WO1999054592A1 - Well treatment for water restriction - Google Patents

Well treatment for water restriction Download PDF

Info

Publication number
WO1999054592A1
WO1999054592A1 PCT/GB1999/001125 GB9901125W WO9954592A1 WO 1999054592 A1 WO1999054592 A1 WO 1999054592A1 GB 9901125 W GB9901125 W GB 9901125W WO 9954592 A1 WO9954592 A1 WO 9954592A1
Authority
WO
WIPO (PCT)
Prior art keywords
water
well
particles
chemical
scale inhibitor
Prior art date
Application number
PCT/GB1999/001125
Other languages
French (fr)
Inventor
Philip John Charles Webb
Original Assignee
Aea Technology Plc
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Aea Technology Plc filed Critical Aea Technology Plc
Priority to AU35293/99A priority Critical patent/AU3529399A/en
Publication of WO1999054592A1 publication Critical patent/WO1999054592A1/en

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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • 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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
    • 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
    • E21B43/25—Methods for stimulating production
    • E21B43/26—Methods for stimulating production by forming crevices or fractures
    • E21B43/267—Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping

Definitions

  • This invention relates to a method for treating an oil or gas well so as to restrict the inflow of water.
  • Oil and gas wells extend through subterranean formations, some of which are fluid permeable and contain oil or gas.
  • the oil or gas-containing formation may also contain water, or in some cases water may be injected into such a formation by a well operator to displace other fluids. Consequently water may flow into the well along with the oil or gas, the proportion of water varying through the formation.
  • a formation is insufficiently permeable it is known to enhance its permeability by subjecting it to a fracturing treatment and injecting proppant particles. This will increase the permeability of the formation to any fluids present.
  • a method of treating an oil or gas well so as to reduce the proportion of water produced by the well comprising subjecting the well to a fracture treatment with proppant particles whose conductivity decreases when they are contacted by water.
  • the proppant particles may be coated on their external surfaces with a water-soluble chemical such as a scale inhibitor.
  • the particles may be either porous or non-porous.
  • the proppant particles might be porous, impregnated with a water- soluble chemical, such that the proppant particles are progressively crushed as the chemical is dissolved.
  • the particles in either case may be of a ceramic material, and are preferably of size in the range 0.3 mm to 5 mm, more preferably between 0.5 mm and 2.0 mm, for example about 0.5 mm or about 1.0 mm. It is usually desirable to have all particles of substantially the same size.
  • the water-soluble chemical may be one which has no appreciable effect on any chemical processes within any well.
  • it may be a chemical which would suppress a deleterious process (such as corrosion or scale formation) , but be used in a well in which that deleterious process is not occurring anyway - i.e. it has no appreciable effect on any chemical processes occurring in that well .
  • the fluid injected into the rocks may contain a dissolved polymer which may be cross-linked to form a gel (so it is of high viscosity) , and contains proppant particles which are carried into the fractures by the injected fluid.
  • the particles prevent the fractures closing.
  • the fractures extend over 20 rn out from the well bore, often in excess of 100 m, and the proppant particles will be distributed throughout the length of every fracture.
  • This embodiment of the invention uses, as the proppant particles, porous alumino-silicate ceramic beads of porosity about 6 percent and of size 16/20 mesh (0.85 - 3 -
  • the beads are coated and impregnated with a scale inhibitor chemical in solid form. This may be done by substantially the same procedure as that described in GB 2 298 440 A, as follows:
  • concentrated aqueous solution of scale inhibitor is made from a commercially-available diethylene-triamine penta- (methylenephosphonic acid) - based scale inhibitor (initially about 25 percent active material), by first adding to this inhibitor 5000 to 25,000 pp cations (calcium and magnesium) added as chlorides, preferably 12,000 to 25,000 ppm, and then distilling under vacuum to about half the initial volume.
  • the pH is adjusted to a value in the range pH 6.0 to pH 11.0 by acting concentrated sodium hydroxide, preferably to pH 10.
  • the ceramic beads are placed in a pressure vessel, and the vessel evacuated to about 0.1 mbar (10 Pa) absolute to ensure that no air or vapours remain in the pores.
  • the vessel is then filled under vacuum with the concentrated inhibitor. After quarter of an hour the vacuum is released, the vessel drained, and the wet beads removed.
  • the wet beads are then dried in an oven or a fluidised bed, so that they contain the scale inhibitor in a solid form.
  • the decrease in fluid conductivity as the scale inhibitor dissolves is the result of two mechanisms. Firstly, the dissolution of the scale inhibitor from the external surface of the beads reduces their diameter, so lowering the conductivity. Secondly, the dissolution of the scale inhibitor from the surface and the pores weakens the beads so they are less able to withstand the closure stress, and they generate fines, which also lowers the fluid conductivity. For example experimental tests at a closure stress of 5000 psi found that the beads containing scale inhibitor generated about 10 percent fines, whereas the beads containing no scale inhibitor generated 28 percent fines.
  • the process of the invention may be performed using beads which differ from those described above.
  • the ceramic beads might be substantially non-porous, with only an external coating of the solid scale inhibitor.
  • the beads might be impregnated and coated with a different scale inhibitor, or indeed with any water-soluble chemical, for example a water-soluble polymer.
  • the size of the beads must be selected so as to ensure the beads are sufficiently strong to withstand the closure stresses in the fracture, and to provide a - 5 -

Abstract

An oil or gas well is treated to reduce the proportion of water produced by the well, by subjecting the well to a fracture treatment with proppant particles whose conductivity decreases when they are contacted by water. The particles may be of a ceramic material, and may be coated on their external surfaces with a water-soluble chemical; if the proppant particles are porous, they may also be impregnated with the water-soluble chemical. When contacted with water the permeability of a bed of such particles decreases, because the particles become slightly smaller and/or weaker. The chemical might be a water-soluble polymer or a scale inhibitor.

Description

- 1 -
Well Treatment for Water Restriction
This invention relates to a method for treating an oil or gas well so as to restrict the inflow of water.
Oil and gas wells extend through subterranean formations, some of which are fluid permeable and contain oil or gas. The oil or gas-containing formation may also contain water, or in some cases water may be injected into such a formation by a well operator to displace other fluids. Consequently water may flow into the well along with the oil or gas, the proportion of water varying through the formation. Where a formation is insufficiently permeable it is known to enhance its permeability by subjecting it to a fracturing treatment and injecting proppant particles. This will increase the permeability of the formation to any fluids present.
According to the present invention there is provided a method of treating an oil or gas well so as to reduce the proportion of water produced by the well, the method comprising subjecting the well to a fracture treatment with proppant particles whose conductivity decreases when they are contacted by water.
The proppant particles may be coated on their external surfaces with a water-soluble chemical such as a scale inhibitor. In this case the particles may be either porous or non-porous. Alternatively the proppant particles might be porous, impregnated with a water- soluble chemical, such that the proppant particles are progressively crushed as the chemical is dissolved. The particles in either case may be of a ceramic material, and are preferably of size in the range 0.3 mm to 5 mm, more preferably between 0.5 mm and 2.0 mm, for example about 0.5 mm or about 1.0 mm. It is usually desirable to have all particles of substantially the same size.
It will be appreciated that the water-soluble chemical may be one which has no appreciable effect on any chemical processes within any well. Alternatively it may be a chemical which would suppress a deleterious process (such as corrosion or scale formation) , but be used in a well in which that deleterious process is not occurring anyway - i.e. it has no appreciable effect on any chemical processes occurring in that well .
The invention will now be further described by way of example only, and with reference to the accompanying drawing, which shows graphically the variation of fracture conductivity with closure stress for two different types of proppant particle.
When it is desired to enhance the permeability of a formation comprising oil-bearing strata in the vicinity of an oil well, it is known to inject fluid into the well such that the pressure at the depth of those strata is sufficient to cause of fracturing of the rocks of the strata. The fluid injected into the rocks may contain a dissolved polymer which may be cross-linked to form a gel (so it is of high viscosity) , and contains proppant particles which are carried into the fractures by the injected fluid. When the pressure is reduced the particles prevent the fractures closing. Typically the fractures extend over 20 rn out from the well bore, often in excess of 100 m, and the proppant particles will be distributed throughout the length of every fracture.
This embodiment of the invention uses, as the proppant particles, porous alumino-silicate ceramic beads of porosity about 6 percent and of size 16/20 mesh (0.85 - 3 -
- 1.2 mm) . The beads are coated and impregnated with a scale inhibitor chemical in solid form. This may be done by substantially the same procedure as that described in GB 2 298 440 A, as follows:
(i) concentrated aqueous solution of scale inhibitor is made from a commercially-available diethylene-triamine penta- (methylenephosphonic acid) - based scale inhibitor (initially about 25 percent active material), by first adding to this inhibitor 5000 to 25,000 pp cations (calcium and magnesium) added as chlorides, preferably 12,000 to 25,000 ppm, and then distilling under vacuum to about half the initial volume. The pH is adjusted to a value in the range pH 6.0 to pH 11.0 by acting concentrated sodium hydroxide, preferably to pH 10.
(ii) the ceramic beads are placed in a pressure vessel, and the vessel evacuated to about 0.1 mbar (10 Pa) absolute to ensure that no air or vapours remain in the pores. The vessel is then filled under vacuum with the concentrated inhibitor. After quarter of an hour the vacuum is released, the vessel drained, and the wet beads removed.
(iii) the wet beads are then dried in an oven or a fluidised bed, so that they contain the scale inhibitor in a solid form.
If such beads are used as proppants then, in those parts of the fracture in which water flows, the permeability will decrease, because the water will dissolve the scale inhibitor from the surface of the beads. This decrease in permeability is illustrated in the figure, to which reference is now made. This shows graphically the fracture conductivity when using such - 4 -
beads containing solid scale inhibitor (graph A) and the fracture conductivity if all the scale inhibitor has dissolved from such beads (graph B) . The fracture conductivity values are given in millidarcy feet (1 md ft
-15 3 = 0.3 x 10 m ) and the closure stresses m psi (1000 psi
= 6.8 MPa) . In both cases the conductivity decreases at higher closure stresses, but for all closure stresses above about 3000 psi the fracture conductivity is noticeably less once the inhibitor has dissolved (graph B) .
The decrease in fluid conductivity as the scale inhibitor dissolves is the result of two mechanisms. Firstly, the dissolution of the scale inhibitor from the external surface of the beads reduces their diameter, so lowering the conductivity. Secondly, the dissolution of the scale inhibitor from the surface and the pores weakens the beads so they are less able to withstand the closure stress, and they generate fines, which also lowers the fluid conductivity. For example experimental tests at a closure stress of 5000 psi found that the beads containing scale inhibitor generated about 10 percent fines, whereas the beads containing no scale inhibitor generated 28 percent fines.
It will be appreciated that the process of the invention may be performed using beads which differ from those described above. For example the ceramic beads might be substantially non-porous, with only an external coating of the solid scale inhibitor. The beads might be impregnated and coated with a different scale inhibitor, or indeed with any water-soluble chemical, for example a water-soluble polymer. It will also be understood that the size of the beads must be selected so as to ensure the beads are sufficiently strong to withstand the closure stresses in the fracture, and to provide a - 5 -
significant contrast in flow capacity between the fracture and the formation.

Claims

Claims
1. A method of treating an oil or gas well so as to reduce the proportion of water produced by the well, the method comprising subjecting the well to a fracture treatment with proppant particles whose conductivity decreases when they are contacted by water.
2. A method as claimed in claim 1 in which the proppant particles are coated on their external surfaces with a water-soluble chemical.
3. A method as claimed in claim 1 or claim 2 in which the proppant particles are porous and are impregnated with a water-soluble chemical.
4. A method as claimed in claim 2 or claim 3 in which the water-soluble chemical is one which has no appreciable effect on any chemical processes within any well.
5. A method as claimed in claim 2 or claim 3 in which the water-soluble chemical is a scale inhibitor.
6. A method as claimed in any one of the preceding claims in which the particles are of a ceramic material, and are of size in the range 0.3 mm to 5 mm, more preferably between 0.5 mm and 2.0 mm, for example about 0.5 mm or about 1.0 mm.
PCT/GB1999/001125 1998-04-22 1999-04-13 Well treatment for water restriction WO1999054592A1 (en)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU35293/99A AU3529399A (en) 1998-04-22 1999-04-13 Well treatment for water restriction

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GBGB9808490.8A GB9808490D0 (en) 1998-04-22 1998-04-22 Well treatment for water restriction
GB9808490.8 1998-04-22

Publications (1)

Publication Number Publication Date
WO1999054592A1 true WO1999054592A1 (en) 1999-10-28

Family

ID=10830725

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB1999/001125 WO1999054592A1 (en) 1998-04-22 1999-04-13 Well treatment for water restriction

Country Status (3)

Country Link
AU (1) AU3529399A (en)
GB (1) GB9808490D0 (en)
WO (1) WO1999054592A1 (en)

Cited By (29)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002040828A1 (en) 2000-11-20 2002-05-23 Statoil Asa Well treatment method
WO2002079608A1 (en) 2001-03-30 2002-10-10 Statoil Asa Method of well treatment
GB2421260A (en) * 2004-12-15 2006-06-21 Bj Services Co Treatment agent adsorbed on water insoluble particles
WO2006129258A1 (en) * 2005-06-02 2006-12-07 Schlumberger Canada Limited Proppants useful for prevention of scale deposition
GB2430453A (en) * 2002-09-03 2007-03-28 Bj Services Co Porous particulate material
WO2007063325A1 (en) * 2005-12-01 2007-06-07 Visible Technology Oil & Gas Limited Particles
WO2007148121A2 (en) 2006-06-23 2007-12-27 Statoilhydro Asa Nucleic acid molecules encoding an enzyme that degrades long-chain n-alkanes
US7426961B2 (en) * 2002-09-03 2008-09-23 Bj Services Company Method of treating subterranean formations with porous particulate materials
US7598209B2 (en) 2006-01-26 2009-10-06 Bj Services Company Porous composites containing hydrocarbon-soluble well treatment agents and methods for using the same
US7964539B2 (en) 2004-06-17 2011-06-21 Statoil Asa Well treatment
WO2011114238A2 (en) 2010-03-18 2011-09-22 Universität Regensburg Shuttle vector based transformation system for pyrococcus furiosus
WO2011149633A2 (en) * 2010-05-24 2011-12-01 Chevron U.S.A. Inc. Methods and systems for treating subterranean wells
US8245778B2 (en) 2007-10-16 2012-08-21 Exxonmobil Upstream Research Company Fluid control apparatus and methods for production and injection wells
US8278087B2 (en) 2006-07-18 2012-10-02 The University of Regensburg Energy production with hyperthermophilic organisms
EP2679688A1 (en) 2008-09-24 2014-01-01 Hyperthermics Holding AS Energy production with hyperthermophilic organisms
US8664168B2 (en) 2011-03-30 2014-03-04 Baker Hughes Incorporated Method of using composites in the treatment of wells
US8863855B2 (en) 2007-06-26 2014-10-21 Statoil Asa Method of enhancing oil recovery
US9010430B2 (en) 2010-07-19 2015-04-21 Baker Hughes Incorporated Method of using shaped compressed pellets in treating a well
US9033040B2 (en) 2011-12-16 2015-05-19 Baker Hughes Incorporated Use of composite of lightweight hollow core having adhered or embedded cement in cementing a well
US9708208B2 (en) 2006-07-18 2017-07-18 Hyperthermics Holding As Energy production with hyperthermophilic organisms
RU2639232C2 (en) * 2011-12-21 2017-12-20 Акцо Нобель Кемикалз Интернэшнл Б.В. Particles containing one or multiple crosslinked active substances with controlled release
US9976070B2 (en) 2010-07-19 2018-05-22 Baker Hughes, A Ge Company, Llc Method of using shaped compressed pellets in well treatment operations
US10400159B2 (en) 2014-07-23 2019-09-03 Baker Hughes, A Ge Company, Llc Composite comprising well treatment agent and/or a tracer adhered onto a calcined substrate of a metal oxide coated core and a method of using the same
US10413966B2 (en) 2016-06-20 2019-09-17 Baker Hughes, A Ge Company, Llc Nanoparticles having magnetic core encapsulated by carbon shell and composites of the same
US10641083B2 (en) 2016-06-02 2020-05-05 Baker Hughes, A Ge Company, Llc Method of monitoring fluid flow from a reservoir using well treatment agents
US10822536B2 (en) 2010-07-19 2020-11-03 Baker Hughes, A Ge Company, Llc Method of using a screen containing a composite for release of well treatment agent into a well
US10961444B1 (en) 2019-11-01 2021-03-30 Baker Hughes Oilfield Operations Llc Method of using coated composites containing delayed release agent in a well treatment operation
US11254861B2 (en) 2017-07-13 2022-02-22 Baker Hughes Holdings Llc Delivery system for oil-soluble well treatment agents and methods of using the same
US11254850B2 (en) 2017-11-03 2022-02-22 Baker Hughes Holdings Llc Treatment methods using aqueous fluids containing oil-soluble treatment agents

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4518039A (en) * 1981-08-20 1985-05-21 Graham John W Method for treating subterranean formations
EP0193369A2 (en) * 1985-02-27 1986-09-03 Exxon Chemical Patents Inc. Polymer article and its use for controlled introduction of reagent into a fluid
US5420174A (en) * 1992-11-02 1995-05-30 Halliburton Company Method of producing coated proppants compatible with oxidizing gel breakers
US5422183A (en) * 1993-06-01 1995-06-06 Santrol, Inc. Composite and reinforced coatings on proppants and particles

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US4518039A (en) * 1981-08-20 1985-05-21 Graham John W Method for treating subterranean formations
EP0193369A2 (en) * 1985-02-27 1986-09-03 Exxon Chemical Patents Inc. Polymer article and its use for controlled introduction of reagent into a fluid
US5420174A (en) * 1992-11-02 1995-05-30 Halliburton Company Method of producing coated proppants compatible with oxidizing gel breakers
US5422183A (en) * 1993-06-01 1995-06-06 Santrol, Inc. Composite and reinforced coatings on proppants and particles

Cited By (42)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2002040828A1 (en) 2000-11-20 2002-05-23 Statoil Asa Well treatment method
WO2002079608A1 (en) 2001-03-30 2002-10-10 Statoil Asa Method of well treatment
US7861780B2 (en) * 2002-09-03 2011-01-04 Baker Hughes Incorporated Method of treating subterranean formations with porous particulate materials
GB2430453B (en) * 2002-09-03 2007-06-20 Bj Services Co Method of treating subterranean formations with porous ceramic particulate materials
US7426961B2 (en) * 2002-09-03 2008-09-23 Bj Services Company Method of treating subterranean formations with porous particulate materials
GB2430453A (en) * 2002-09-03 2007-03-28 Bj Services Co Porous particulate material
US7713918B2 (en) 2002-09-03 2010-05-11 Bj Services Company Porous particulate materials and compositions thereof
US7964539B2 (en) 2004-06-17 2011-06-21 Statoil Asa Well treatment
NO340542B1 (en) * 2004-12-15 2017-05-08 Baker Hughes Inc Methods for stimulating an underground formation and for inhibiting or controlling the rate of release of a well treating agent in an underground formation or wellbore
GB2421260B (en) * 2004-12-15 2009-07-22 Bj Services Co Well treating compositions for slow release of treatment agents and methods of using the same
GB2421260A (en) * 2004-12-15 2006-06-21 Bj Services Co Treatment agent adsorbed on water insoluble particles
US7493955B2 (en) 2004-12-15 2009-02-24 Bj Services Company Well treating compositions for slow release of treatment agents and methods of using the same
US7491682B2 (en) 2004-12-15 2009-02-17 Bj Services Company Method of inhibiting or controlling formation of inorganic scales
WO2006129258A1 (en) * 2005-06-02 2006-12-07 Schlumberger Canada Limited Proppants useful for prevention of scale deposition
GB2440082B (en) * 2005-06-02 2010-11-10 Schlumberger Holdings Proppants useful for prevention of scale deposition
EA011760B1 (en) * 2005-06-02 2009-06-30 Шлюмбергер Текнолоджи Б.В. A proppant useful for prevention of scale deposition
GB2440082A (en) * 2005-06-02 2008-01-16 Schlumberger Holdings Proppants useful for prevention of scale deposition
WO2007063325A1 (en) * 2005-12-01 2007-06-07 Visible Technology Oil & Gas Limited Particles
EA013192B1 (en) * 2005-12-01 2010-02-26 Визибл Текнолоджи Ойл Энд Гэс Лимитед Manufactured particle for use in well or in reservoir
US8735333B2 (en) 2005-12-01 2014-05-27 Ewen Robertson Particles
US7598209B2 (en) 2006-01-26 2009-10-06 Bj Services Company Porous composites containing hydrocarbon-soluble well treatment agents and methods for using the same
WO2007148121A2 (en) 2006-06-23 2007-12-27 Statoilhydro Asa Nucleic acid molecules encoding an enzyme that degrades long-chain n-alkanes
US9708208B2 (en) 2006-07-18 2017-07-18 Hyperthermics Holding As Energy production with hyperthermophilic organisms
US8278087B2 (en) 2006-07-18 2012-10-02 The University of Regensburg Energy production with hyperthermophilic organisms
US8863855B2 (en) 2007-06-26 2014-10-21 Statoil Asa Method of enhancing oil recovery
US8245778B2 (en) 2007-10-16 2012-08-21 Exxonmobil Upstream Research Company Fluid control apparatus and methods for production and injection wells
EP2679688A1 (en) 2008-09-24 2014-01-01 Hyperthermics Holding AS Energy production with hyperthermophilic organisms
WO2011114238A2 (en) 2010-03-18 2011-09-22 Universität Regensburg Shuttle vector based transformation system for pyrococcus furiosus
WO2011149633A3 (en) * 2010-05-24 2012-01-12 Chevron U.S.A. Inc. Methods and systems for treating subterranean wells
WO2011149633A2 (en) * 2010-05-24 2011-12-01 Chevron U.S.A. Inc. Methods and systems for treating subterranean wells
US9976070B2 (en) 2010-07-19 2018-05-22 Baker Hughes, A Ge Company, Llc Method of using shaped compressed pellets in well treatment operations
US9010430B2 (en) 2010-07-19 2015-04-21 Baker Hughes Incorporated Method of using shaped compressed pellets in treating a well
US10822536B2 (en) 2010-07-19 2020-11-03 Baker Hughes, A Ge Company, Llc Method of using a screen containing a composite for release of well treatment agent into a well
US8664168B2 (en) 2011-03-30 2014-03-04 Baker Hughes Incorporated Method of using composites in the treatment of wells
US9033040B2 (en) 2011-12-16 2015-05-19 Baker Hughes Incorporated Use of composite of lightweight hollow core having adhered or embedded cement in cementing a well
RU2639232C2 (en) * 2011-12-21 2017-12-20 Акцо Нобель Кемикалз Интернэшнл Б.В. Particles containing one or multiple crosslinked active substances with controlled release
US10400159B2 (en) 2014-07-23 2019-09-03 Baker Hughes, A Ge Company, Llc Composite comprising well treatment agent and/or a tracer adhered onto a calcined substrate of a metal oxide coated core and a method of using the same
US10641083B2 (en) 2016-06-02 2020-05-05 Baker Hughes, A Ge Company, Llc Method of monitoring fluid flow from a reservoir using well treatment agents
US10413966B2 (en) 2016-06-20 2019-09-17 Baker Hughes, A Ge Company, Llc Nanoparticles having magnetic core encapsulated by carbon shell and composites of the same
US11254861B2 (en) 2017-07-13 2022-02-22 Baker Hughes Holdings Llc Delivery system for oil-soluble well treatment agents and methods of using the same
US11254850B2 (en) 2017-11-03 2022-02-22 Baker Hughes Holdings Llc Treatment methods using aqueous fluids containing oil-soluble treatment agents
US10961444B1 (en) 2019-11-01 2021-03-30 Baker Hughes Oilfield Operations Llc Method of using coated composites containing delayed release agent in a well treatment operation

Also Published As

Publication number Publication date
AU3529399A (en) 1999-11-08
GB9808490D0 (en) 1998-06-17

Similar Documents

Publication Publication Date Title
WO1999054592A1 (en) Well treatment for water restriction
RU2667165C2 (en) Well treatment reagent and/or indicator containing composite material, applied on thermal processed substrate with the core, coated with metal oxide and method of its use
US2094479A (en) Treatment of wells
US5964291A (en) Well treatment
CA2942016C (en) Degradable fluid sealing compositions incorporating non-degradable microparticulates and methods for use thereof
US4852650A (en) Hydraulic fracturing with a refractory proppant combined with salinity control
WO2000075486A1 (en) The use of encapsulated acid in acid fracturing treatments
EP1038090B1 (en) An improvement in placing cement slurry in wells in the presence of geological zones containing swelling clays or mud residues containing clays
MXPA04012322A (en) Methods of consolidating formations or forming chemical casing or both while drilling.
WO2015038153A1 (en) Conductivity enhancenment of complex fracture networks in subterranean formations
CA2801653A1 (en) Far field diversion technique for treating subterranean formation
WO1999036668A1 (en) Well treatment
US10414972B2 (en) Peroxide containing formation conditioning and pressure generating composition and method
US3593798A (en) Method of reducing the permeability of a thief zone
WO2006117510A1 (en) Methods and compositions for enhancing hydrocarbon production
US3729052A (en) Hydrothermal treatment of subsurface earth formations
US3285340A (en) Acidizing propped fractures
WO2018026375A1 (en) Amaranth grain particulates for diversion applications
WO1998040606A1 (en) Well treatment with particles
WO1999036667A1 (en) Well treatment with microorganisms
WO2015134350A1 (en) Methods and compositions for using temporary compacted materials as well servicing fluids in a subterranean formation
RU2209936C2 (en) Method of thermochemical treatment of oil formation
RU2101474C1 (en) Method of developing oil deposit in carbonate reservoirs of fissured type
RU2127803C1 (en) Method for treating oil deposit with non-uniform reservoirs
AU720919B2 (en) Increasing the rate of production of methane from subterranean coal and carbonaceous formations

Legal Events

Date Code Title Description
AK Designated states

Kind code of ref document: A1

Designated state(s): AU BR CA GB MX NO US

AL Designated countries for regional patents

Kind code of ref document: A1

Designated state(s): AT BE CH CY DE DK ES FI FR GB GR IE IT LU MC NL PT SE

121 Ep: the epo has been informed by wipo that ep was designated in this application
122 Ep: pct application non-entry in european phase