WO2006063986A1 - Method of sealing an annular space in a wellbore - Google Patents
Method of sealing an annular space in a wellbore Download PDFInfo
- Publication number
- WO2006063986A1 WO2006063986A1 PCT/EP2005/056716 EP2005056716W WO2006063986A1 WO 2006063986 A1 WO2006063986 A1 WO 2006063986A1 EP 2005056716 W EP2005056716 W EP 2005056716W WO 2006063986 A1 WO2006063986 A1 WO 2006063986A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- gel
- fluid
- annular space
- wellbore
- tubular element
- Prior art date
Links
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/422—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells specially adapted for sealing expandable pipes, e.g. of the non-hardening type
-
- C—CHEMISTRY; METALLURGY
- C04—CEMENTS; CONCRETE; ARTIFICIAL STONE; CERAMICS; REFRACTORIES
- C04B—LIME, MAGNESIA; SLAG; CEMENTS; COMPOSITIONS THEREOF, e.g. MORTARS, CONCRETE OR LIKE BUILDING MATERIALS; ARTIFICIAL STONE; CERAMICS; REFRACTORIES; TREATMENT OF NATURAL STONE
- C04B26/00—Compositions of mortars, concrete or artificial stone, containing only organic binders, e.g. polymer or resin concrete
- C04B26/02—Macromolecular compounds
- C04B26/04—Macromolecular compounds obtained by reactions only involving carbon-to-carbon unsaturated bonds
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/44—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing organic binders only
-
- 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
-
- 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
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, 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
- E21B33/00—Sealing or packing boreholes or wells
- E21B33/10—Sealing or packing boreholes or wells in the borehole
- E21B33/13—Methods or devices for cementing, for plugging holes, crevices, or the like
- E21B33/14—Methods or devices for cementing, for plugging holes, crevices, or the like for cementing casings into boreholes
-
- 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
-
- 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
Definitions
- the present invention relates to a method of sealing an annular space formed between an expandable tubular element arranged in a wellbore and a wall surrounding the expandable tubular element, whereby a pressure difference occurs between a first location in the annular space and a second location in the annular space axially spaced from the first location.
- Wellbores for the production of hydrocarbon fluid are conventionally provided with one or more casings to provide stability to the wellbore wall, and to provide zonal isolation between different earth formation layers.
- casings are set at different depth, in a nested arrangement whereby the diameter of each (subsequent) casing is smaller than the diameter of the previous casing in order to allow lowering of the casing through the previous casing.
- the annular space between each casing and the wellbore wall is filled with cement to provide annular sealing and to support the casing in the wellbore. In most applications such cement layer provides adequate sealing functionality as long as the annular space is not too narrow.
- a method of sealing an annular space formed between an expandable tubular element arranged in a wellbore and a wall surrounding the expandable tubular element comprising: installing the tubular element in the wellbore; locating a body of fluid in the annular space between said first and second locations, said fluid having a yield strength selected such that said pressure difference is insufficient to induce axial flow of the body of non-hardening fluid in the annular space after radial expansion of the tubular element; and radially expanding the tubular element.
- the fluid can be inserted in the annular space at a relatively low pumping pressure prior to expansion of the tubular element, since the annular space is relatively wide before the expansion process.
- said fluid is a non-hardening fluid, so that any risk of shrinkage of the annular body due to hardening is avoided.
- a suitable fluid for use in the method of the invention is a thixotropic fluid.
- the fluid is selected from a gel, a Bingham Plastic and a Herschel Bulkley fluid.
- suitable gels for use in the method of the invention are:
- Chromium cross-linked Polyacrylamide such as MarasealTM, MarcitTM available from Schlumberger or OFPG. These gels are based on partially hydrolyzed polyacrylamide polymers crosslinked with Cr(III) released via a chrome acetate complex. Upper application temperatures are 124 0 C for Maraseal, and 104 0 C for Marcit. After setting, the gel is able to resist high concentrations of divalent ions.
- Oil based, thermal insulating gels such as disclosed in US 4,258,791 or US 5,607,901 which are environmentally safe, non aqueous, non corrosive and thermally insulating gels, wherein the liquid part includes an ester of animal or vegetable oil.
- Thermoset synthetic gels having a long lifetime at elevated temperature conditions for example RTV Silicone gels such as Dow Corning' s SylgardTM and/or perfluorether silicone gels such as Shin Etsu' s SIFELTM.
- SilJelTM composed of inorganic silicates which solidify in solution to form a permanent gel after a pre- determined set time.
- the solution has a viscosity close to that of water until more than 90% of the set-time has elapsed.
- the set-time is temperature- and pH dependent, and varies between a few minutes and a few hours at temperatures up to 93 0 C, depending on the pH.
- the addition of urea at higher temperatures results in a delayed gelling time due to the buffering capacity of the urea through the formation of ammonia.
- InjectrolTM which is an internally catalyzed silicate system. Three types of InjectrolTM systems are available dependent on the catalyst applied, i.e.
- type G for temperatures between 23-66 0 C
- type IT for temperatures between 49-82 0 C
- type U for temperatures between 82-149 °C.
- the internal catalyst system enables pumping of a low viscosity solution (typically 1.2 mPa.s) into the formation before the material sets to a stiff gel.
- the amount of catalyst and the bottom hole temperature determines the gelling time.
- the gelling time is between a few minutes at 66 0 C and 600 minutes at 23 0 C.
- H2zeroLTTM or H2zeroTM developed by Halliburton includes an acrylamide acrylate co-polymer having a molecular weight of 250.000, with polyethyleneimine as cross-linker. For applications at temperatures below
- ZrOCl2 is used as cross-linker to achieve reduced gelling times.
- PermSeal E+TM or PermSeal 600TM developed by Halliburton, includes an acrylate monomer and a thermally controlled activator. KCl, water and a pH adjuster
- Floperm 700TM developed by Halliburton, includes polyacrylamide and phenol and formaldehyde as cross- linkers. Precursors which form phenol and formaldehyde in-situ by degradation reactions, such as hydroquinone and hexamethylenetetramine, are less toxic. Floperm 700TM can be used at temperatures up to about 175 0 C. The polymer concentration is of the order of 3000-7000.
- HE300TM developed by Halliburton, includes three monomers (acrylamide-based copolymers) . This polymer is recommended for temperatures beyond 100 0 C. Crosslinking is possible with organic components, such as a mixture of phenol and formaldehyde or precursors to phenol and formaldehyde. Resorcinol can be used to accelerate the reaction at lower temperatures, while ferric ions can delay the gelling process.
- the body of gel comprises a plurality of solid particles of large particle size distribution.
- Suitable solid particles to be included in the body of fluid are: malleable particles such as walnut hulls, fibres (organic or inorganic such as Nylon or Poly-ethylene) , hollow ceramic spheres, wood cuttings, and saw dust; - high density particles such as Mn3O4 (MicromaxTM) ,
- Bauxite particles Aluminium micro balls and micro steel balls
- low density particles such as fly ash, low density spheres (e.g. CarbopropTM) , Bentonite, Pozzolanes, expanded Perlite, powdered coal, GilsoniteTM , glas and ceramic micro spheres
- poorly sorted particle systems such as Dense CreteTM, Lite CreteTM, SandabandTM and SilverfoxTM.
- FIG. 1 schematically shows a wellbore provided with an expandable casing and a stream of gel being pumped into the wellbore;
- FIG. 2 schematically shows the wellbore of Fig. 1 after pumping of the stream of gel into the wellbore
- Fig. 3 schematically shows the wellbore of Fig. 1 during radial expansion of the expandable casing
- Fig. 4 schematically shows the wellbore of Fig. 1 after radial expansion of the expandable casing
- Fig. 5 schematically shows a diagram indicating the effect of radial expansion of a tubular element in a wellbore on the sealing functionality of a body of gel in the annular space between the tubular element and the wellbore wall.
- a wellbore 1 formed in an earth formation 2 which includes a reservoir layer 3 containing hydrocarbon fluid, and an overburden layer 4 overlaying the reservoir layer 3.
- the wellbore 1 passes through the overburden layer 4 and extends into the reservoir layer 3.
- An expandable tubular element in the form of casing 6 extends from surface into the wellbore 1 such that the lower end of the casing 6 is arranged a short distance above the bottom 8 of the wellbore 1.
- An annular space 7 is formed between the casing 6 and the wellbore wall.
- a stream of gel 10 is pumped through the casing 6 and into the lower portion of the wellbore 1 using a pump plug 12 located in the casing 6.
- the pump plug 12 separates the stream of gel 10 from a suitable pumping fluid (such as brine) trailing the stream of gel 10 and the pump plug 12.
- the gel has a yield strength selected in accordance with selection criteria discussed hereinafter.
- FIG. 2 there is shown the wellbore 1 after the stream of gel 10 has been fully pumped into the wellbore 1, whereby the pump plug 12 is located at the lower end of the casing 6.
- the gel 10 extends into the annular space 7 thereby forming an annular body of gel 11.
- Fig. 3 there is shown the casing 6 during radial expansion thereof using an expansion cone 14 connected to a pump (not shown) at surface by a pipe string 16.
- the expansion cone 14 is operable between a collapsed state in which the cone 14 has a largest diameter smaller than the inner diameter of the unexpanded casing 6, and an expanded state in which the cone 14 has a largest diameter commensurate with the inner diameter to which the casing 6 is to be expanded.
- the expansion cone is provided with a longitudinal through-passage 18 providing fluid communication between the interior of the casing 6 below the expansion cone 14, and the pipe string 16.
- a packer 20 is provided at the lower end of the casing 6.
- the packer 20 is operable between a collapsed state in which the packer 20 has a largest diameter smaller than the inner diameter of the unexpanded casing 6, and an expanded state in which the packer 20 has a largest diameter commensurate with the inner diameter to which the casing 6 is to be expanded.
- Fig. 4 there is shown the casing 6 after radial expansion thereof, whereby the expansion cone 14 and the plug 20 are removed from the casing 6, and whereby a production tubing 22 extends from surface through the expanded casing 6, and into the lower open- hole portion 13 of the wellbore 1.
- the production tubing 22 is at surface connected to conventional production equipment (not shown) so as to allow produced hydrocarbon fluid to flow from the lower open-hole portion 13 of the wellbore 1 to the production equipment. Further, the production tubing 22 is near its lower end sealed to the casing 6 by a production packer 24.
- the portion of the stream of gel 10 located in the lower open-hole portion 13 of the wellbore lhas been removed from the wellbore 1.
- the casing 6 is lowered into the wellbore and suspended in the wellbore 1 from surface at the required depth.
- the annular space 7 is filled with brine (not shown) .
- the stream of gel 10 is pumped via the casing 6 into the wellbore 1 by means of the pump plug 12 which trails the stream of gel 10 in the casing (Figs. 1 and 2) .
- the stream of gel 10 flows into the annular space 7 thereby gradually displacing the brine present in the annular space 7.
- the expansion cone 14 and the packer 20 are brought to their respective collapsed states, and the packer 20 is removably attached to the lower end of the cone 14.
- the combined cone 14 and packer 20 are then lowered through the casing 6 by means of pipe string 16 until the cone 14 extends below the lower end of the casing 6, i.e. in the open-hole portion 13 of the wellbore 1.
- the cone 14 is then brought to its expanded state and pulled into the casing 6 using a force multiplier (not shown) thereby radially expanding a lower end portion of the casing 6.
- the packer 20 is radially expanded so as to be anchored to the inner surface of the casing 6.
- the cone 14 is detached from the packer 20 and brine is pumped via the pipe string 16 and the through-passage 18, into the interior of the casing 6 between the cone 14 and the packer 20.
- the cone 14 thereby moves upwardly through the casing 6 and gradually expands the casing 6 (Fig. 3) .
- the annular body of gel 11 moves upwardly. Upward movement of the annular body of gel 11 stops when the expansion cone 14 arrives at a level where no gel is present anymore in the annular space 7. In the Figures, such level is indicated by dotted line A.
- the cone 14 and the packer 20 are removed from the casing.
- the open-hole portion 13 of the wellbore 1 is then cleaned, and the production tubing 22 and the production packer 24 are installed in conventional manner.
- the annular body of gel 11 seals the annular space 7 and thereby prevents that hydrocarbon fluid flows along the outside of the casing 6 in upward direction.
- the yield strength of the gel is selected such that the axial pressure difference across the body of gel 11 is lower than a minimum axial pressure difference across the body of gel 11 required to induce movement of the body of gel 11.
- a wellbore is drilled to a depth of 2000 m, with a diameter of 0.302 m (11.9 inch) in a lower section of the wellbore.
- the fluid pressure in the earth formation at the depth of 2000 m is 200 bar.
- An expandable casing is installed in the wellbore such that the lower end of the casing is positioned a short distance above the wellbore bottom.
- the outer diameter of the casing in unexpanded state is 0.244 m (9.625 inch) .
- a stream of gel having a yield strength of 1000 Pa (0.01 bar) is pumped into the wellbore in the manner described above such that an annular body of gel of 2.28 m3 is contained in the annular space between the unexpanded casing and the wellbore wall.
- the length of the annular body of gel, before radial expansion of the casing, is 92.08 m.
- the maximum pressure at the lower end of the casing required to pump the gel in the annular space, is 63.74 bar which is well below the fracture pressure of the surrounding rock formation.
- the casing is then radially expanded to an outer diameter of 0.286 m (11.261 inch) .
- the annular space thereby becomes narrower so that the length of the body of gel in the annular space increases to about 304.8 m (1000 ft) .
- the effect of expansion of the casing on the minimum axial pressure required to induce longitudinal movement of the body of gel in the annular space is twofold.
- the resistance of the body of gel to axial movement increases due to a longer contact surface with both the wellbore wall and the casing wall, and secondly the cross-sectional area of the annular body of gel decreases.
- the minimum axial pressure difference across the body of gel required to induce longitudinal movement of the body of gel through the annular space increases from 211 bar before expansion of the casing, to 751 bar after expansion of the casing.
- the axial formation fluid pressure difference across the body of gel is taken to be solely due to the hydrostatic column of formation fluid along the length of the body of gel, which is about 30 bar.
- the actual axial fluid pressure difference across the body of gel is far below the minimum axial fluid pressure difference required to induce longitudinal movement of the body of gel.
- a gel with a lower yield strength could safely be applied if desired or, alternatively, the length of the body of gel in the annular space could be reduced.
- Fig. 5 showing a diagram illustrating the minimum axial pressure difference Pa (bar) required across an annular body of gel having a length of 10 m, to induce longitudinal movement of the body of gel through an annular space of width T (mm) for different magnitudes of the yield strength of the gel whereby: line (a) indicates a gel yield strength of 50 Par- line (b) indicates a gel yield strength of 100 Pa; - line (c) indicates a gel yield strength of 200 Pa; line (d) indicates a gel yield strength of 400 Par- line (e) indicates a gel yield strength of 800 Par- line (f) indicates a gel yield strength of 1600 Pa.
- the magnitude of Pa increases exponentially for T decreasing to near zero.
- the effect of radial expansion of the tubular element is therefore that a gel of relatively low yield strength can be used, or alternatively a relatively short annular body of gel can be used, to achieve an effective seal in the annular space.
- the sealing functionality of the gel is particularly effective if the tubular element is radially expanded to near the wellbore wall, or even locally against the wellbore wall.
- a fluid can be pumped which transforms into a gel some time after being pumped into the wellbore.
- a fluid obtains the desired yield strength and, optionally, the desired thixotropic properties after being inserted in the wellbore.
Abstract
Description
Claims
Priority Applications (7)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EA200701275A EA009321B1 (en) | 2004-12-15 | 2005-12-13 | Method of sealing an annular space in a wellbore |
BRPI0519027-4A BRPI0519027A2 (en) | 2004-12-15 | 2005-12-13 | Method for sealing an annular space formed between an expandable tubular member arranged in a well bore and a wall surrounding the expandable tubular member |
AU2005315670A AU2005315670A1 (en) | 2004-12-15 | 2005-12-13 | Method of sealing an annular space in a wellbore |
CA002588008A CA2588008A1 (en) | 2004-12-15 | 2005-12-13 | Method of sealing an annular space in a wellbore |
US11/793,670 US20080110628A1 (en) | 2004-12-15 | 2005-12-13 | Method of Sealing an Annular Space in a Wellbore |
GB0710204A GB2435176A (en) | 2004-12-15 | 2007-05-29 | Method of sealing an annular space in a wellbore |
NO20073538A NO20073538L (en) | 2004-12-15 | 2007-07-09 | Method for sealing an annular space in a borehole |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EP04257820 | 2004-12-15 | ||
EP04257820.3 | 2004-12-15 |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2006063986A1 true WO2006063986A1 (en) | 2006-06-22 |
Family
ID=34930921
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/EP2005/056716 WO2006063986A1 (en) | 2004-12-15 | 2005-12-13 | Method of sealing an annular space in a wellbore |
Country Status (10)
Country | Link |
---|---|
US (1) | US20080110628A1 (en) |
CN (1) | CN101080549A (en) |
AR (1) | AR052814A1 (en) |
AU (1) | AU2005315670A1 (en) |
BR (1) | BRPI0519027A2 (en) |
CA (1) | CA2588008A1 (en) |
EA (1) | EA009321B1 (en) |
GB (1) | GB2435176A (en) |
NO (1) | NO20073538L (en) |
WO (1) | WO2006063986A1 (en) |
Cited By (1)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2008146017A1 (en) * | 2007-06-01 | 2008-12-04 | Statoilhydro Asa | Method of well cementing |
Families Citing this family (8)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2009071536A1 (en) * | 2007-12-04 | 2009-06-11 | Shell Internationale Research Maatschappij B.V. | Method of radially expanding a tubular element |
AU2010234746A1 (en) * | 2009-03-31 | 2011-09-29 | Shell Internationale Research Maatschappij B.V. | Cement as anchor for expandable tubing |
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 |
US8322423B2 (en) * | 2010-06-14 | 2012-12-04 | Halliburton Energy Services, Inc. | Oil-based grouting composition with an insulating material |
US8875800B2 (en) | 2011-09-02 | 2014-11-04 | Baker Hughes Incorporated | Downhole sealing system using cement activated material and method of downhole sealing |
US9993996B2 (en) * | 2015-06-17 | 2018-06-12 | Deborah Duen Ling Chung | Thixotropic liquid-metal-based fluid and its use in making metal-based structures with or without a mold |
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 |
CN113266303A (en) * | 2021-06-28 | 2021-08-17 | 安东柏林石油科技(北京)有限公司 | Packer, method and well completion structure for improving axial packing effect of continuous packing body along shaft |
Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
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US5667011A (en) * | 1995-01-16 | 1997-09-16 | Shell Oil Company | Method of creating a casing in a borehole |
GB2345308A (en) * | 1998-12-22 | 2000-07-05 | Petroline Wellsystems Ltd | Tubing hanger |
WO2000061915A1 (en) * | 1999-04-09 | 2000-10-19 | Shell Internationale Research Maatschappij B.V. | Method of creating a wellbore in an underground formation |
WO2003042494A1 (en) * | 2001-11-15 | 2003-05-22 | Services Petroliers Schlumberger | Method and apparatus for borehole stabilisation |
US20040149431A1 (en) * | 2001-11-14 | 2004-08-05 | Halliburton Energy Services, Inc. | Method and apparatus for a monodiameter wellbore, monodiameter casing and monobore |
Family Cites Families (7)
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US4258791A (en) * | 1980-01-29 | 1981-03-31 | Nl Industries, Inc. | Thermal insulation method |
JPH0818569B2 (en) * | 1986-09-24 | 1996-02-28 | 豊田工機株式会社 | Steering force control device for power steering device |
BR0111032B1 (en) * | 2000-05-22 | 2009-08-11 | method for placing a seal, plug or fitting in a well. | |
US7040404B2 (en) * | 2001-12-04 | 2006-05-09 | Halliburton Energy Services, Inc. | Methods and compositions for sealing an expandable tubular in a wellbore |
US6939833B2 (en) * | 2002-08-01 | 2005-09-06 | Burts, Iii Boyce Donald | Additive for, treatment fluid for, and method of plugging a tubing/casing annulus in a well bore |
US20040221990A1 (en) * | 2003-05-05 | 2004-11-11 | Heathman James F. | Methods and compositions for compensating for cement hydration volume reduction |
GB2419902B (en) * | 2004-11-09 | 2008-02-13 | Schlumberger Holdings | Method of cementing expandable tubulars |
-
2005
- 2005-12-13 CN CNA2005800428831A patent/CN101080549A/en active Pending
- 2005-12-13 US US11/793,670 patent/US20080110628A1/en not_active Abandoned
- 2005-12-13 WO PCT/EP2005/056716 patent/WO2006063986A1/en active Application Filing
- 2005-12-13 AU AU2005315670A patent/AU2005315670A1/en not_active Abandoned
- 2005-12-13 CA CA002588008A patent/CA2588008A1/en not_active Abandoned
- 2005-12-13 BR BRPI0519027-4A patent/BRPI0519027A2/en not_active IP Right Cessation
- 2005-12-13 EA EA200701275A patent/EA009321B1/en not_active IP Right Cessation
- 2005-12-14 AR ARP050105234A patent/AR052814A1/en unknown
-
2007
- 2007-05-29 GB GB0710204A patent/GB2435176A/en not_active Withdrawn
- 2007-07-09 NO NO20073538A patent/NO20073538L/en not_active Application Discontinuation
Patent Citations (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US5667011A (en) * | 1995-01-16 | 1997-09-16 | Shell Oil Company | Method of creating a casing in a borehole |
GB2345308A (en) * | 1998-12-22 | 2000-07-05 | Petroline Wellsystems Ltd | Tubing hanger |
WO2000061915A1 (en) * | 1999-04-09 | 2000-10-19 | Shell Internationale Research Maatschappij B.V. | Method of creating a wellbore in an underground formation |
US20040149431A1 (en) * | 2001-11-14 | 2004-08-05 | Halliburton Energy Services, Inc. | Method and apparatus for a monodiameter wellbore, monodiameter casing and monobore |
WO2003042494A1 (en) * | 2001-11-15 | 2003-05-22 | Services Petroliers Schlumberger | Method and apparatus for borehole stabilisation |
Cited By (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2008146017A1 (en) * | 2007-06-01 | 2008-12-04 | Statoilhydro Asa | Method of well cementing |
EA017404B1 (en) * | 2007-06-01 | 2012-12-28 | Статойл Аса | Method of well cementing |
Also Published As
Publication number | Publication date |
---|---|
EA200701275A1 (en) | 2007-10-26 |
AR052814A1 (en) | 2007-04-04 |
GB0710204D0 (en) | 2007-07-04 |
CN101080549A (en) | 2007-11-28 |
NO20073538L (en) | 2007-09-14 |
BRPI0519027A2 (en) | 2008-12-23 |
AU2005315670A1 (en) | 2006-06-22 |
US20080110628A1 (en) | 2008-05-15 |
GB2435176A (en) | 2007-08-15 |
CA2588008A1 (en) | 2006-06-22 |
EA009321B1 (en) | 2007-12-28 |
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