosierra Llc | Inclusion propagation by casing expansion giving rise to formation dilation and extension |
WO2014065962A1 (en) | 2012-10-26 | 2014-05-01 | Exxonmobil Upstream Research Company | Wellbore apparatus and method for sand control using gravel reserve |
US9341044B2 (en) * | 2012-11-13 | 2016-05-17 | Baker Hughes Incorporated | Self-energized seal or centralizer and associated setting and retraction mechanism |
US10138707B2 (en) | 2012-11-13 | 2018-11-27 | Exxonmobil Upstream Research Company | Method for remediating a screen-out during well completion |
US9322239B2 (en) | 2012-11-13 | 2016-04-26 | Exxonmobil Upstream Research Company | Drag enhancing structures for downhole operations, and systems and methods including the same |
WO2014084868A1 (en) | 2012-12-01 | 2014-06-05 | Halliburton Energy Services, Inc. | Protection of electronic devices used with perforating guns |
US9707642B2 (en) | 2012-12-07 | 2017-07-18 | Baker Hughes Incorporated | Toughened solder for downhole applications, methods of manufacture thereof and articles comprising the same |
US9243490B2 (en) | 2012-12-19 | 2016-01-26 | Baker Hughes Incorporated | Electronically set and retrievable isolation devices for wellbores and methods thereof |
US9382781B2 (en) * | 2012-12-19 | 2016-07-05 | Baker Hughes Incorporated | Completion system for accomodating larger screen assemblies |
US9540906B2 (en) * | 2013-01-14 | 2017-01-10 | Halliburton Energy Services, Inc. | Remote-open inflow control device with swellable actuator |
US9273526B2 (en) | 2013-01-16 | 2016-03-01 | Baker Hughes Incorporated | Downhole anchoring systems and methods of using same |
WO2014149396A2 (en) | 2013-03-15 | 2014-09-25 | Exxonmobil Upstream Research Company | Apparatus and methods for well control |
US9725989B2 (en) | 2013-03-15 | 2017-08-08 | Exxonmobil Upstream Research Company | Sand control screen having improved reliability |
US9796877B2 (en) * | 2013-03-25 | 2017-10-24 | Shell Oil Company | Coating composition and method |
US9540899B1 (en) * | 2013-05-20 | 2017-01-10 | Baker Hughes Incorporated | Downhole seal apparatus and method thereof |
US20140360613A1 (en) * | 2013-06-07 | 2014-12-11 | Baker Hughes Incorporated | Instrumentation line protection and securement system |
US9970269B2 (en) * | 2013-06-28 | 2018-05-15 | Halliburton Energy Services, Inc. | Expandable well screen having enhanced drainage characteristics when expanded |
GB2535865B (en) | 2013-07-24 | 2020-03-18 | Bp Corp North America Inc | Centralizers for centralizing well casings |
US9637997B2 (en) | 2013-08-29 | 2017-05-02 | Weatherford Technology Holdings, Llc | Packer having swellable and compressible elements |
US9816339B2 (en) | 2013-09-03 | 2017-11-14 | Baker Hughes, A Ge Company, Llc | Plug reception assembly and method of reducing restriction in a borehole |
GB201315957D0 (en) * | 2013-09-06 | 2013-10-23 | Swellfix Bv | Retrievable packer |
CN104563954B (en) * | 2013-10-27 | 2017-03-08 | 中国石油化工集团公司 | Steel pipe recovers expansion type external pipe packer |
FR3016389B1 (en) | 2014-01-10 | 2016-01-08 | Saltel Ind | ISOLATION DEVICE FOR WELLS |
US9611700B2 (en) | 2014-02-11 | 2017-04-04 | Saudi Arabian Oil Company | Downhole self-isolating wellbore drilling systems |
CN104847299A (en) * | 2014-02-15 | 2015-08-19 | 陕西思锐机电科技有限公司 | Novel composite expanding packer rubber cylinder |
US10150713B2 (en) | 2014-02-21 | 2018-12-11 | Terves, Inc. | Fluid activated disintegrating metal system |
US11167343B2 (en) | 2014-02-21 | 2021-11-09 | Terves, Llc | Galvanically-active in situ formed particles for controlled rate dissolving tools |
US10865465B2 (en) | 2017-07-27 | 2020-12-15 | Terves, Llc | Degradable metal matrix composite |
US9810365B2 (en) * | 2014-02-24 | 2017-11-07 | Saudi Arabian Oil Company | Variable speed pipeline pig with internal flow cavity |
US9447653B1 (en) | 2014-03-16 | 2016-09-20 | Elie Robert Abi Aad | Inflatable packer |
US9670756B2 (en) | 2014-04-08 | 2017-06-06 | Exxonmobil Upstream Research Company | Wellbore apparatus and method for sand control using gravel reserve |
EP2947259A1 (en) * | 2014-05-19 | 2015-11-25 | Welltec A/S | Downhole string for drilling through a low pressure zone |
GB2526354A (en) * | 2014-05-22 | 2015-11-25 | Meta Downhole Ltd | Improved isolation barrier |
US9551216B2 (en) * | 2014-05-23 | 2017-01-24 | Baker Hughes Incorporated | Packer element with laminar fluid entry |
US9605509B2 (en) * | 2014-05-30 | 2017-03-28 | Baker Hughes Incorporated | Removable treating plug with run in protected agglomerated granular sealing element |
EP2952672A1 (en) * | 2014-06-04 | 2015-12-09 | Welltec A/S | Downhole expandable metal tubular |
FR3023579B1 (en) * | 2014-07-11 | 2016-08-19 | Saltel Ind | EXPANSIBLE TUBULAR ELEMENT HAVING ONE OR MORE INFLATABLE SEAL SEALS |
CN104314508B (en) * | 2014-08-19 | 2018-04-20 | 淮阴工学院 | A kind of method for sealing for the drilling of coal-bed gas pump drainage |
WO2016028414A1 (en) | 2014-08-21 | 2016-02-25 | Exxonmobil Upstream Research Company | Bidirectional flow control device for facilitating stimulation treatments in a subterranean formation |
CA2958232C (en) * | 2014-09-19 | 2019-01-08 | Halliburton Energy Services, Inc. | Expandable radius isolation tool |
US9951596B2 (en) | 2014-10-16 | 2018-04-24 | Exxonmobil Uptream Research Company | Sliding sleeve for stimulating a horizontal wellbore, and method for completing a wellbore |
US9810037B2 (en) | 2014-10-29 | 2017-11-07 | Weatherford Technology Holdings, Llc | Shear thickening fluid controlled tool |
EP3020912A1 (en) * | 2014-11-12 | 2016-05-18 | Welltec A/S | Annular barrier with closing mechanism |
US10584564B2 (en) * | 2014-11-17 | 2020-03-10 | Terves, Llc | In situ expandable tubulars |
US9910026B2 (en) | 2015-01-21 | 2018-03-06 | Baker Hughes, A Ge Company, Llc | High temperature tracers for downhole detection of produced water |
BR112017015592B1 (en) * | 2015-02-17 | 2022-08-23 | Halliburton Energy Services, Inc. | BOTTOM TOOL AND METHOD FOR OPERATING A WELL |
US10378303B2 (en) | 2015-03-05 | 2019-08-13 | Baker Hughes, A Ge Company, Llc | Downhole tool and method of forming the same |
US10060229B2 (en) | 2015-03-31 | 2018-08-28 | Baker Hughes, A Ge Company, Llc | Swelling sleeve method to prevent gravel pack movement into voids adjacent screen connections and exposing screen portions |
US10180038B2 (en) | 2015-05-06 | 2019-01-15 | Weatherford Technology Holdings, Llc | Force transferring member for use in a tool |
MY189438A (en) * | 2015-05-26 | 2022-02-12 | Welltec Oilfield Solutions Ag | Annular barrier having a downhole expandable tubular |
US10655425B2 (en) * | 2015-07-01 | 2020-05-19 | Shell Oil Company | Method and system for sealing an annulur space around an expanded well tubular |
MX2018000172A (en) | 2015-07-09 | 2018-03-26 | Halliburton Energy Services Inc | Wellbore plug sealing assembly. |
US10221637B2 (en) | 2015-08-11 | 2019-03-05 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing dissolvable tools via liquid-solid state molding |
US20180245420A1 (en) * | 2015-09-22 | 2018-08-30 | Halliburton Energy Services, Inc. | Packer element protection from incompatible fluids |
CN108291378A (en) * | 2015-11-26 | 2018-07-17 | 埃雷兹·多尔 | The system and method that underground for antiseepage thin slice is laid |
US10107065B2 (en) * | 2015-12-04 | 2018-10-23 | Baker Hughes, A Ge Company, Llc | Through-tubing deployed annular isolation device and method |
US10016810B2 (en) | 2015-12-14 | 2018-07-10 | Baker Hughes, A Ge Company, Llc | Methods of manufacturing degradable tools using a galvanic carrier and tools manufactured thereof |
JP6620286B2 (en) * | 2015-12-15 | 2019-12-18 | 帝石削井工業株式会社 | Packer |
SG11201804097VA (en) * | 2015-12-31 | 2018-06-28 | Halliburton Energy Services Inc | Downhole tool with alterable structural component |
CN106401564B (en) * | 2016-06-07 | 2023-08-08 | 华北科技学院 | Measuring device for drilling while drilling quick sealing coal seam |
MY192458A (en) * | 2016-09-20 | 2022-08-22 | Halliburton Energy Services Inc | High expansion metal back-up ring for packers and bridge plugs |
US10145217B2 (en) | 2016-10-03 | 2018-12-04 | Saudi Arabian Oil Company | Chemical attenuator sleeve |
EP3592714A1 (en) * | 2017-03-07 | 2020-01-15 | Saudi Arabian Oil Company | Method of encapsulating signaling agents for use downhole |
DE102017003778B4 (en) | 2017-04-19 | 2021-11-11 | Andreas Simon | Exhaust filters for automobiles |
US10260295B2 (en) | 2017-05-26 | 2019-04-16 | Saudi Arabian Oil Company | Mitigating drilling circulation loss |
US10260310B2 (en) * | 2017-07-10 | 2019-04-16 | Baker Hughes, A Ge Company, Llc | High temperature and pressure packer |
CN107246249B (en) * | 2017-08-07 | 2023-05-26 | 南充西南石油大学设计研究院有限责任公司 | Cage type well drilling plugging device and well drilling plugging method |
CN111094810B (en) | 2017-11-13 | 2022-06-07 | 哈利伯顿能源服务公司 | Expandable metal for nonelastomeric O-rings, seal stacks, and gaskets |
WO2019103777A1 (en) | 2017-11-22 | 2019-05-31 | Exxonmobil Upstream Research Company | Perforation devices including trajectory-altering structures and methods of utilizing the same |
US10662745B2 (en) | 2017-11-22 | 2020-05-26 | Exxonmobil Upstream Research Company | Perforation devices including gas supply structures and methods of utilizing the same |
AU2018409809B2 (en) | 2018-02-23 | 2023-09-07 | Halliburton Energy Services, Inc. | Swellable metal for swell packer |
GB2572218A (en) * | 2018-03-23 | 2019-09-25 | Equinor Energy As | Wellbore drilling tool |
CN108505965B (en) * | 2018-03-23 | 2020-10-09 | 中煤科工集团西安研究院有限公司 | Pressing and deblocking type hydraulic expansion packer and deblocking method |
EP3807492B1 (en) | 2018-06-13 | 2021-12-29 | Shell Internationale Research Maatschappij B.V. | Method of preparing a wellbore tubular comprising an elastomer sleeve |
MY197716A (en) * | 2018-09-17 | 2023-07-10 | Halliburton Energy Services Inc | Two part bonded seal for static downhole tool applications |
GB2577341B (en) * | 2018-09-18 | 2021-01-27 | Morphpackers Ltd | Method of manufacturing an assembly for use as an isolation barrier |
EP3647532A1 (en) * | 2018-10-30 | 2020-05-06 | Welltec Oilfield Solutions AG | Annular barrier |
AU2019377506A1 (en) | 2018-11-09 | 2021-05-06 | Halliburton Energy Services, Inc. | Multilateral multistage system and method |
US11111752B2 (en) * | 2018-12-11 | 2021-09-07 | Baker Hughes, A Ge Company, Llc | Water and gas barrier for hydraulic systems |
CN109632497B (en) * | 2018-12-13 | 2022-03-22 | 大港油田集团有限责任公司 | Experimental device and experimental method for expansion of expansion pipe |
US11512561B2 (en) | 2019-02-22 | 2022-11-29 | Halliburton Energy Services, Inc. | Expanding metal sealant for use with multilateral completion systems |
CA3138868C (en) | 2019-07-16 | 2024-03-19 | Halliburton Energy Services, Inc. | Composite expandable metal elements with reinforcement |
MX2021014826A (en) | 2019-07-31 | 2022-01-18 | Halliburton Energy Services Inc | Methods to monitor a metallic sealant deployed in a wellbore, methods to monitor fluid displacement, and downhole metallic sealant measurement systems. |
US10662734B1 (en) * | 2019-09-14 | 2020-05-26 | Vertice Oil Tools | Methods and systems for preventing hydrostatic head within a well |
US10961804B1 (en) * | 2019-10-16 | 2021-03-30 | Halliburton Energy Services, Inc. | Washout prevention element for expandable metal sealing elements |
US11519239B2 (en) | 2019-10-29 | 2022-12-06 | Halliburton Energy Services, Inc. | Running lines through expandable metal sealing elements |
CN110984960B (en) * | 2019-11-19 | 2023-07-18 | 四川省冶勘设计集团有限公司 | Top pressure type layered water pumping and injecting test system and method for same-diameter drilling holes |
US11255160B2 (en) * | 2019-12-09 | 2022-02-22 | Saudi Arabian Oil Company | Unblocking wellbores |
US11761290B2 (en) | 2019-12-18 | 2023-09-19 | Halliburton Energy Services, Inc. | Reactive metal sealing elements for a liner hanger |
US11499399B2 (en) | 2019-12-18 | 2022-11-15 | Halliburton Energy Services, Inc. | Pressure reducing metal elements for liner hangers |
CN113187431A (en) * | 2020-01-14 | 2021-07-30 | 中国石油化工股份有限公司 | Packer |
US11215032B2 (en) | 2020-01-24 | 2022-01-04 | Saudi Arabian Oil Company | Devices and methods to mitigate pressure buildup in an isolated wellbore annulus |
CN113216894A (en) * | 2020-02-06 | 2021-08-06 | 中国石油化工股份有限公司 | High-temperature-resistant expansion packer |
CN113338846B (en) * | 2020-02-18 | 2022-09-23 | 中国石油化工股份有限公司 | Packing type stage cementing device |
US11131158B1 (en) | 2020-07-08 | 2021-09-28 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
US11256273B2 (en) | 2020-07-08 | 2022-02-22 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
US11274501B2 (en) | 2020-07-08 | 2022-03-15 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
US11294401B2 (en) | 2020-07-08 | 2022-04-05 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
US11802645B2 (en) | 2020-07-08 | 2023-10-31 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
US11314266B2 (en) | 2020-07-08 | 2022-04-26 | Saudi Arabian Oil Company | Flow management systems and related methods for oil and gas applications |
CN111908301B (en) * | 2020-07-15 | 2021-03-30 | 中南大学 | Underground ore lifting method |
US11591880B2 (en) | 2020-07-30 | 2023-02-28 | Saudi Arabian Oil Company | Methods for deployment of expandable packers through slim production tubing |
US11761293B2 (en) | 2020-12-14 | 2023-09-19 | Halliburton Energy Services, Inc. | Swellable packer assemblies, downhole packer systems, and methods to seal a wellbore |
US11572749B2 (en) | 2020-12-16 | 2023-02-07 | Halliburton Energy Services, Inc. | Non-expanding liner hanger |
US11725472B2 (en) | 2020-12-23 | 2023-08-15 | Baker Hughes Oilfield Operations Llc | Open tip downhole expansion tool |
US11525343B2 (en) * | 2020-12-23 | 2022-12-13 | Baker Hughes Oilfield Operations Llc | Open tip downhole expansion tool |
US11578498B2 (en) | 2021-04-12 | 2023-02-14 | Halliburton Energy Services, Inc. | Expandable metal for anchoring posts |
US11879304B2 (en) | 2021-05-17 | 2024-01-23 | Halliburton Energy Services, Inc. | Reactive metal for cement assurance |
NO20231340A1 (en) * | 2021-08-31 | 2023-12-12 | Halliburton Energy Services Inc | Controlled actuation of a reactive metal |
US20230069138A1 (en) * | 2021-08-31 | 2023-03-02 | Halliburton Energy Services, Inc. | Controlled actuation of a reactive metal |
CN113847018A (en) * | 2021-09-30 | 2021-12-28 | 于婷婷 | General pilot production tool for packing off earth formation |
US11828132B2 (en) * | 2022-02-28 | 2023-11-28 | Saudi Arabian Oil Company | Inflatable bridge plug |
CN114604476B (en) * | 2022-04-01 | 2022-11-22 | 西南石油大学 | Reversible plugging type irregular sample side wall anti-seepage device |
US20230349258A1 (en) * | 2022-04-29 | 2023-11-02 | Saudi Arabian Oil Company | Protection apparatus on swellable packers to prevent fluid reaction |
CN114870526B (en) * | 2022-05-31 | 2024-04-05 | 华能重庆两江燃机发电有限责任公司 | High-temperature natural gas filter element and manufacturing method and application thereof |
CN117027771B (en) * | 2023-08-28 | 2024-02-09 | 河北省地质矿产勘查开发局第一地质大队(河北省清洁能源应用技术中心) | Geothermal investigation and geothermal temperature measuring device |
Citations (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2646845A (en) * | 1951-08-01 | 1953-07-28 | Zero Hour Bomb Company | Well bridge |
US2738017A (en) * | 1953-08-18 | 1956-03-13 | Oil Recovery Corp | Packer construction for oil well tools |
US3097696A (en) * | 1961-07-27 | 1963-07-16 | Jersey Prod Res Co | Self-expanding retrievable or permanent bridge plug |
US3235017A (en) * | 1962-06-28 | 1966-02-15 | Gen Oil Tools Inc | Earth borehole drilling and testing tool |
US3477506A (en) * | 1968-07-22 | 1969-11-11 | Lynes Inc | Apparatus relating to fabrication and installation of expanded members |
US3784214A (en) * | 1971-10-18 | 1974-01-08 | J Tamplen | Seal that is responsive to either mechanical or pressure force |
US6173788B1 (en) * | 1998-04-07 | 2001-01-16 | Baker Hughes Incorporated | Wellpacker and a method of running an I-wire or control line past a packer |
US6446717B1 (en) * | 2000-06-01 | 2002-09-10 | Weatherford/Lamb, Inc. | Core-containing sealing assembly |
US20020125009A1 (en) * | 2000-08-03 | 2002-09-12 | Wetzel Rodney J. | Intelligent well system and method |
US6457518B1 (en) * | 2000-05-05 | 2002-10-01 | Halliburton Energy Services, Inc. | Expandable well screen |
US6530574B1 (en) * | 2000-10-06 | 2003-03-11 | Gary L. Bailey | Method and apparatus for expansion sealing concentric tubular structures |
Family Cites Families (150)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US266848A (en) | 1882-10-31 | Daniel l | ||
US1336738A (en) | 1920-04-13 | Well-packer | ||
US1842033A (en) | 1930-09-17 | 1932-01-19 | Lewis Albert Van Hook | Oil and gas reclaiming plug |
US1979802A (en) | 1933-05-15 | 1934-11-06 | Zero Hour Torpedo Company | Plugging device |
US2144026A (en) * | 1936-02-06 | 1939-01-17 | Leslie A Layne | Packer |
US2187480A (en) * | 1938-12-12 | 1940-01-16 | Baker Oil Tools Inc | Well cementing apparatus |
US2214226A (en) | 1939-03-29 | 1940-09-10 | English Aaron | Method and apparatus useful in drilling and producing wells |
US2356947A (en) | 1941-04-11 | 1944-08-29 | Guiberson Corp | Packer for pressure drilling head |
US2845130A (en) * | 1952-08-19 | 1958-07-29 | Baker Oil Tools Inc | Apparatus for bridging and cementing well casing |
US2742968A (en) | 1952-12-11 | 1956-04-24 | Exxon Research Engineering Co | Self-inflating balloon type formation tester |
US2812025A (en) | 1955-01-24 | 1957-11-05 | James U Teague | Expansible liner |
US2945541A (en) | 1955-10-17 | 1960-07-19 | Union Oil Co | Well packer |
US2849070A (en) | 1956-04-02 | 1958-08-26 | Union Oil Co | Well packer |
US2986217A (en) * | 1957-08-09 | 1961-05-30 | Camerland Pipelines Inc | Casing packer joint |
US3067819A (en) | 1958-06-02 | 1962-12-11 | George L Gore | Casing interliner |
US3067891A (en) | 1959-11-06 | 1962-12-11 | Crown Cork & Seal Co | Article handling apparatus and system |
US3119451A (en) * | 1961-01-09 | 1964-01-28 | John A Hall | Cement basket |
US3099318A (en) | 1961-01-23 | 1963-07-30 | Montgomery K Miller | Well screening device |
US3203451A (en) | 1962-08-09 | 1965-08-31 | Pan American Petroleum Corp | Corrugated tube for lining wells |
US3272517A (en) | 1963-07-08 | 1966-09-13 | Pan American Petroleum Corp | Casing packer |
US3389752A (en) | 1965-10-23 | 1968-06-25 | Schlumberger Technology Corp | Zone protection |
US3380534A (en) * | 1966-04-25 | 1968-04-30 | Weatherford Oil Tool Company I | Well bore cleaner and cement disperser |
US3385367A (en) * | 1966-12-07 | 1968-05-28 | Kollsman Paul | Sealing device for perforated well casing |
US3575237A (en) | 1969-07-10 | 1971-04-20 | Lynes Inc | Closeoff tool for bores or other openings |
US3581816A (en) | 1970-03-05 | 1971-06-01 | Lynes Inc | Permanent set inflatable element |
US3842912A (en) * | 1973-09-04 | 1974-10-22 | Mwl Tool & Supply Co | Method and apparatus for deep gas well completions |
US3918523A (en) | 1974-07-11 | 1975-11-11 | Ivan L Stuber | Method and means for implanting casing |
US3955625A (en) | 1975-03-06 | 1976-05-11 | The Dow Chemical Company | Cementing basket |
US4137970A (en) * | 1977-04-20 | 1979-02-06 | The Dow Chemical Company | Packer with chemically activated sealing member and method of use thereof |
US4155404A (en) * | 1978-02-22 | 1979-05-22 | Standard Oil Company (Indiana) | Method for tensioning casing in thermal wells |
USRE30711E (en) * | 1978-04-27 | 1981-08-18 | Well completion method and system | |
US4230180A (en) | 1978-11-13 | 1980-10-28 | Westbay Instruments Ltd. | Isolating packer units in geological and geophysical measuring casings |
US4349204A (en) | 1981-04-29 | 1982-09-14 | Lynes, Inc. | Non-extruding inflatable packer assembly |
US4424861A (en) | 1981-10-08 | 1984-01-10 | Halliburton Company | Inflatable anchor element and packer employing same |
US4614346A (en) | 1982-03-12 | 1986-09-30 | The Gates Rubber Company | Inflatable unitary packer element having elastic recovery |
US4528104A (en) * | 1982-08-19 | 1985-07-09 | Nl Industries, Inc. | Oil based packer fluids |
US4440226A (en) * | 1982-12-08 | 1984-04-03 | Suman Jr George O | Well completion method |
US4484626A (en) | 1983-04-15 | 1984-11-27 | K-V Associates, Inc. | Pneumatic packer |
US4498536A (en) | 1983-10-03 | 1985-02-12 | Baker Oil Tools, Inc. | Method of washing, injecting swabbing or flow testing subterranean wells |
US4499947A (en) * | 1983-12-12 | 1985-02-19 | Magyar Szenhidrogenipari Kutatofejleszto Intezet | Packer for separation of zones in a well bore |
US4715442A (en) | 1984-04-11 | 1987-12-29 | Pa Incorporated | Apparatus for servicing tubular strings in subterranean wells |
US4629991A (en) | 1984-04-11 | 1986-12-16 | Pa Incorporated | Methods and apparatus for detecting tubular defects having a plurality of expandable arcuate segments |
US4655286A (en) * | 1985-02-19 | 1987-04-07 | Ctc Corporation | Method for cementing casing or liners in an oil well |
US4651818A (en) | 1986-05-12 | 1987-03-24 | Exxon Production Research Co. | Metal seal tubing plug |
GB2197363B (en) | 1986-11-14 | 1990-09-12 | Univ Waterloo | Packing seal for boreholes |
US4714117A (en) | 1987-04-20 | 1987-12-22 | Atlantic Richfield Company | Drainhole well completion |
FR2626040B1 (en) * | 1988-01-20 | 1993-10-22 | Hutchinson Sa | METHOD FOR ISOLATING BETWEEN WELL PRODUCTION AREAS AND DEVICE FOR CARRYING OUT SAID METHOD |
WO1990005833A1 (en) | 1988-11-22 | 1990-05-31 | Tatarsky Gosudarstvenny Nauchno-Issledovatelsky I Proektny Institut Neftyanoi Promyshlennosti | Device for closing off a complication zone in a well |
US4892144A (en) | 1989-01-26 | 1990-01-09 | Davis-Lynch, Inc. | Inflatable tools |
US4919989A (en) | 1989-04-10 | 1990-04-24 | American Colloid Company | Article for sealing well castings in the earth |
US5027894A (en) * | 1990-05-01 | 1991-07-02 | Davis-Lynch, Inc. | Through the tubing bridge plug |
CA2083156C (en) | 1990-05-18 | 1996-03-19 | Philippe Nobileau | Preform device and processes for coating and/or lining a cylindrical volume |
US5101908A (en) | 1990-08-23 | 1992-04-07 | Baker Hughes Incorporated | Inflatable packing device and method of sealing |
US5095991A (en) | 1990-09-07 | 1992-03-17 | Vetco Gray Inc. | Device for inserting tubular members together |
GB2248255B (en) | 1990-09-27 | 1994-11-16 | Solinst Canada Ltd | Borehole packer |
GB9117683D0 (en) | 1991-08-16 | 1991-10-02 | Head Philip F | Well packer |
US5366012A (en) | 1992-06-09 | 1994-11-22 | Shell Oil Company | Method of completing an uncased section of a borehole |
FR2703102B1 (en) | 1993-03-25 | 1999-04-23 | Drillflex | Method of cementing a deformable casing inside a wellbore or a pipe. |
US5664628A (en) | 1993-05-25 | 1997-09-09 | Pall Corporation | Filter for subterranean wells |
US5392850A (en) | 1994-01-27 | 1995-02-28 | Atlantic Richfield Company | System for isolating multiple gravel packed zones in wells |
US5398998A (en) | 1994-02-04 | 1995-03-21 | Aeroquip Corporation | Pressure actuated fracture device |
US5678635A (en) * | 1994-04-06 | 1997-10-21 | Tiw Corporation | Thru tubing bridge plug and method |
GB9425240D0 (en) * | 1994-12-14 | 1995-02-08 | Head Philip | Dissoluable metal to metal seal |
US5657822A (en) | 1995-05-03 | 1997-08-19 | James; Melvyn C. | Drill hole plugging method utilizing layered sodium bentonite and liquid retaining particles |
FR2737534B1 (en) | 1995-08-04 | 1997-10-24 | Drillflex | DEVICE FOR COVERING A BIFURCATION OF A WELL, ESPECIALLY OIL DRILLING, OR A PIPE, AND METHOD FOR IMPLEMENTING SAID DEVICE |
FR2737533B1 (en) | 1995-08-04 | 1997-10-24 | Drillflex | INFLATABLE TUBULAR SLEEVE FOR TUBING OR CLOSING A WELL OR PIPE |
UA67719C2 (en) | 1995-11-08 | 2004-07-15 | Shell Int Research | Deformable well filter and method for its installation |
US5833001A (en) | 1996-12-13 | 1998-11-10 | Schlumberger Technology Corporation | Sealing well casings |
GB9714651D0 (en) | 1997-07-12 | 1997-09-17 | Petroline Wellsystems Ltd | Downhole tubing |
US5873413A (en) | 1997-08-18 | 1999-02-23 | Halliburton Energy Services, Inc. | Methods of modifying subterranean strata properties |
US6026899A (en) | 1997-09-27 | 2000-02-22 | Pes, Inc. | High expansion slip system |
FR2771133B1 (en) | 1997-11-17 | 2000-02-04 | Drillflex | DEVICE FOR PLACING A FILTERING ENCLOSURE WITHIN A WELL |
WO1999032756A1 (en) * | 1997-12-22 | 1999-07-01 | Specialised Petroleum Services Limited | Apparatus and method for inflating packers in a well |
US6263972B1 (en) | 1998-04-14 | 2001-07-24 | Baker Hughes Incorporated | Coiled tubing screen and method of well completion |
EP0952305A1 (en) | 1998-04-23 | 1999-10-27 | Shell Internationale Researchmaatschappij B.V. | Deformable tube |
US6135208A (en) | 1998-05-28 | 2000-10-24 | Halliburton Energy Services, Inc. | Expandable wellbore junction |
US6619397B2 (en) | 1998-11-03 | 2003-09-16 | Baker Hughes Incorporated | Unconsolidated zonal isolation and control |
US7121352B2 (en) | 1998-11-16 | 2006-10-17 | Enventure Global Technology | Isolation of subterranean zones |
US6745845B2 (en) | 1998-11-16 | 2004-06-08 | Shell Oil Company | Isolation of subterranean zones |
US6634431B2 (en) | 1998-11-16 | 2003-10-21 | Robert Lance Cook | Isolation of subterranean zones |
US6712154B2 (en) | 1998-11-16 | 2004-03-30 | Enventure Global Technology | Isolation of subterranean zones |
GB2343691B (en) | 1998-11-16 | 2003-05-07 | Shell Int Research | Isolation of subterranean zones |
US7357188B1 (en) | 1998-12-07 | 2008-04-15 | Shell Oil Company | Mono-diameter wellbore casing |
GB2344606B (en) | 1998-12-07 | 2003-08-13 | Shell Int Research | Forming a wellbore casing by expansion of a tubular member |
US6725919B2 (en) | 1998-12-07 | 2004-04-27 | Shell Oil Company | Forming a wellbore casing while simultaneously drilling a wellbore |
GB2383361A (en) | 1998-12-22 | 2003-06-25 | Weatherford Lamb | A packer/seal produced by plastically deforming a tubular |
EP2273064A1 (en) * | 1998-12-22 | 2011-01-12 | Weatherford/Lamb, Inc. | Procedures and equipment for profiling and jointing of pipes |
NO308911B1 (en) | 1999-02-19 | 2000-11-13 | Norske Stats Oljeselskap | Device for annular isolation in a well |
AU770359B2 (en) | 1999-02-26 | 2004-02-19 | Shell Internationale Research Maatschappij B.V. | Liner hanger |
MXPA01010126A (en) | 1999-04-09 | 2002-04-24 | Shell Int Research | Method for annular sealing. |
DE60044853D1 (en) | 1999-09-06 | 2010-09-30 | E2Tech Ltd | Expanding device in the borehole |
GB9923092D0 (en) | 1999-09-30 | 1999-12-01 | Solinst Canada Ltd | System for introducing granular material into a borehole |
GB9930866D0 (en) * | 1999-12-30 | 2000-02-16 | Reeves Wireline Tech Ltd | Pumping sub for well logging tools |
US6478091B1 (en) | 2000-05-04 | 2002-11-12 | Halliburton Energy Services, Inc. | Expandable liner and associated methods of regulating fluid flow in a well |
US6454001B1 (en) | 2000-05-12 | 2002-09-24 | Halliburton Energy Services, Inc. | Method and apparatus for plugging wells |
US6415509B1 (en) | 2000-05-18 | 2002-07-09 | Halliburton Energy Services, Inc. | Methods of fabricating a thin-wall expandable well screen assembly |
EG22932A (en) | 2000-05-31 | 2002-01-13 | Shell Int Research | Method and system for reducing longitudinal fluid flow around a permeable well tubular |
US7455104B2 (en) * | 2000-06-01 | 2008-11-25 | Schlumberger Technology Corporation | Expandable elements |
RU2191249C2 (en) | 2000-07-03 | 2002-10-20 | Институт горного дела - научно-исследовательское учреждение СО РАН | Packer and method of its locking in well |
US6412565B1 (en) | 2000-07-27 | 2002-07-02 | Halliburton Energy Services, Inc. | Expandable screen jacket and methods of using same |
US6799637B2 (en) | 2000-10-20 | 2004-10-05 | Schlumberger Technology Corporation | Expandable tubing and method |
US6695054B2 (en) | 2001-01-16 | 2004-02-24 | Schlumberger Technology Corporation | Expandable sand screen and methods for use |
US6848510B2 (en) | 2001-01-16 | 2005-02-01 | Schlumberger Technology Corporation | Screen and method having a partial screen wrap |
US6505685B1 (en) * | 2000-08-31 | 2003-01-14 | Halliburton Energy Services, Inc. | Methods and apparatus for creating a downhole buoyant casing chamber |
NO312478B1 (en) | 2000-09-08 | 2002-05-13 | Freyer Rune | Procedure for sealing annulus in oil production |
US6648076B2 (en) | 2000-09-08 | 2003-11-18 | Baker Hughes Incorporated | Gravel pack expanding valve |
AU2001292695B2 (en) | 2000-09-18 | 2006-07-06 | Shell Internationale Research Maatschappij B.V. | Liner hanger with sliding sleeve valve |
US7490676B2 (en) | 2000-10-06 | 2009-02-17 | Philippe Nobileau | Method and system for tubing a borehole in single diameter |
GB2399529A (en) | 2000-10-06 | 2004-09-22 | Obi Corp | Expansion sealing concentric tubular structures |
US6450261B1 (en) | 2000-10-10 | 2002-09-17 | Baker Hughes Incorporated | Flexible swedge |
GB0026063D0 (en) | 2000-10-25 | 2000-12-13 | Weatherford Lamb | Downhole tubing |
US6543545B1 (en) | 2000-10-27 | 2003-04-08 | Halliburton Energy Services, Inc. | Expandable sand control device and specialized completion system and method |
US6725934B2 (en) | 2000-12-21 | 2004-04-27 | Baker Hughes Incorporated | Expandable packer isolation system |
NO314812B1 (en) | 2001-01-10 | 2003-05-26 | Jon Olav Aarhus | Propulsion device for step-movable pipe plug |
US20020088744A1 (en) | 2001-01-11 | 2002-07-11 | Echols Ralph H. | Well screen having a line extending therethrough |
EP1223305B1 (en) | 2001-01-16 | 2008-04-23 | Services Petroliers Schlumberger | Bi-stable expandable device and method for expanding such a device |
US6695067B2 (en) | 2001-01-16 | 2004-02-24 | Schlumberger Technology Corporation | Wellbore isolation technique |
US7228915B2 (en) * | 2001-01-26 | 2007-06-12 | E2Tech Limited | Device and method to seal boreholes |
US6554070B2 (en) | 2001-03-16 | 2003-04-29 | Intevep, S.A. | Composition and method for sealing an annular space between a well bore and a casing |
US6662876B2 (en) | 2001-03-27 | 2003-12-16 | Weatherford/Lamb, Inc. | Method and apparatus for downhole tubular expansion |
US6575251B2 (en) | 2001-06-13 | 2003-06-10 | Schlumberger Technology Corporation | Gravel inflated isolation packer |
GC0000398A (en) * | 2001-07-18 | 2007-03-31 | Shell Int Research | Method of activating a downhole system |
MY135121A (en) | 2001-07-18 | 2008-02-29 | Shell Int Research | Wellbore system with annular seal member |
US6681849B2 (en) | 2001-08-22 | 2004-01-27 | Baker Hughes Incorporated | Downhole packer system utilizing electroactive polymers |
CA2459537C (en) | 2001-09-06 | 2010-12-21 | Enventure Global Technology | System for lining a wellbore casing |
US6719064B2 (en) | 2001-11-13 | 2004-04-13 | Schlumberger Technology Corporation | Expandable completion system and method |
US7661470B2 (en) | 2001-12-20 | 2010-02-16 | Baker Hughes Incorporated | Expandable packer with anchoring feature |
US7051805B2 (en) | 2001-12-20 | 2006-05-30 | Baker Hughes Incorporated | Expandable packer with anchoring feature |
GB0131019D0 (en) | 2001-12-27 | 2002-02-13 | Weatherford Lamb | Bore isolation |
AU2003209251B2 (en) | 2002-01-16 | 2006-10-26 | Weatherford Technology Holdings, Llc | Inflatable packing element |
US6659178B2 (en) | 2002-03-14 | 2003-12-09 | Wzi, Inc. | Apparatus and method for sealing well bores and bore holes |
GB0208004D0 (en) | 2002-04-08 | 2002-05-15 | Diesel Autogas Systems Ltd | Multi-point / sequential diesel LPG system |
US7017669B2 (en) | 2002-05-06 | 2006-03-28 | Weatherford/Lamb, Inc. | Methods and apparatus for expanding tubulars |
US6722433B2 (en) | 2002-06-21 | 2004-04-20 | Halliburton Energy Services, Inc. | Methods of sealing expandable pipe in well bores and sealing compositions |
US7128145B2 (en) | 2002-08-19 | 2006-10-31 | Baker Hughes Incorporated | High expansion sealing device with leak path closures |
US7644773B2 (en) | 2002-08-23 | 2010-01-12 | Baker Hughes Incorporated | Self-conforming screen |
US6769484B2 (en) | 2002-09-03 | 2004-08-03 | Jeffrey Longmore | Downhole expandable bore liner-filter |
US6935432B2 (en) * | 2002-09-20 | 2005-08-30 | Halliburton Energy Services, Inc. | Method and apparatus for forming an annular barrier in a wellbore |
US7828068B2 (en) | 2002-09-23 | 2010-11-09 | Halliburton Energy Services, Inc. | System and method for thermal change compensation in an annular isolator |
US7152687B2 (en) | 2003-11-06 | 2006-12-26 | Halliburton Energy Services, Inc. | Expandable tubular with port valve |
US6854522B2 (en) | 2002-09-23 | 2005-02-15 | Halliburton Energy Services, Inc. | Annular isolators for expandable tubulars in wellbores |
US6834725B2 (en) | 2002-12-12 | 2004-12-28 | Weatherford/Lamb, Inc. | Reinforced swelling elastomer seal element on expandable tubular |
US6907937B2 (en) | 2002-12-23 | 2005-06-21 | Weatherford/Lamb, Inc. | Expandable sealing apparatus |
US6848505B2 (en) | 2003-01-29 | 2005-02-01 | Baker Hughes Incorporated | Alternative method to cementing casing and liners |
GB0303152D0 (en) | 2003-02-12 | 2003-03-19 | Weatherford Lamb | Seal |
GB0303422D0 (en) | 2003-02-13 | 2003-03-19 | Read Well Services Ltd | Apparatus and method |
GB2398582A (en) | 2003-02-20 | 2004-08-25 | Schlumberger Holdings | System and method for maintaining zonal isolation in a wellbore |
GB0315144D0 (en) | 2003-06-28 | 2003-08-06 | Weatherford Lamb | Centraliser |
US7234533B2 (en) | 2003-10-03 | 2007-06-26 | Schlumberger Technology Corporation | Well packer having an energized sealing element and associated method |
WO2005088064A1 (en) | 2004-02-13 | 2005-09-22 | Halliburton Energy Services Inc. | Annular isolators for tubulars in wellbores |
-
2002
- 2002-09-23 US US10/252,621 patent/US6854522B2/en not_active Ceased
-
2003
- 2003-09-18 CN CNA038225948A patent/CN1708631A/en active Pending
- 2003-09-18 WO PCT/US2003/029566 patent/WO2004027201A2/en not_active Application Discontinuation
- 2003-09-18 EP EP03752507A patent/EP1552105A4/en not_active Withdrawn
- 2003-09-18 BR BRPI0314637-5A patent/BR0314637B1/en not_active IP Right Cessation
- 2003-09-18 AU AU2003270795A patent/AU2003270795A1/en not_active Abandoned
-
2004
- 2004-02-13 US US10/778,465 patent/US7216706B2/en not_active Expired - Lifetime
- 2004-02-13 GB GB0905141A patent/GB2456082B/en not_active Expired - Fee Related
- 2004-02-13 GB GB0905142A patent/GB2456083B/en not_active Expired - Fee Related
- 2004-11-05 US US10/981,822 patent/US7252142B2/en not_active Expired - Fee Related
-
2005
- 2005-03-10 NO NO20051246A patent/NO20051246L/en not_active Application Discontinuation
-
2007
- 2007-01-19 US US11/624,753 patent/US7264047B2/en not_active Expired - Fee Related
- 2007-01-19 US US11/624,751 patent/US20070114018A1/en not_active Abandoned
- 2007-01-19 US US11/624,757 patent/US7320367B2/en not_active Expired - Fee Related
- 2007-01-19 US US11/624,747 patent/US7299882B2/en not_active Expired - Fee Related
- 2007-01-19 US US11/624,759 patent/US7363986B2/en not_active Expired - Fee Related
- 2007-08-03 US US11/833,309 patent/US7404437B2/en not_active Expired - Fee Related
- 2007-10-30 US US11/928,732 patent/USRE41118E1/en not_active Expired - Fee Related
-
2008
- 2008-06-25 US US12/146,401 patent/US20080251250A1/en not_active Abandoned
Patent Citations (11)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US2646845A (en) * | 1951-08-01 | 1953-07-28 | Zero Hour Bomb Company | Well bridge |
US2738017A (en) * | 1953-08-18 | 1956-03-13 | Oil Recovery Corp | Packer construction for oil well tools |
US3097696A (en) * | 1961-07-27 | 1963-07-16 | Jersey Prod Res Co | Self-expanding retrievable or permanent bridge plug |
US3235017A (en) * | 1962-06-28 | 1966-02-15 | Gen Oil Tools Inc | Earth borehole drilling and testing tool |
US3477506A (en) * | 1968-07-22 | 1969-11-11 | Lynes Inc | Apparatus relating to fabrication and installation of expanded members |
US3784214A (en) * | 1971-10-18 | 1974-01-08 | J Tamplen | Seal that is responsive to either mechanical or pressure force |
US6173788B1 (en) * | 1998-04-07 | 2001-01-16 | Baker Hughes Incorporated | Wellpacker and a method of running an I-wire or control line past a packer |
US6457518B1 (en) * | 2000-05-05 | 2002-10-01 | Halliburton Energy Services, Inc. | Expandable well screen |
US6446717B1 (en) * | 2000-06-01 | 2002-09-10 | Weatherford/Lamb, Inc. | Core-containing sealing assembly |
US20020125009A1 (en) * | 2000-08-03 | 2002-09-12 | Wetzel Rodney J. | Intelligent well system and method |
US6530574B1 (en) * | 2000-10-06 | 2003-03-11 | Gary L. Bailey | Method and apparatus for expansion sealing concentric tubular structures |
Non-Patent Citations (1)
Title |
---|
See also references of EP1552105A2 * |
Cited By (9)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7886831B2 (en) | 2003-01-22 | 2011-02-15 | Enventure Global Technology, L.L.C. | Apparatus for radially expanding and plastically deforming a tubular member |
US7793721B2 (en) | 2003-03-11 | 2010-09-14 | Eventure Global Technology, Llc | Apparatus for radially expanding and plastically deforming a tubular member |
GB2418692A (en) * | 2003-05-30 | 2006-04-05 | Baker Hughes Inc | Expansion set packer |
GB2418692B (en) * | 2003-05-30 | 2007-04-04 | Baker Hughes Inc | Expansion set packer |
GB2432383A (en) * | 2003-09-05 | 2007-05-23 | Enventure Global Technology | Radial expansion of a tubular patch to repair a tubular assembly |
US7712522B2 (en) | 2003-09-05 | 2010-05-11 | Enventure Global Technology, Llc | Expansion cone and system |
US7819185B2 (en) | 2004-08-13 | 2010-10-26 | Enventure Global Technology, Llc | Expandable tubular |
NO338447B1 (en) * | 2015-01-19 | 2016-08-15 | Archer Oiltools As | A casing annulus cement foundation system and a method for forming a flange collar constituting a cement foundation |
US9784071B2 (en) | 2015-01-19 | 2017-10-10 | Archer Oiltools As | Casing annulus cement foundation system and a method for forming a flange collar constituting a cement foundation |
Also Published As
Similar Documents
Publication | Publication Date | Title |
---|---|---|
US6854522B2 (en) | Annular isolators for expandable tubulars in wellbores | |
US10458199B2 (en) | Sealing an undesirable formation zone in the wall of a wellbore | |
EP2817481B1 (en) | Expandable tubing run through production tubing and into open hole | |
US7392841B2 (en) | Self boosting packing element | |
AU743241B2 (en) | Deformable liner tube | |
US20050098324A1 (en) | Expandable tubular with port valve | |
WO2005088064A1 (en) | Annular isolators for tubulars in wellbores | |
WO2018057361A1 (en) | Sealing an undesirable formation zone in the wall of a wellbore | |
US20090151957A1 (en) | Zonal Isolation of Telescoping Perforation Apparatus with Memory Based Material | |
WO2015017085A1 (en) | Self-setting downhole tool | |
CA2994530C (en) | Packing element having a bonded petal anti-extrusion device | |
EP2305947A2 (en) | Geothermal liner system with packer |
Legal Events
Date | Code | Title | Description |
---|---|---|---|
AK | Designated states |
Kind code of ref document: A2 Designated state(s): AE AG AL AM AT AU AZ BA BB BG BR BY BZ CA CH CN CO CR CU CZ DE DK DM DZ EC EE EG 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 MA MD MG MK MN MW MX MZ NI NO NZ OM PG PH PL PT RO RU SC SD SE SG SK SL SY TJ TM TN TR TT TZ UA UG UZ VC VN YU ZA ZM ZW |
|
AL | Designated countries for regional patents |
Kind code of ref document: A2 Designated state(s): GH GM KE LS MW MZ SD SL SZ TZ UG ZM ZW AM AZ BY KG KZ MD RU TJ TM AT BE BG CH CY CZ DE DK EE ES FI FR GB GR HU IE IT LU MC NL PT RO SE SI SK TR BF BJ CF CG CI CM GA GN GQ GW ML MR NE SN TD TG |
|
121 | Ep: the epo has been informed by wipo that ep was designated in this application | ||
WWE | Wipo information: entry into national phase |
Ref document number: 20038225948 Country of ref document: CN |
|
REEP | Request for entry into the european phase |
Ref document number: 2003752507 Country of ref document: EP |
|
WWE | Wipo information: entry into national phase |
Ref document number: 2003752507 Country of ref document: EP |
|
WWP | Wipo information: published in national office |
Ref document number: 2003752507 Country of ref document: EP |
|
DFPE | Request for preliminary examination filed prior to expiration of 19th month from priority date (pct application filed before 20040101) | ||
NENP | Non-entry into the national phase |
Ref country code: JP |
|
WWW | Wipo information: withdrawn in national office |
Ref document number: JP |