WO1999054592A1 - Well treatment for water restriction - Google Patents
Well treatment for water restriction Download PDFInfo
- 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
Links
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 title claims abstract description 16
- 239000002245 particle Substances 0.000 claims abstract description 22
- 239000002455 scale inhibitor Substances 0.000 claims abstract description 17
- 206010017076 Fracture Diseases 0.000 claims abstract description 15
- 239000000126 substance Substances 0.000 claims abstract description 14
- 208000010392 Bone Fractures Diseases 0.000 claims abstract description 12
- 230000007423 decrease Effects 0.000 claims abstract description 8
- 229910010293 ceramic material Inorganic materials 0.000 claims abstract description 3
- 238000000034 method Methods 0.000 claims description 14
- 238000001311 chemical methods and process Methods 0.000 claims description 3
- 230000000694 effects Effects 0.000 claims description 3
- 230000035699 permeability Effects 0.000 abstract description 6
- 229920003169 water-soluble polymer Polymers 0.000 abstract description 2
- 239000011324 bead Substances 0.000 description 18
- 230000015572 biosynthetic process Effects 0.000 description 9
- 238000005755 formation reaction Methods 0.000 description 9
- 239000012530 fluid Substances 0.000 description 8
- 239000007787 solid Substances 0.000 description 4
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical compound [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 description 3
- 239000000919 ceramic Substances 0.000 description 3
- 239000003112 inhibitor Substances 0.000 description 3
- 230000002939 deleterious effect Effects 0.000 description 2
- 238000004090 dissolution Methods 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 239000011435 rock Substances 0.000 description 2
- OYPRJOBELJOOCE-UHFFFAOYSA-N Calcium Chemical compound [Ca] OYPRJOBELJOOCE-UHFFFAOYSA-N 0.000 description 1
- FYYHWMGAXLPEAU-UHFFFAOYSA-N Magnesium Chemical compound [Mg] FYYHWMGAXLPEAU-UHFFFAOYSA-N 0.000 description 1
- 239000011149 active material Substances 0.000 description 1
- 229910000323 aluminium silicate Inorganic materials 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000011575 calcium Substances 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 150000001768 cations Chemical class 0.000 description 1
- 150000001805 chlorine compounds Chemical class 0.000 description 1
- 239000011248 coating agent Substances 0.000 description 1
- 238000000576 coating method Methods 0.000 description 1
- 238000005260 corrosion Methods 0.000 description 1
- 230000007797 corrosion Effects 0.000 description 1
- HNPSIPDUKPIQMN-UHFFFAOYSA-N dioxosilane;oxo(oxoalumanyloxy)alumane Chemical compound O=[Si]=O.O=[Al]O[Al]=O HNPSIPDUKPIQMN-UHFFFAOYSA-N 0.000 description 1
- DUYCTCQXNHFCSJ-UHFFFAOYSA-N dtpmp Chemical compound OP(=O)(O)CN(CP(O)(O)=O)CCN(CP(O)(=O)O)CCN(CP(O)(O)=O)CP(O)(O)=O DUYCTCQXNHFCSJ-UHFFFAOYSA-N 0.000 description 1
- 239000011777 magnesium Substances 0.000 description 1
- 229910052749 magnesium Inorganic materials 0.000 description 1
- 230000007246 mechanism Effects 0.000 description 1
- 239000003129 oil well Substances 0.000 description 1
- 229920000642 polymer Polymers 0.000 description 1
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 OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—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 -
Landscapes
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Chemical & Material Sciences (AREA)
- Engineering & Computer Science (AREA)
- Geology (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
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
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.
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 |
|---|---|---|---|
| GB9808490.8 | 1998-04-22 | ||
| GBGB9808490.8A GB9808490D0 (en) | 1998-04-22 | 1998-04-22 | Well treatment for water restriction |
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 (30)
| 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 |
| US11254850B2 (en) | 2017-11-03 | 2022-02-22 | Baker Hughes Holdings Llc | Treatment methods using aqueous fluids containing oil-soluble treatment agents |
| 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 |
| US12060523B2 (en) | 2017-07-13 | 2024-08-13 | Baker Hughes Holdings Llc | Method of introducing oil-soluble well treatment agent into a well or subterranean formation |
Citations (4)
| 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 |
-
1998
- 1998-04-22 GB GBGB9808490.8A patent/GB9808490D0/en not_active Ceased
-
1999
- 1999-04-13 WO PCT/GB1999/001125 patent/WO1999054592A1/en active Application Filing
- 1999-04-13 AU AU35293/99A patent/AU3529399A/en not_active Abandoned
Patent Citations (4)
| 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 (43)
| 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 |
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| US9976070B2 (en) | 2010-07-19 | 2018-05-22 | Baker Hughes, A Ge Company, Llc | Method of using shaped compressed pellets in well treatment operations |
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| 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 |
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| 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 |
| US12060523B2 (en) | 2017-07-13 | 2024-08-13 | Baker Hughes Holdings Llc | Method of introducing oil-soluble well treatment agent into a well or subterranean formation |
| 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 |
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