WO2012009184A2 - Water sensitive porous medium to control downhole water production and method therefor - Google Patents
Water sensitive porous medium to control downhole water production and method therefor Download PDFInfo
- Publication number
- WO2012009184A2 WO2012009184A2 PCT/US2011/042993 US2011042993W WO2012009184A2 WO 2012009184 A2 WO2012009184 A2 WO 2012009184A2 US 2011042993 W US2011042993 W US 2011042993W WO 2012009184 A2 WO2012009184 A2 WO 2012009184A2
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- copolymers
- water
- acrylamide
- solid particles
- crosslinked
- 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
- E21B34/00—Valve arrangements for boreholes or wells
- E21B34/06—Valve arrangements for boreholes or wells in wells
- E21B34/08—Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
-
- 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
- E21B43/32—Preventing gas- or water-coning phenomena, i.e. the formation of a conical column of gas or water around 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
- E21B43/34—Arrangements for separating materials produced by the well
Definitions
- the present invention relates to apparatus and methods for controlling the production of fluid through a device in a wellbore and methods for constructing said apparatus, and more particularly relates, in one non- limiting embodiment, to apparatus for and methods of inhibiting and controlling the flow of water through a wellbore from subterranean formations during hydrocarbon recovery operations and methods for constructing said apparatus.
- Oil and gas wells are typically completed by placing a casing along the wellbore length and perforating the casing adjacent each such production zone to extract the formation fluids (such as hydrocarbons) into the wellbore. These production zones are sometimes separated or isolated from each other by installing a packer between the production zones. Fluid from each production zone entering the wellbore is drawn into a tubing that runs to the surface. It is desirable to have substantially even drainage along the production zone. Uneven drainage may result in undesirable conditions such as an invasive gas cone or water cone. In the instance of an oil-producing well, for example, a gas cone may cause an in-flow of gas into the wellbore that could significantly reduce oil production. Similarly, a water cone may cause an in-flow of water into the oil production flow that reduces the amount and quality of the produced oil.
- a wellbore device for controlling a flow of a fluid through a flow path therein.
- the wellbore device includes a container comprising a flow path and a consolidated water sensitive porous medium (WSPM) packed within the flow path of the wellbore device container.
- WSPM consolidated water sensitive porous medium
- the WSPM includes solid particles and at least one water hydrolyzable polymer at least partially coated on the solid particles.
- a method of constructing a wellbore device for controlling a flow of a fluid through a flow path in the wellbore device involves mixing solid particles with at least one water hydrolyzable polymer in the presence of a fluid that may be water or brine to give a mixture.
- the method further includes at least partially drying the mixture.
- the method involves packing the at least partially dried mixture into the flow path of the container of the wellbore device to form a consolidated water sensitive porous medium (WSPM).
- WSPM water sensitive porous medium
- a method for controlling a flow of a fluid through a flow path in a wellbore device in a wellbore involves flowing the fluid through the flowpath in the wellbore device and controlling a resistance to flow of the fluid through the flow path whereby: resistance to flow increases as water content of the fluid increases, and resistance to flow decreases as water content of the fluid decreases.
- the wellbore device used includes a container (which may be coextensive therewith) comprising the flow path and a consolidated water sensitive porous medium (WSPM) packed within the flow path of the wellbore device container.
- the WSPM includes solid particles and at least one water hydrolyzable polymer at least partially coated on the solid particles.
- FIG. 1 is a schematic illustration of water sensitive porous media (WSPM) installed inside a wellbore to control the production of water;
- WSPM water sensitive porous media
- FIGS. 2A and 2B are schematic illustrations of different water cuts generating different flow resistance when flowing through a WSPM as a result of different degrees of polymer chain activation (expansion);
- FIG. 3 is a graph of the pressure differential of WSPM (cross- linked VF-1 copolymer coated on 20-60 mesh (850-250 micron) HSP ® proppant) at 200 °F (93 °C) with diesel and simulated formation brine (SFB);
- FIG. 4 is a graph of a pressure drop response for different water cut fluids flowing through WSPM at 200 °F (93 O);
- FIG. 5 is a microphotograph of 20/40 mesh (850/425 micron) HSP ceramic proppant before polymer coating.
- FIG. 6 is a microphotograph of 20/40 mesh (850/425 micron) HSP ceramic proppant after polymer coating.
- the WSPM may be constructed of water-soluble or water-hydrolyzable, high molecular weight polymers which are coated on solid particles, such as sand, glass beads, and ceramic proppants.
- the coated particles are packed under high pressure to form a consolidated homogenous and high porosity porous medium within a container of a wellbore device.
- the container and the wellbore device may be separate structures, where the container is part of the wellbore device, or the container and the wellbore device may be the same and coextensive.
- the polymers may be optionally crosslinked with crosslinking agents.
- the solid particles may be mixed with the polymer solution, e.g. in a blender or mixer, at a particular ratio.
- the production of unwanted subterranean formation water may be prevented, controlled or inhibited by a method involving treating particles with high molecular weight, water-hydrolyzable polymers, and incorporating the particles into a water sensitive porous medium (WSPM) in a wellbore device placed within the wellbore.
- the polymer-coated particles are introduced into a container of a wellbore device under high pressure to form a consolidated WSPM in the device before its introduction downhole.
- the relatively high molecular weight polymers that have components or functional groups that anchor, affiliate or attach onto the surface of the solid particles.
- the polymers are hydrophilic and/or hydrolyzable meaning they swell or expand in physical size upon contact with water.
- the average particle size of the particles may range from about 1 0 mesh to about 100 mesh (from about 2000 microns to about 150 microns). Alternatively, the average particle size of the particles may range from about 20 mesh independently to about 60 mesh (from about 840 microns to about 250 microns); where the term "independently" means that any lower threshold may be combined with any upper threshold.
- the solid particles which serve as a substrate to the water hydrolyzable polymer are relatively small, particulate matter, but should not be confused with atomic particles or subatomic particles.
- the particles may be any of a wide variety of solid particulate material; suitable materials include, but are not necessarily limited to, sand, glass beads, ceramic beads, metal beads, bauxite grains, walnut shell fragments, aluminum pellets, nylon pellets and combinations thereof, including conventional proppants and gravel, and, including proppants and gravel of to- be-developed materials.
- suitable materials include, but are not necessarily limited to, sand, glass beads, ceramic beads, metal beads, bauxite grains, walnut shell fragments, aluminum pellets, nylon pellets and combinations thereof, including conventional proppants and gravel, and, including proppants and gravel of to- be-developed materials.
- Proppants are known in the oilfield as sized particles typically mixed with fracturing fluids to hold open fractures after a hydraulic fracturing treatment. Proppants are sorted for size and sphericity to provide an effective conduit for the production of oil and/or gas from the reservoir to the wellbore.
- Granular has a particular meaning in the oilfield relating to particles of a specific size or specific size range which are placed between a screen that is positioned in the wellbore and the surrounding annulus.
- the size of the gravel is selected to prevent the passage of sand from the formation through the gravel pack.
- the solid particles e.g. proppants or gravel
- the solid particles may suitably be a variety of materials including, but not necessarily limited to, sand (the most common component of which is silica, i.e. silicon dioxide, Si0 2 ), glass beads, ceramic beads, metal beads, bauxite grains, walnut shell fragments, aluminum pellets, nylon pellets and combinations thereof.
- the particles may be coated by a method that involves at least partially hydrolyzing the polymer in a liquid including, but not necessarily limited to, water, brine, glycol, ethanol and mixtures thereof.
- the particles are then intimately mixed or contacted with the liquid containing the polymer to contact the surfaces of the particles with the polymer.
- the liquid is then at least partially vaporized or evaporated through vacuum, or the use of heat and/or contact with a dry gas such as air, nitrogen, or the like.
- the coating method may be conducted at a temperature between ambient up to about 200 °F (about 93°C), to facilitate quick drying of the coating. It may not be necessary in some embodiments to completely dry the coating.
- the loading of the polymers may be a ratio of weight of solid particles to weight of dry water hydrolyzable polymer ranging from about 1 0,000:1 to about 1 0:1 ; alternatively ranging from about 500:1 independently to about 25:1 .
- the solid particles should be at least partially coated by the polymer; that is, while it is desirable to completely coat the solid particles with the polymer, the method and apparatus may still be considered successful if the particles are at least partially coated to the extent the WSPM functions effectively for the purposes noted herein.
- the high pressure used to pack the water hydrolyzable polymer coated particles into the container of the wellbore device through which the flow path exists may range from about 50 to about 2000 psi (about 0.3 to about 1 3.8 MPa), alternatively from about 1 00 independently to about 1000 psi (about 0.7 to about 6.9 MPa).
- the WSPM placed in the wellbore will control unwanted formation water flowing through the wellbore while not adversely affecting the flow of oil and gas.
- the polymers anchored on the solid particles expand to reduce the water flow channel and increase the resistance to water flow.
- the polymers may be understood to interact chemically, ionically or mechanically with a component of the produced or in-flowing formation fluids, e.g. water molecules. This desired response may be variously described as resistance, permeability, impedance, etc. , where the flow of hydrocarbons (e.g. oil and gas) is desirable, but the flow of water is not. This interaction varies the resistance to flow across the flow path of the wellbore device.
- the pre-treated particles e.g. proppants
- the pre-treated particles are expected to form homogeneous porous media with the polymer uniformly distributed in the media to increase the efficiency of the polymer controlling unwanted water production.
- suitable water hydrolyzable polymers include those having a weight average molecular weight greater than 1 00,000.
- suitable, more specific examples of water hydrolyzable polymers include, but are not necessarily limited to, homopolymers and copolymers of acrylamide, sulfonated or quaternized homopolymers and copolymers of acrylamide, polyvinylalcohols, polysiloxanes, hydrophilic natural gum polymers and chemically modified derivatives thereof.
- Crosslinked versions of these polymers may also be suitable, including but not necessarily limited to, crosslinked homopolymers and copolymers of acrylamide, crosslinked sulfonated or quaternized homopolymers and copolymers of acrylamide, crosslinked polyvinylalcohols, crosslinked polysiloxanes, crosslinked hydrophilic natural gum polymers and chemically modified derivatives thereof.
- suitable water hydrolyzable polymers include, but are not necessarily limited to, copolymers having a hydrophilic monomeric unit, where the hydrophilic monomeric unit is selected from the group consisting of ammonium and alkali metal salt of acrylamido- methylpropanesulfonic acid (AMPS), a first anchoring monomeric unit based on N-vinylformamide and a filler monomeric unit, where the filler monomeric unit is selected from the group consisting of acrylamide and methylacrylamide.
- AMPS acrylamido- methylpropanesulfonic acid
- Additional suitable water hydrolyzable polymers include, but are not necessarily limited to, copolymers of vinylamide monomers and monomers containing ammonium or quaternary ammonium moieties, copolymers of vinylamide monomers and monomers comprising vinylcarboxylic acid monomers and/or vinylsulfonic acid monomers, and salts thereof, and these aforementioned copolymers further comprising a crosslinking monomer selected from the group consisting of bis-acrylamide, diallylamine, ⁇ , ⁇ -diallylacrylamide, divinyloxy- ethane, divinyldimethylsilane.
- Suitable crosslinking agents include, but are not necessarily limited to, aluminum, boron, chromium, zirconium, titanium, and other inorganic based and organic based crosslinking agents and other conventional crosslinking agents.
- RPMs relative permeability modifiers
- FIG. 1 Shown in FIG. 1 is a schematic illustration of an oil well 10 having a wellbore 12, which happens to be vertical in part and horizontal in part, in a subterranean formation 14 that contains both oil and water.
- Water sensitive porous media (WSPM) within wellbore devices 16 have been installed at four locations between packers 18 along the horizontal section of the wellbore 12 to control the production of water.
- the flow of oil from the formation 14 into the wellbore 12 is schematically indicated by black arrows 20, whereas the flow of water is schematically indicated by gray arrows 22.
- the flow of oil 20 is uninhibited by the WSPM due to the lack of resistance of the unhydrolyzed polymer, whereas the flow of water is inhibited by the increased resistance of the hydrolyzed polymer, as indicated by the lower water flow at small gray arrows 24.
- FIG. 2 Shown in FIG. 2 is a schematic illustration of different water cuts generating different flow resistance when flowing through a WSPM 16 as a result of different degrees of polymer chain activation (expansion).
- the WSPM 16 includes solid particles 30 having water hydrolyzable polymers 32 at least partially coated thereon or adhered thereto.
- the water droplets are schematically represented by gray circles 34 and the oil droplets are schematically represented by black circles 36.
- FIG. 2A schematically illustrates the WSPM 16 where a 25% water cut flows in the direction shown (left to right) where the relatively low amount of water droplets 34 cause a relatively small amount of the polymer 32 to swell, enlarge or hydrolyze increasing resistance to flow.
- FIG. 1 schematically illustrates the WSPM 16 where a 25% water cut flows in the direction shown (left to right) where the relatively low amount of water droplets 34 cause a relatively small amount of the polymer 32 to swell, enlarge or hydrolyze increasing resistance to flow.
- FIG. 2B schematically illustrates the WSPM 16 where a larger 50% water cut flows in the direction shown (left to right) where the relatively equal amount of water droplets 34 compared to the oil droplets 36 cause a relatively larger amount of the polymer 32 to swell, enlarge or hydrolyze further increasing resistance to flow, as compared with FIG. 2A.
- FIG. 5 is a microphotograph of 20/40 mesh (850/425 micron) HSP ® ceramic proppant before polymer coating.
- HSP proppant is available from Carbo Ceramics.
- FIG. 6 is a microphotograph of the same 20/40 mesh (850/425 micron) HSP ceramic proppant after polymer coating. It may be seen that each proppant particle in FIG. 6 is fully coated and bonded by the polymer using the coating method described.
- the stainless steel tube (container, simulating a wellbore device) is affixed on one end with an end cap; a 1 00 mesh (150 micron) stainless screen is laid inside the end cap to hold the polymer coated proppants;
- Steps 3) and 4) are repeated until the length of the porous medium reaches desired porous medium length;
- FIG. 3 is a graph of the pressure differential of crosslinked VF-1 copolymer coated on 20-60 mesh (850-250 micron) HSP proppant at 200 °F (93°C) with diesel and simulated formation brine (SFB).
- VF-1 is a cross-linked vinylamide-vinylsulfonate copolymer.
- the HSP proppants were coated with the VF-1 polymer as described above.
- the polymer loading was 0.4 % bw (by weight) of the proppant weight.
- FIG. 3 is a response test graph showing that the pressure differential of the polymer-coated proppant WSPM placed inside of a 1 2-inch long, 1 -inch ID stainless steel tube (about 30 cm long by about 2.5 cm ID) changes when pumping with oil (diesel in this Example) relative to pumping with formation water (Simulated Formation Brine or SFB) flowing through the pack.
- This graph demonstrates that the pack exhibits high flow resistance for water and low flow resistance for oil.
- FIG. 4 is a graph of a pressure drop response for different water cut fluids flowing through a WSPM at 200°F (93 °C). The fluids were blends of brine and diesel. With increasing amounts of water (greater water cut percentage), the higher the pressure drop.
- the WSPM was made from VF-1 coated 50-60 mesh (297 to 250 micron) ceramic proppants with polymer loading 0.4%. Different water cuts are marked on FIG 4.
- the components and proportions of the solid particles and polymers and steps of constructing the wellbore devices may change somewhat from wellbore device to another and still accomplish the stated purposes and goals of the methods described herein.
- the assembly methods may use different pressures and additional or different steps than those exemplified herein.
- a wellbore device for controlling a flow of a fluid through a flow path may consist of or consist essentially of a container comprising a flow path and a consolidated water sensitive porous medium (WSPM) packed within the flow path of the wellbore device container, where the WSPM consists of or consists essentially of solid particles and at least one water hydrolyzable polymer at least partially coated on the solid particles.
- WSPM consolidated water sensitive porous medium
Abstract
Description
Claims
Priority Applications (7)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU2011279476A AU2011279476A1 (en) | 2010-07-13 | 2011-07-06 | Water sensitive porous medium to control downhole water production and method therefor |
CA2804663A CA2804663C (en) | 2010-07-13 | 2011-07-06 | Water sensitive porous medium to control downhole water production and method therefor |
GB1300119.3A GB2494826A (en) | 2010-07-13 | 2011-07-06 | Water sensitive porous medium to control downhole water production and method therefor |
CN2011800345143A CN103080472A (en) | 2010-07-13 | 2011-07-06 | Water sensitive porous medium to control downhole water production and method therefor |
BR112013000803A BR112013000803A2 (en) | 2010-07-13 | 2011-07-06 | porous water-sensitive medium to control downhole water production and method for this purpose |
MX2013000464A MX2013000464A (en) | 2010-07-13 | 2011-07-06 | Water sensitive porous medium to control downhole water production and method therefor. |
NO20130019A NO20130019A1 (en) | 2010-07-13 | 2013-01-04 | Water-sensitive porous medium for controlling water production in the wellbore and methods for this |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US12/835,023 | 2010-07-13 | ||
US12/835,023 US20110005752A1 (en) | 2008-08-14 | 2010-07-13 | Water Sensitive Porous Medium to Control Downhole Water Production and Method Therefor |
Publications (2)
Publication Number | Publication Date |
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WO2012009184A2 true WO2012009184A2 (en) | 2012-01-19 |
WO2012009184A3 WO2012009184A3 (en) | 2012-04-05 |
Family
ID=45470005
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/US2011/042993 WO2012009184A2 (en) | 2010-07-13 | 2011-07-06 | Water sensitive porous medium to control downhole water production and method therefor |
Country Status (9)
Country | Link |
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US (1) | US20110005752A1 (en) |
CN (1) | CN103080472A (en) |
AU (1) | AU2011279476A1 (en) |
BR (1) | BR112013000803A2 (en) |
CA (1) | CA2804663C (en) |
GB (1) | GB2494826A (en) |
MX (1) | MX2013000464A (en) |
NO (1) | NO20130019A1 (en) |
WO (1) | WO2012009184A2 (en) |
Families Citing this family (6)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US9051819B2 (en) | 2011-08-22 | 2015-06-09 | Baker Hughes Incorporated | Method and apparatus for selectively controlling fluid flow |
CN102364041B (en) * | 2011-10-26 | 2014-03-26 | 王胜存 | Oil extraction method for establishing oil permeable water stop sieve by filling fusheng sand in horizontal well fracture |
US9334708B2 (en) | 2012-04-23 | 2016-05-10 | Baker Hughes Incorporated | Flow control device, method and production adjustment arrangement |
CN110486004B (en) * | 2018-05-14 | 2022-05-10 | 中国石油天然气股份有限公司 | Method and device for identifying water flow dominant channel of sandstone reservoir |
CN109932489B (en) * | 2019-03-20 | 2024-02-13 | 西安航空学院 | Gas pretreatment device with mixing instrument and gas detection device |
US20230075579A1 (en) * | 2021-09-09 | 2023-03-09 | Baker Hughes Oilfield Operations Llc | Pseudoplastic flow control device, method and system |
Citations (4)
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US4095651A (en) * | 1975-09-25 | 1978-06-20 | Institut Francais Du Petrole | Process for selectively plugging areas in the vicinity of oil or gas producing wells in order to reduce water penetration |
US5529124A (en) * | 1994-12-19 | 1996-06-25 | Texaco Inc. | Method for retarding water coning |
US5701956A (en) * | 1996-04-17 | 1997-12-30 | Halliburton Energy Services, Inc. | Methods and compositions for reducing water production from subterranean formations |
US20090301726A1 (en) * | 2007-10-12 | 2009-12-10 | Baker Hughes Incorporated | Apparatus and Method for Controlling Water In-Flow Into Wellbores |
Family Cites Families (16)
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US3336979A (en) * | 1965-07-26 | 1967-08-22 | Dow Chemical Co | Composition and use thereof for water shut-off |
US3878893A (en) * | 1972-10-06 | 1975-04-22 | Dow Chemical Co | Method for forming a consolidated gravel pack in a well borehole |
US5735349A (en) * | 1996-08-16 | 1998-04-07 | Bj Services Company | Compositions and methods for modifying the permeability of subterranean formations |
US5981447A (en) * | 1997-05-28 | 1999-11-09 | Schlumberger Technology Corporation | Method and composition for controlling fluid loss in high permeability hydrocarbon bearing formations |
US6228812B1 (en) * | 1998-12-10 | 2001-05-08 | Bj Services Company | Compositions and methods for selective modification of subterranean formation permeability |
US7008908B2 (en) * | 2002-11-22 | 2006-03-07 | Schlumberger Technology Corporation | Selective stimulation with selective water reduction |
US7117942B2 (en) * | 2004-06-29 | 2006-10-10 | Halliburton Energy Services, Inc. | Methods useful for controlling fluid loss during sand control operations |
US7207386B2 (en) * | 2003-06-20 | 2007-04-24 | Bj Services Company | Method of hydraulic fracturing to reduce unwanted water production |
US7223827B1 (en) * | 2004-02-27 | 2007-05-29 | Fritz Industries, Inc | Water control in a subsurface formation |
US20060065396A1 (en) * | 2004-08-13 | 2006-03-30 | Dawson Jeffrey C | Compositions containing water control treatments and formation damage control additives, and methods for their use |
US7398825B2 (en) * | 2004-12-03 | 2008-07-15 | Halliburton Energy Services, Inc. | Methods of controlling sand and water production in subterranean zones |
US7493957B2 (en) * | 2005-07-15 | 2009-02-24 | Halliburton Energy Services, Inc. | Methods for controlling water and sand production in subterranean wells |
US7776797B2 (en) * | 2006-01-23 | 2010-08-17 | Halliburton Energy Services, Inc. | Lost circulation compositions |
MX2008010008A (en) * | 2006-02-10 | 2008-11-20 | Exxonmobil Upstream Res Co | Conformance control through stimulus-responsive materials. |
US7637320B2 (en) * | 2006-12-18 | 2009-12-29 | Schlumberger Technology Corporation | Differential filters for stopping water during oil production |
US7942206B2 (en) * | 2007-10-12 | 2011-05-17 | Baker Hughes Incorporated | In-flow control device utilizing a water sensitive media |
-
2010
- 2010-07-13 US US12/835,023 patent/US20110005752A1/en not_active Abandoned
-
2011
- 2011-07-06 CA CA2804663A patent/CA2804663C/en not_active Expired - Fee Related
- 2011-07-06 MX MX2013000464A patent/MX2013000464A/en unknown
- 2011-07-06 GB GB1300119.3A patent/GB2494826A/en not_active Withdrawn
- 2011-07-06 WO PCT/US2011/042993 patent/WO2012009184A2/en active Application Filing
- 2011-07-06 AU AU2011279476A patent/AU2011279476A1/en not_active Abandoned
- 2011-07-06 CN CN2011800345143A patent/CN103080472A/en active Pending
- 2011-07-06 BR BR112013000803A patent/BR112013000803A2/en not_active IP Right Cessation
-
2013
- 2013-01-04 NO NO20130019A patent/NO20130019A1/en not_active Application Discontinuation
Patent Citations (4)
Publication number | Priority date | Publication date | Assignee | Title |
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US4095651A (en) * | 1975-09-25 | 1978-06-20 | Institut Francais Du Petrole | Process for selectively plugging areas in the vicinity of oil or gas producing wells in order to reduce water penetration |
US5529124A (en) * | 1994-12-19 | 1996-06-25 | Texaco Inc. | Method for retarding water coning |
US5701956A (en) * | 1996-04-17 | 1997-12-30 | Halliburton Energy Services, Inc. | Methods and compositions for reducing water production from subterranean formations |
US20090301726A1 (en) * | 2007-10-12 | 2009-12-10 | Baker Hughes Incorporated | Apparatus and Method for Controlling Water In-Flow Into Wellbores |
Also Published As
Publication number | Publication date |
---|---|
MX2013000464A (en) | 2013-02-27 |
WO2012009184A3 (en) | 2012-04-05 |
CA2804663A1 (en) | 2012-01-19 |
CA2804663C (en) | 2015-06-02 |
AU2011279476A1 (en) | 2013-01-24 |
BR112013000803A2 (en) | 2017-11-14 |
GB2494826A (en) | 2013-03-20 |
GB201300119D0 (en) | 2013-02-20 |
NO20130019A1 (en) | 2013-02-13 |
US20110005752A1 (en) | 2011-01-13 |
CN103080472A (en) | 2013-05-01 |
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