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WO2014172715A1 - Système de gonflage d'un élément de garniture par activateur à époxy, procédés de gonflement d'un élément de garniture par un système d'activateur à époxy, élément de garniture gonflable par un activateur à époxy dans la vessie - Google Patents

Système de gonflage d'un élément de garniture par activateur à époxy, procédés de gonflement d'un élément de garniture par un système d'activateur à époxy, élément de garniture gonflable par un activateur à époxy dans la vessie Download PDF

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Publication number
WO2014172715A1
WO2014172715A1 PCT/US2014/034846 US2014034846W WO2014172715A1 WO 2014172715 A1 WO2014172715 A1 WO 2014172715A1 US 2014034846 W US2014034846 W US 2014034846W WO 2014172715 A1 WO2014172715 A1 WO 2014172715A1
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WO
WIPO (PCT)
Prior art keywords
packer
epoxy
inflatable
inflating
activator
Prior art date
Legal status (The legal status 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 status listed.)
Ceased
Application number
PCT/US2014/034846
Other languages
English (en)
Inventor
Boyce D. Burts
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
Bottom Line Industries Inc
Original Assignee
Bottom Line Industries Inc
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 Bottom Line Industries Inc filed Critical Bottom Line Industries Inc
Publication of WO2014172715A1 publication Critical patent/WO2014172715A1/fr
Anticipated expiration legal-status Critical
Ceased legal-status Critical Current

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Classifications

    • 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
    • E21B33/00—Sealing or packing boreholes or wells
    • E21B33/10—Sealing or packing boreholes or wells in the borehole
    • E21B33/12—Packers; Plugs
    • E21B33/127—Packers; Plugs with inflatable sleeve
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B23/00—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
    • E21B23/06—Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers

Definitions

  • the present invention relates to methods, apparatus, products and compositions relating to inflatable packers.
  • the present invention relates to methods, apparatus, products and compositions relating to inflatable packers inflated with a two part inflating composition comprising a polymeric component and an activator component.
  • the present invention relates to a two part inflating composition comprising a polymeric component and an activator component, to methods of inflating an inflatable packer using such a composition, to inflatable packers comprising such compositions in the inflatable portion of the packer, and to wellbore systems comprising such packers with such compositions.
  • the present invention relates to a two part inflating composition comprising an epoxy and an activator component, to methods of inflating an inflatable packer using such a composition, to inflatable packers comprising such compositions in the inflatable portion of the packer, and to wellbore systems comprising such packers with such compositions.
  • Hydrocarbon fluids such as oil and natural gas are obtained from a subterranean geologic formation, referred to as a reservoir, by drilling a well that penetrates the hydrocarbon-bearing formation. Once a wellbore has been drilled, the well must be completed before hydrocarbons can be produced from the well. A completion involves the design, selection, and installation of equipment and materials in or around the wellbore for conveying, pumping, or controlling the production or injection of fluids. After the well has been completed, production of oil and gas can begin.
  • Sand or silt flowing into the wellbore from unconsolidated formations can lead to an accumulation of fill within the wellbore, reduced production rates and damage to subsurface production equipment.
  • Migrating sand has the possibility of packing off around the subsurface production equipment, or may enter the production tubing and become carried into the production equipment. Due to its highly abrasive nature, sand contained within production streams can result in the erosion of tubing, flowlines, valves and processing equipment. The problems caused by sand production can significantly increase operational and maintenance expenses and can lead to a total loss of the well.
  • One means of controlling sand production is the placement of relatively large sand (i.e., "gravel") around the exterior of a slotted, perforated, or other type liner or screen.
  • the gravel serves as a filter to help assure that formation fines and sand do not migrate with the produced fluids into the wellbore.
  • a screen is placed in the wellbore and positioned within the unconsolidated formation that is to be completed for production.
  • the screen is typically connected to a tool that includes a production packer and a cross-over, and the tool is in turn connected to a work or production tubing string.
  • the gravel is pumped in a slurry down the tubing and through the cross-over, thereby flowing into the annulus between the screen and the wellbore.
  • the liquid forming the slurry leaks off into the formation and/or through the screen, which is sized to prevent the sand in the slurry from flowing through.
  • the sand is deposited in the annulus around the screen where it forms a gravel pack.
  • the screen prevents the gravel pack from entering into the production tubing. It is important to size the gravel for proper containment of the formation sand, and the screen must be designed in a manner to prevent the flow of the gravel through the screen.
  • a problem that is frequently encountered during a well completion is the need to seal off sections of the wellbore. These sections can include areas in which an adequate gravel pack cannot be obtained, such as below the bottom of the gravel pack screens where adequate circulation is difficult to achieve. In some formations, such as across a major or minor shale section, a gravel pack completion is not desirable. Sections of the hole that are not going to be completed often need to be isolated from the sections that will be completed. If these areas that are not going to be completed were left open, the gravel which is tightly packed around the gravel pack screens after a gravel pack may be able to migrate to these void areas, thereby losing the protection provided by the gravel pack completion. Once the well is placed on production, the flow of produced fluids may accelerate the gravel migration by having a fluidizing effect on the gravel. This migration could expose the screens to direct production of formation sand and could result in equipment damage, formation collapse and even the loss of the well.
  • Annular cementing has long been used to provide zonal isolation. However, it is also well recognized in the art of oil and gas drilling that it is, at times, desirable to provide annular isolation in a well liner using formation packers in lieu of conventional annular cementing. This allows for improved well management, and more specifically, the creation of zones to enable:
  • hydraulic anchor packers may be used to isolate sections of a well bore and support materials and equipment within a well bore.
  • Conventional hydraulic anchor packers typically comprise a plurality of metallic gripping elements having a serrated surface for engaging the wall of a well bore.
  • the gripping elements are generally mounted on, or operated by, hydraulic pistons which move the gripping elements between gripping and non-gripping positions in response to a hydraulic pressure differential.
  • an inflatable packer is a very specific type of packer which is set in place and then inflated to provide a seal.
  • inflatable packers that comprise an inflatable bladder (commonly elastomeric or other polymeric material) are well known in the industry and have been used in attempts to seal off sections of a wellbore for the reasons discussed above.
  • the bladder defines a chamber that contains a pressurized fluid which is used to inflate the packer while an exterior surface body (again, commonly elastomeric or other polymeric material) seals against the wellbore and prohibits fluid flow past the packer when in its inflated condition
  • these inflatable packers that are used for the creation of such annular isolation zones, may be filled cement or some other settable composition such as resin.
  • the packers may be inflated with non-settable liquids, including drilling mud or other well fluid, particularly if the use is only needed for a short time and the packer is to be retrieved.
  • inflatable packers may be used in a well for a number of other reasons. As a non-limiting example, they can be used to support a column of cement above a lost circulation zone. As another example, inflatable packers may be used to support materials and/or equipment within a wellbore. As another non-limiting example, inflatable packers can be used to isolate producing zones from cement contact. As even another non- limiting example, at times inflatable packers are used to centralize a casing during cementing operations. Also, inflatable packers may be used to isolate production and lost circulation zones for gravel pack operations. Also, inflatable packers may be used in hydrological and/or stress testing. Also, inflatable packers may be used in grouting operations.
  • inflatable packers may be used in the relining of deteriorated casing or seal casing in open hole situations. Also, inflatable packers may be used in sampling the well. Also, inflatable packers may be used in mechanical integrity testing. As even another non-limiting example, inflatable packers may also be used in certain situations on the outside of the liner.
  • the present invention results from a desire to provide improved and more reliable inflating of packers under any circumstance for any reason, application or use.
  • the methods, apparatus, products and compositions encompasses the inflation of packers under any circumstance for any reason, application or use. Indeed, the inventions disclosed herein may be applied to any situation or location where downhole packers require to be inflated.
  • Fixed and sliding end shoes each are a single machined structure and include a roughened inner cylindrical surface disposed about an end of the reinforcing element.
  • Upper and lower hardened rings, formed from a liquid adhesive, have the ends of the reinforcing element embedded therein and are bonded to the end shoes.
  • United States Patent No. 6,431,273 to McGarian, et al., issued August 13, 2002 discloses hydraulic anchor packers for use in well bores and, more particularly, to inflatable anchor packers.
  • the disclosed hydraulic anchor packer (90) is provided having an inflatable packer element (36) incorporating a cylinder (38) and an elastomer sleeve (44) provided on the exterior surface thereof but free of the cylinder (38) intermediate the end portions. Means are provided for causing fluid from within the cylinder (38) to flow through an aperture (48) and between the elastomer sleeve (44) and the exterior surface of the cylinder so as to radially expand the sleeve (44). Means are also provided for trapping fluid so as to prevent relaxation of the sleeve (44).
  • Pressure relief means (92, 94, 98) permits fluid located exteriorly of the packer (90) to move past the sleeve (44) as the sleeve (44) expands whilst in engagement with a well bore wall during use.
  • the downhole half of the sleeve (44) may freely expand and displace fluid located below the packer (90.
  • the inflatable element is adapted for inflation by gravel.
  • One embodiment of the invention is a method of sealing an annulus in a well that comprises expanding the inflatable element with a gravel laden slurry.
  • the inflatable element comprises a passageway communicating between an exterior and an interior of the inflatable element.
  • the inflatable element is capable of being connected to a sand screen and the inflatable element can be inflated with the gravel laden slurry during a gravel packing of the well.
  • United States Patent Application No. 20050039917 to Hailey, published February 24, 2005 discloses an isolation packer inflated by a fluid filtered from gravel-laden slurry.
  • the isolation packer is adapted to direct a gravel laden slurry to the particulate filter, where the filter removes a substantial amount of the particulate matter from the gravel laden slurry thereby producing an inflating fluid that is substantially free of particulate matter.
  • the inflating fluid then inflates the inflatable element thereby creating a seal in the wellbore.
  • United States Patent Application No. 20050061520 to Surjaatmadja et al., published March 24, 2005 discloses a fluid inflatable packer and method that includes a mandrel having an elongated tubular body with a number of openings along its length or other open architecture.
  • An inflatable element is disposed about the elongated tubular body of the mandrel or the interior of the fluid inflatable packer. The inflatable element is exposed to an interior of the mandrel through the openings or otherwise.
  • the inflatable element expands and contracts with pressure of process fluids in the interior of the mandrel or the fluid inflatable packer.
  • the process fluids may be unfiltered and include five or more pounds of sand or other solids per gallon.
  • a seal includes a mandrel; an element disposed radially adjacent the mandrel; a chamber defined between the mandrel and the element; and a pressure regulator in fluid communication with the chamber, the regulator configured to resist fluid flow to a selected threshold pressure related to element expansion and method.
  • a sampling method and apparatus that utilize one or more of the following to advantage is provided: restricting deformation of the packers during inflation using an annular bracing assembly; actively retracting the packers using ambient borehole pressure; and substantially centralizing the mandrel intermediate the packers so as to resist buckling of the mandrel.
  • United States Patent No. 8,028,756 to Corre, et al., issued October 4, 2011, discloses a method of curing an inflatable packer that includes providing a packer assembly having an inflatable packer around a mandrel; a polyamide bandage around the inflatable packer; and a sealing layer around both the polyamide bandage and the inflatable packer to from an airtight seal about the inflatable packer, wherein the method further includes curing the assembled packer assembly.
  • an inflatable packer comprising a mandrel supporting an inflatable portion, wherein the inflatable portion defines a bladder, and further comprising an inflating composition residing in the bladder, wherein the inflating composition comprises a polymeric component and an activator component.
  • a method of inflating an inflatable packer having an inflatable portion comprising: (a) providing an inflating composition to the inflatable portion to inflate the inflatable portion, wherein the inflating composition comprises a polymeric component and an activator component.
  • a method of operating a well comprising a well bore in the subterranean with an inflatable packer having an inflatable portion residing in the well bore, the method comprising: (a) providing an inflating composition to the inflatable portion to inflate the inflatable portion, wherein the inflating composition comprises a polymeric component and an activator component.
  • Various subembodiments of the above embodiments may include wherein the polymeric component is an epoxy, wherein the epoxy is a difunctional epoxy resin produced from bisphenol-F (BPF) and epichlorohydrin, modified with an aliphatic monoglycidyl ether or glycidyl ester; wherein the activating agent is an aliphatic amidoamine.
  • a further method step for the above method embodiments may include (b) allowing the inflating composition to harden to keep the inflatable portion inflated.
  • the present disclosure relates to inflatable packers that comprise an inflatable bladder (commonly elastomeric or other polymeric material) that are used to seal off sections of a wellbore for the reasons discussed above.
  • the bladder defines a chamber for receiving the inflating compositions of the present invention and thus inflate the packer while an exterior surface body (again, commonly elastomeric or other polymeric material) seals against the wellbore and prohibits fluid flow past the packer when in its inflated condition.
  • Inflatable packers of the present invention will include an inflating composition residing in the inflatable portion of the inflatable packer, the inflating composition comprising a polymeric component and an activator component.
  • the present invention is also directed to two part inflating compositions for inflating inflatable packers, comprising a polymeric component and an activator component.
  • the polymeric component will in the presence of an activator component be set up, reacted, hardened, cured, catalyzed or crosslinked into a hardened mass for keeping the inflatable packer inflated.
  • the two part inflating composition may optionally include additional component parts.
  • the present disclosure is also directed to methods of inflating an inflatable packer with a two part inflating composition comprising a polymeric component and an activator component.
  • a preferred inflating composition of the present invention that is useful for inflating an inflatable packer comprises a two part inflating composition, which is incorporated into known packer inflating methods and useful with known inflatable packers.
  • the two part inflating composition of the present invention comprises a polymeric component and an activator component.
  • the polymeric component will in the presence of an activator component be set up, reacted, hardened, cured, catalyzed or crosslinked into a hardened mass, sufficient to keep the inflated packer in an inflated position.
  • the polymeric component utilized in the present invention may be any suitable polymeric material for forming the inflating material that is sufficient to inflate the inflatable packer and at some point thereafter retain its shape to keep the packer inflated.
  • suitable polymeric systems include those described in U.S. Patent No. 8,235,116 and 7,748,455, both of which are herein incorporated by reference.
  • This polymeric component may comprise a thermoplastic or thermoset material, which can be water soluble or insoluble.
  • the polymeric component is an epoxy.
  • the polymeric system not only contains the polymeric material and activator, but may optionally include additives to improve thermal stability, control set time, generate expansion, and control fluid loss. The additives may be incorporated into the system directly, or into one or both of the components.
  • any suitable polymeric system may be utilized, with epoxy systems being preferred.
  • a suitable polymeric system it is optionally desired that the system exhibit one or more, preferably several if not all, of the following characteristics: liquid system that is solid free, no shrinkage upon set up, maintains (or causes an increase in) the wellhole pressure; hydrophobic; a density that would allows it to fall thru the well fluid at a suitable rate; and non-gas generating (so as not to cause micro channels).
  • the epoxy component is modified with at least one of Monofunctional Aliphatic Glycidyl Ethers, Monofunctional Aromatic Glycidyl Ethers, Polyfunctional Glycidyl Ethers, and/or Polyfunctional Flexibilizers, all as discussed below.
  • the activator component serves not only to activate, set up, crosslink and/or cure the polymeric compound, but also to accelerate such, so as to reduce the wait on cement (WOC) time.
  • the activator causes the sealant to set under downhole temperature and pressure conditions at an accelerated rate.
  • this activator component will have to be carefully selected depending upon the material utilized as the first component.
  • accelerated set times are generally less than 12 hours, preferably less than 10 hours, more preferably less than 8 hours, even more preferably less than 6 hours, still more preferably less than 4 hours, and yet more preferably less than 2 hours.
  • the activator will cause the polymeric inflating composition to set under downhole conditions to cause the inflating composition to keep the inflatable packer in an inflatable state.
  • the activator component may be selected to not only accelerate cement set, but may optionally be selected to also alter slurry density, clean downhole surfaces, and/or improve bond.
  • the activator may be selected for its known property for accelerating the setup, activation, cure, crosslinking, of the polymeric material.
  • activators for epoxies are well known, and any suitable one may be utilized. In many instances paired epoxy-activator systems are commercially available.
  • Non-limiting examples of suitable commercially available epoxies include:
  • Epon brand Resin 862 (Diglycidyl Ether of Bisphenol F) is a low viscosity, liquid epoxy resin manufactured from epichlorohydrin and Bisphenol-F, and generally contains no diluents or modifiers.
  • Epon brand Resin 863 is a low viscosity, undiluted, difunctional epoxy resin produced from bisphenol-F (BPF) and epichlorohydrin and was specially developed to provide good resistance to crystallization.
  • epoxy modifiers include epoxy functionalized alcohols, diols, polyols and acids. Commercially available example includes the Heloxy brand modifiers. Commercially available classes include monofunctional glycidyl ethers, polyfunctional glycidyl ethers and polyfunctional flexibilizers. Certain commercially available monofunctional products include both aliphatics and aromatics and are primarily utilized as diluents for a variety of epoxy resins. Certain commercially polyfunctional modifier products are aliphatics which provide an increase in the chemical resistance and mechanical performance of the system. Certain commercially available cycloaliphatic modifier products offer improved UV resistance when compared to an aromatic modifier. The trifunctional modifier increases the crosslink density of a system. Commercially available activators include Epicure Curing Agent 3046 and 3055, both of which are an aliphatic amidoamine.
  • HELOXY Modifier 7 is an aliphatic monoglycidyl ether containing alkyl chains which are predominately C8 to CIO in length. It will usually function to provide viscosity reducing modification of epoxy resin formulations.
  • a commercially available diluent includes Cardura E10P, which is the glycidyl ester of VersaticTM Acid 10, a synthetic saturated monocarboxylic acid of highly branched CIO isomers.
  • Cardura E10P is a versatile reactive modifier that lowers viscosity, provides good moisture resistance and improved resistance to crystallization.
  • Monofunctional Aliphatic Glycidyl Ethers are low viscosity epoxy functional modifiers made from aliphatic alcohols provide maximum viscosity reduction when blended with liquid epoxy resins. They can enhance the elongation characteristics of an epoxy system.
  • Monofunctional Aromatic Glycidyl Ethers are low viscosity epoxy functional modifiers made from aromatic alcohols provide viscosity reduction when blended with liquid epoxy systems. They can enhance the tensile strength, flexural strength and elongation of an epoxy system without losing chemical resistance qualities.
  • Polyfunctional Glycidyl Ethers are di- and trifunctional reactive modifiers made from polyols that provide good viscosity reduction yet retain the functionality and crosslink density of an epoxy system. When properly formulated, the Heat Deflection Temperature of a diluted epoxy system can be maintained while also retaining tensile properties and solvent resistance.
  • Polyfunctional Flexibilizers are di- and polyfunctional reactive modifiers made from polyols and acids that provide viscosity reduction while imparting flexibility and toughness to an epoxy resin system.
  • Formulations (1) 100 Epon 862 or 863+17 to 40 Epicure 3046 good 50 F to 100 F; (2) 100 Epon 862 or 863+20 to 50 parts Heloxy 7+20 to 40 parts Epicure 3046 good 70 F to 125 F; (3) 100 Epon 862 or 863+20 to 50 parts Heloxy 7+10 to 20 parts Epicure 3046+10 to 20 parts Epicure W good 125 to 175 F; (4) 100 parts Epon 862 or 863+0 to 50 parts Heloxy 7+17 to 35 parts Epicure W good from 175 to 250 F; (5) 100 parts Epon 862 04 863+30 to 50 parts Heloxy 7+15 to 25 parts Epicure W+0 to 20 parts CarDura E10P good from 250 to 350 F.
  • the present invention also contemplates any range of activators from/to, or between 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 20, or 30 activators.
  • ranges include the following ranges from 1 to 20, from 2 to 10, from 3 to 8, from 2 to 6, between 1 and 10, between 1 and 20, between 2 and 10, between 2 and 8, between 2 and 5, and between 3 and 10 activators.
  • the present invention also contemplates having at least 1, 2, 3, 4, 5, 6, 7, 8, 9, 10, 20, 30 or more activators.
  • the activators may generally be selected to operate at various temperatures/pressures and/or well conditions, to assist in controlling any set, activation, curing, or crosslinking. A blend of polymeric material may also be utilized.
  • the method of the present invention for inflating packers and/or inflating packers in the operation of a well includes any of the known packer inflating/well operating methods in which is utilized the two component inflating composition as the inflating material. While a generalized packer inflating/well operating method is described below, it should be understood that any suitable packer inflating method/well operating method as are known in the art, including any described above in the background or described in any cited reference (all of which are herein incorporated by reference), may be utilized with the inflating composition of the present invention.
  • the packer inflating compositions of the present invention are useful in methods for inflating an inflatable packer in well bore or downhole environments.
  • the packer inflating compositions of the present invention are useful in any number of methods and well operations.
  • the packer inflating compositions of the present invention may be substituted for any known/other packer inflating composition and used to inflate an inflatable packer, non-limiting examples of such known/other compositions include cements, liquids, well fluids, oil based well fluids, water based well fluids, gases, and/or slurries.
  • the packer inflating compositions of the present invention can be used to inflate a packer to support a column of cement above a lost circulation zone.
  • packer inflating compositions of the present invention can be used to inflate packers that may be used to support materials and/or equipment within a wellbore.
  • packer inflating compositions of the present invention can be used to inflate packers that may be used to isolate producing zones from cement contact.
  • the packer inflating compositions of the present invention may be used to inflate packers that may be used to centralize a casing during cementing operations.
  • the packer inflating compositions of the present invention may be used to inflate packers to isolate production and lost circulation zones for gravel pack operations. Also, the packer inflating compositions of the present invention may be used to inflate inflatable packers used in hydrological and/or stress testing. Also, the packer inflating compositions of the present invention may be used to inflate inflatable packers used in grouting operations. Also, the packer inflating compositions of the present invention may be used to inflate inflatable packers used in the relining of deteriorated casing or seal casing in open hole situations. Also, the packer inflating compositions of the present invention may be used to inflate inflatable packers used in sampling the well.
  • the packer inflating compositions of the present invention may be used to inflate inflatable packers used in mechanical integrity testing.
  • the packer inflating compositions of the present invention may be used to inflate packers may that may be used in certain situations on the outside of the liner.
  • Non-limiting examples of the apparatus of the present invention include inflatable packers having the packer inflating compositions of the present invention residing in the inflatable portion of the inflatable packer.
  • Further non-limiting examples of the apparatus of the present invention include wellbore/downhole work string, drill string or liner string, to which is affixed an inflatable packer having the packer inflating compositions of the present invention residing in the inflatable portion of the inflatable packer.
  • Further non-limiting examples of the apparatus of the present invention include wellbores having zonal isolation provided by an inflatable packer having the packer inflating compositions of the present invention residing in the inflatable portion of the inflatable packer.
  • the epoxy component and the activator component is mixed at the surface and then placed into the inflatable portion of the inflatable backer.
  • this is accomplished by pumping the inflating composition into the inflatable portion with sufficient pressure to inflate the inflatable packer to the desired degree of inflation.
  • the inflating composition will harden sufficient to keep the inflatable packer in an inflated position.
  • the present invention also contemplates that the polymeric component and the activator component may be mixed down hole prior to being placed in the inflatable packer. For example, in-line mixing within the well bore.
  • the present invention also contemplates that the polymeric component and the activator component may be sequentially provided to the inflatable packer, in either order, with contacting of the components taking place within the inflatable packer.
  • the present invention also contemplates that the polymeric component and the activator component may be provided to the inflatable packer at the same time unmixed, with contacting of the components taking place within the inflatable packer.
  • the present invention optionally provides for the utilization of weighting agent additives to the first component or the second component, or to the resultant combined system, to change the density of the mixed system.
  • Suitable additives to change the density include metal salts, preferably calcium chloride.
  • Other examples of weighting agents include sand, barite, hemitite, calcium carbonate, FeO, MgO, and manganese ore. Sufficient amounts of the additive are utilized to achieve the desired density.
  • first and/or second component may be incorporated into the first and/or second component, or added before, along with, or after the introduction of the first and/or second component, non-limiting examples of which include surfactants, surface bond enhancers (non-limiting examples include styrene butadiene latex, polyvinal alcohols, and other adhesives), emulsifiers, ph control agents, fluid loss additives, gas prevention additive, dispersants, expanding agents, and wetting agents.
  • surfactants include surface bond enhancers (non-limiting examples include styrene butadiene latex, polyvinal alcohols, and other adhesives), emulsifiers, ph control agents, fluid loss additives, gas prevention additive, dispersants, expanding agents, and wetting agents.
  • surface bond enhancers non-limiting examples include styrene butadiene latex, polyvinal alcohols, and other adhesives
  • emulsifiers include emulsifiers, ph control agents, fluid

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  • Environmental & Geological Engineering (AREA)
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  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Consolidation Of Soil By Introduction Of Solidifying Substances Into Soil (AREA)

Abstract

L'invention concerne un procédé de gonflage d'un élément de garniture gonflable à l'aide d'un fluide de gonflage à deux constituants comprenant un époxy et un agent d'activation, comprenant le pompage de l'époxy et de l'agent d'activation dans l'élément de garniture gonflable pour le gonfler, puis le durcissement de l'époxy maintenant ainsi l'élément de garnissage gonflé.
PCT/US2014/034846 2013-04-20 2014-04-21 Système de gonflage d'un élément de garniture par activateur à époxy, procédés de gonflement d'un élément de garniture par un système d'activateur à époxy, élément de garniture gonflable par un activateur à époxy dans la vessie Ceased WO2014172715A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US201361814267P 2013-04-20 2013-04-20
US61/814,267 2013-04-20
US201461935245P 2014-02-03 2014-02-03
US61/935,245 2014-02-03

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WO2014172715A1 true WO2014172715A1 (fr) 2014-10-23

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Cited By (2)

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Publication number Priority date Publication date Assignee Title
CN108397176A (zh) * 2017-02-08 2018-08-14 中国石油化工股份有限公司 一种水平井注剂型分段封隔注汽管柱及工艺
US11828132B2 (en) 2022-02-28 2023-11-28 Saudi Arabian Oil Company Inflatable bridge plug

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US5488994A (en) * 1994-08-24 1996-02-06 Halliburton Company Inflation packer method and apparatus
WO2002031077A2 (fr) * 2000-10-10 2002-04-18 Henkel Kommanditgesellschaft Auf Aktien Compositions thermodurcissables a deux composants destinees a produire des adhesifs de renfort structuraux

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