WO2009106987A1 - Agents de réticulation pour la production de gels pour des applications dans des champs de pétrole - Google Patents

Agents de réticulation pour la production de gels pour des applications dans des champs de pétrole Download PDF

Info

Publication number
WO2009106987A1
WO2009106987A1 PCT/IB2009/005037 IB2009005037W WO2009106987A1 WO 2009106987 A1 WO2009106987 A1 WO 2009106987A1 IB 2009005037 W IB2009005037 W IB 2009005037W WO 2009106987 A1 WO2009106987 A1 WO 2009106987A1
Authority
WO
WIPO (PCT)
Prior art keywords
gel
gelling agent
crosslinking agent
combinations
polycarbodiimide
Prior art date
Application number
PCT/IB2009/005037
Other languages
English (en)
Inventor
David Antony Ballard
Original Assignee
M-I Drilling Fluids Uk Limited
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 M-I Drilling Fluids Uk Limited filed Critical M-I Drilling Fluids Uk Limited
Publication of WO2009106987A1 publication Critical patent/WO2009106987A1/fr

Links

Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/02—Well-drilling compositions
    • C09K8/03—Specific additives for general use in well-drilling compositions
    • C09K8/035—Organic additives
    • 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
    • C09K17/00—Soil-conditioning materials or soil-stabilising materials
    • C09K17/14—Soil-conditioning materials or soil-stabilising materials containing organic compounds only
    • C09K17/18—Prepolymers; Macromolecular compounds
    • 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
    • C09K17/00—Soil-conditioning materials or soil-stabilising materials
    • C09K17/14—Soil-conditioning materials or soil-stabilising materials containing organic compounds only
    • C09K17/18—Prepolymers; Macromolecular compounds
    • C09K17/32—Prepolymers; Macromolecular compounds of natural origin, e.g. cellulosic materials
    • 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
    • C09K8/504—Compositions based on water or polar solvents
    • C09K8/506—Compositions based on water or polar solvents containing organic compounds
    • C09K8/508—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
    • C09K8/512—Compositions based on water or polar solvents containing organic compounds macromolecular compounds containing cross-linking agents
    • 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
    • C09K8/56—Compositions for consolidating loose sand or the like around wells without excessively decreasing the permeability thereof
    • C09K8/57—Compositions based on water or polar solvents
    • C09K8/575—Compositions based on water or polar solvents containing organic compounds
    • C09K8/5751—Macromolecular compounds
    • C09K8/5756—Macromolecular compounds containing cross-linking agents

Definitions

  • Embodiments disclosed herein relate generally to gels for use in downhole oilfield applications. More particularly, embodiments disclosed herein relate to gels and methods for treating a wellbore such as methods of strengthening a wellbore.
  • Formations of this type are formations which are, at least in part, consolidated by the presence of clays in the formation. Such clays can become dispersed and expanded by the production of aqueous fluids from the formation, thereby weakening the overall formation to the point where it becomes unconsolidated or weakly consolidated with the resulting production of particulates into the wellbore.
  • uncemented, weakly consolidated or unconsolidated formations impose limits on the draw-down pressure which can be used to produce fluids from the formation. This limits the rate at which fluids can be produced from the subterranean formation.
  • lost circulation of the drilling fluid is a recurring drilling problem, characterized by loss of drilling mud into downhole formations that are fractured, highly permeable, porous, cavernous, or vugular.
  • earth formations can include shale, sands, gravel, shell beds, reef deposits, limestone, dolomite, and chalk, among others.
  • Other problems encountered while drilling and producing oil and gas include stuck pipe, hole collapse, loss of well control, and loss of or decreased production. Induced mud losses may also occur when the mud weight, required for well control and to maintain a stable wellbore, exceeds the fracture resistance of the formations.
  • one method to increase the production of a well is to perforate the well in a number of different locations, either in the same hydrocarbon bearing zone or in different hydrocarbon bearing zones, and thereby increase the flow of hydrocarbons into the well.
  • the problem associated with producing from a well in this manner relates to the control of the flow of fluids from the well and to the management of the reservoir. For example, in a well producing from a number of separate zones (or from laterals in a multilateral well) in which one zone has a higher pressure than another zone, the higher pressure zone may disembogue into the lower pressure zone rather than to the surface.
  • perforations near the "heel" of the well i.e., nearer the surface, may begin to produce water before those perforations near the "toe” of the well.
  • the production of water near the heel reduces the overall production from the well.
  • a cement or gel to isolate one zone from another in managing a hydrocarbon reservoir.
  • embodiments disclosed herein relate to a process for treating an earth formation that includes injecting a gelling agent having at least one active hydrogen into the earthen formation; injecting a polycarbodiimide crosslinking agent into the earthen formation; and allowing the gelling agent and the polycarbodiimide crosslinking agent to form a gel.
  • embodiments disclosed herein relate to a gel that includes the reaction product of a gelling agent and a polycarbodiimide crosslinking agent; wherein the gelling agent comprises at least one of a lignin, a lignosulfonate, a tannin, a tannic acid, a modified lignin, a modified lignosulfonate, a modified tannin, a modified tannic acid, biopolymers, starches, carboxy methyl cellulose, polyacrylates, polyacrylamides, polyamines, alloxylated amines, poly vinyl amines, polyethylene imines, and combinations thereof.
  • the gelling agent comprises at least one of a lignin, a lignosulfonate, a tannin, a tannic acid, a modified lignin, a modified lignosulfonate, a modified tannin, a modified tannic acid, biopolymers, starches, carboxy methyl cellulose, polyacrylates, polyacrylamide
  • embodiments disclosed herein relate to gels formed from carbodiimide crosslinking agents. In other aspects, embodiments disclosed herein relate to processes for making such gels, and applications in which the gels disclosed herein may be useful.
  • a gel is a colloidal system in which an extended porous network of interconnected molecules spans the volume of a liquid medium. Although gels appear to be solid, jelly-like materials, by weight, gels are mostly liquid.
  • the gels of the present disclosure may be used in downhole applications as a component of drilling mud and may be preformed and pumped downhole. Alternatively, reactants or components may be introduced simultaneously or sequentially downhole forming the gel in situ. For example, the components may be pumped into a wellbore which traverses a loosely consolidated formation, and allowed to cure, thereby forming a polymeric network which stabilizes the formation and the wellbore as a whole.
  • the polycarbodiimide crosslinking agent and a gelling agent (the material to be crosslinked) having an active hydrogen functional group may be reacted to form a gel.
  • the gelling agent may be dissolved in water to form a solution, and a crosslinking agent may be added to the solution, reacting with the gelling agent to form a gel.
  • the pH of the solution may be adjusted to effect or enhance gel formation.
  • the desired gel may be achieved by exposing a gelling agent having at least one active hydrogen functional group and a polycarbodiimide crosslinking agent.
  • active hydrogen compound refers to a compound that will give up or transfer a hydrogen atom to another substance, such as amine, carboxylic acid, sulfonic acid, phosphoric acid, or hydroxyl groups.
  • the reaction between a carbodiimide and an active hydrogen compound proceeds by the addition of the active hydrogen bond to one of the carbon-nitrogen double bonds as shown below in Eq. 1 :
  • the type of active hydrogen compound may have some bearing on whether any further reaction occurs.
  • a carboxylic acid reacting with a carbodiimide upon the addition reaction between the carbodiimide and the carboxylic acid, the following the addition reaction may result in a less stable O- isoacylurea, which may then rearrange to form a more stable N-acylurea, as shown in Eq. 2 below:
  • Such polycarbodiimide compounds may be used alone or two or more of them may be used in combination.
  • Such polycarbodiimide compounds containing two or more carbodiimide groups may be formed by subjecting a polyisocyanate compound (containing at least two isocyanate groups) to decarboxylation in an organic solvent in the presence of a carbodiimide formation catalyst.
  • polyisocyanates which may be used include aliphatic, alicyclic, aromatic or araliphatic diisocyanate compounds.
  • Aliphatic polyisocyanates may include hexamethylene diisocyanate, trimethylhexamethylene diisocyanate, dimeric acid diisocyanate, lysine diisocyanate and the like, and biuret-type adducts and isocyanurate ring adducts of these polyisocyanates.
  • Alicyclic diisocyanates may include isophorone diisocyanate, 4,4'-methylenebis(cyclohexylisocyanate), methylcyclohexane-2,4- or -2,6-diisocyanate, 1,3- or 1,4- di(isocyanatomethyl)cyclohexane, 1 ,4-cyclohexane diisocyanate, 1,3-cyclopentane diisocyanate, 1 ,2-cyclohexane diisocyanate, and the like, and biuret-type adducts and isocyanurate ring adducts of these polyisocyanate.
  • Aromatic diisocyanate compounds may include xylylene diisocyanate, metaxylylene diisocyanate, tetramethylxylylene diisocyanate, tolylene diisocyanate, 4,4'-diphenylmethane diisocyanate, 1,5- naphthalene diisocyanate, 1,4-naphthalene diisocyanate, 4,4'-toluydine diisocyanate, 4,4'-diphenyl ether diisocyanate, m- or p-phenylene diisocyanate, 4,4'-biphenylene diisocyanate, 3,3'-dimethyl-4,4'-biphenylene diisocyanate, bis(4-isocyanatophenyl)- sulfone, isopropylidenebis (4-phenylisocyanate), and the like, and biuret type adducts and isocyanurate ring adducts of these
  • Polyisocyanates having three or more isocyanate groups per molecule may include, for example, triphenylmethane- 4,4',4"-triisocyanate, 1,3,5-triisocyanato-benzene, 2,4,6-triisocyanatotoluene, 4,4'- dimethyldiphenylmethane-2,2',5,5'-tetraisocyanate, and the like, biuret type adducts and isocyanurate ring adducts of these polyisocyanates.
  • isocyanate compounds used herein may include urethanation adducts formed by reacting hydroxyl groups of polyols such as ethylene glycol, propylene glycol, 1 ,4-butylene glycol, dimethylolpropionic acid, polyalkylene glycol, trimethylolpropane, hexanetriol, and the like with the polyisocyanate compounds, and biuret type adducts and isocyanurate ring adducts of these polyisocyanates.
  • polyols such as ethylene glycol, propylene glycol, 1 ,4-butylene glycol, dimethylolpropionic acid, polyalkylene glycol, trimethylolpropane, hexanetriol, and the like
  • polyisocyanate compounds such as ethylene glycol, propylene glycol, 1 ,4-butylene glycol, dimethylolpropionic acid, polyalkylene glycol, trimethylolpropane, hexa
  • isocyanate compounds may include tetramethylene diisocyanate, toluene diisocyanate, hydrogenated diphenylmethane diisocyanate, hydrogenated xylylene diisocyanate, and trimers of these isocyanate compounds; terminal isocyanate group-containing compounds obtained by reacting the above isocyanate compound in an excess amount and a low molecular weight active hydrogen compounds (e.g., ethylene glycol, propylene glycol, trimethylolpropane, glycerol, sorbitol, ethylenediamine, monoethanolamine, diethanolamine, triethanolamine etc.) or high molecular weight active hydrogen compounds such as polyesterpolyols, polyetherpolyols, polyamides and the like may be used in embodiments disclosed herein.
  • a low molecular weight active hydrogen compounds e.g., ethylene glycol, propylene glycol, trimethylolpropane, glycerol, sorbitol, ethylene
  • polyisocyanates include, but are not limited to 1,2- ethylenediisocyanate, 2,2,4- and 2,4,4-trimethyl-l,6-hexamethylenediisocyanate, 1,12-dodecandiisocyanate, omega, omega-diisocyanatodipropylether, cyclobutan-1,3- diisocyanate, cyclohexan-1,3- and 1 ,4-diisocyanate, 2,4- and 2,6-diisocyanato-l- methylcylcohexane, 3-isocyanatomethyl-3,5,5-trimethylcyclohexylisocyanate
  • isophoronediisocyanate 2,5- and 3,5-bis-(isocyanatomethyl)-8-methyl-l,4- methano, decahydronaphthathalin, 1,5-, 2,5-, 1,6- and 2,6-bis-(isocyanatomethyl)-4,7- methanohexahydroindan, 1,5-, 2,5-, 1,6- and 2,6-bis-(isocyanato)-4,7- methanohexahydroindan, dicyclohexyl-2,4'- and -4,4'-diisocyanate, omega, omega- diisocyanato-l,4-diethylbenzene, 1,3- and 1 ,4-phenylenediisocyanate, 4,4'- diisocyanatodiphenyl, 4,4'-diisocyanato-3,3'-dichlorodiphenyl, 4,4'-diisocyanato- 3 ,3 ' '
  • polyisocyanates may include: 1,8-octamethylenediisocyanate;
  • 1,11 -undecane-methylenediisocyanate 1 , 12-dodecamethylendiisocyanate; 1 - isocyanato-3 -isocyanatomethyl-3 ,5,5-trimethylcyclohexane; 1 -isocyanato- 1 -methyl - 4(3)-isocyanatomethylcyclohexane; l-isocyanato-2-isocyanatomethylcyclopentane; (4,4'- and/or 2,4'-) diisocyanato-dicyclohexylmethane; bis-(4-isocyanato-3-methylcyc- lohexyl)-methane; a,a,a',a'-tetramethyl-l,3- and/or -1,4-xylylenediisocyanate; 1,3- and/or 1,4-hexahydroxylylene-diisocyanate; 2,4- and/or 2,6-hexahydrotol
  • Polyisocyanates may also include aliphatic compounds such as trimethylene, pentamethylene, 1 ,2-propylene, 1 ,2-butylene, 2,3-butylene, 1,3-butylene, ethylidene and butylidene diisocyanates, and substituted aromatic compounds such as dianisidine diisocyanate, 4,4'-diphenylether diisocyanate and chlorodiphenylene diisocyanate.
  • aliphatic compounds such as trimethylene, pentamethylene, 1 ,2-propylene, 1 ,2-butylene, 2,3-butylene, 1,3-butylene, ethylidene and butylidene diisocyanates
  • substituted aromatic compounds such as dianisidine diisocyanate, 4,4'-diphenylether diisocyanate and chlorodiphenylene diisocyanate.
  • polyisocyanate compound from which a polycarbodiimide may be derived is intended to be placed on the gels of the present disclosure. It is also appreciated that one or more polyisocyanates may be used in accordance with some embodiments of the present disclosure.
  • the decarbonation condensation reaction between the one or more polycarbodiimides it may also be desirable to include a monofunctional water- soluble or dispersible organic compound of component to impart solubility or dispersibility in water to the polycarbodiimide compound being formed, depending on the type of gel desired to be formed (aqueous gel or non-aqueous gel).
  • the compound should be one which has monofunctionality and can react with the terminal isocyanate groups of the polycarbodiimide compound derived from the isocyanate as discussed above to block the terminal groups.
  • Such water-soluble or water-dispersible organic compounds may be any compounds which have one group capable of reacting with an isocyanate group, e.g., a hydroxyl group, carboxylic acid group, amine group or sulfonyl group, and which are soluble or dispersible in water.
  • an isocyanate group e.g., a hydroxyl group, carboxylic acid group, amine group or sulfonyl group
  • such compounds may include monoalkyl esters and monoalkyl ethers of bifunctional, water-soluble or water-dispersible organic compounds having preferably OH groups at terminal ends thereof, e.g., polyethylene glycol, polypropylene glycol and the like, and monofunctional organic compounds having a cationic functional group (e.g., a group containing nitrogen) or an anionic functional group (e.g., a group containing a sulfonyl group).
  • a cationic functional group e.g., a group containing nitrogen
  • anionic functional group e.g., a group containing a sulfonyl group
  • Specific examples may include polyethylene glycol monomethyl ether, polypropylene glycol monomethyl ether, and the like.
  • a monoisocyanate may be used at the terminal ends of the carbodiimide, and that such ends may also be blocked with blocking agents, as known in the art.
  • Organic solvents which may be used to form such carbodiimides are ones having a high boiling point and having no active hydrogen atom reactive with the isocyanate compound or the carbodiimide group-containing compound formed.
  • such solvents may include aromatic hydrocarbons such as toluene, xylene and diethylbenzene; glycol ether esters such as diethylene glycol diacetate, dipropylene glycol dibutyrate, hexylene glycol diacetate, glycol diacetate, methylglycol acetate, ethylglycol acetate, butylglycol acetate, ethyldiglycol acetate and butyldiglycol acetate; ketones such as ethyl butyl ketone, acetophenone, propiophenone, diisobutyl ketone and cyclohexanone; and aliphatic esters such as amyl acetate, propyl propionate,
  • examples of carbodiimide formation catalyst may include any known in the art, including phospholenes, phospholene oxides and so forth.
  • U.S. Patent Nos. 5,958,516, 6,124,398, 5,688,875, and 5,360,933 disclose the synthesis and use of various carbodiimides, which are herein incorporated by reference in their entirety.
  • examples of commercially available polycarbodiimides that may be used as crosslinking agents include those sold under the tradename Carbodilite V- Series from Nisshinbo Industries, Inc. (Chiba, Japan).
  • the gelling agent For reaction between a gelling agent and a polycarbodiimide crosslinking agent to occur, the gelling agent must contain at least one functional group reactive with a carbodiimide.
  • carbodiimides are reactive with functional groups having an active hydrogen, i.e., a hydrogen available to be given up or transfered to another substance (the carbodiimide), such as amine, carboxylic acid, sulfonic acid, phosphoric acid, or hydroxyl groups.
  • an active hydrogen group reactive with a carbodiimide there is no limit on the type of materials that may be crosslinked with the carbodiimides, so long as they (or a modified version thereof) contain(s) an active hydrogen group reactive with a carbodiimide.
  • the gelling agents that may be crosslinked with the polycarbodiimide crosslinking agents of the present disclosure may include a wide variety of compounds, including conventional gelling agents, as well as compounds not typically used as gelling agents in downhole application.
  • gelling agents may include lignins, lignosulfonates, tannins, tannic acids, modified versions thereon (such as to include higher phenol content or active hydrogen content, e.g., amine functional groups, etc.) and combinations thereof.
  • Such types of gelling agents are frequently used in downhole applications; however, they have been conventionally crosslinked with crosslinking agents such as bichromate, epichlorohydrin, and aldehydes, etc., which are not considered to be environmentally acceptable due to the relatively high toxicity of the crosslinking agents, while more environmentally acceptable crosslinking agent may not provide the desired gel strength.
  • gelling agents suitable for use in the present disclosure may include biopolymers including starches, celluloses, chitin, alginates or other gums, etc., and synthetic polymers such as polyacrylates, polyacrylamides, polyols, polyamines, polyesters, polyurethanes, polyvinylalcohols, combinations thereof, and copolymers thereof, etc.
  • Suitable starches may include natural starches, chemically modified starches, and mixtures of one or more natural and/or chemically modified starches. Natural starches may include those of potato, wheat, tapioca, rice, corn, and roots having a high starch content, among others. Chemically modified starches may include carboxymethyl starch, hydroxyethyl starch, hydroxypropyl starch, acetate starch, sulfamate starch, phosphate-modified starch, nitrogen-modified starch, and dextrin, among others.
  • Suitable cellulosic materials may include cellulose or derivatives thereof including hydroxyethyl cellulose, carboxymethyl cellulose, hydroxypropyl methyl cellulose, etc.
  • suitable synthetic polymers include, for example, polyacrylates, polyacrylamides, polyols, polyamines, polyesters, polyurethanes, polyvinylalcohols, etc.
  • Aliphatic polyols useful in preparing polyurethane gels may have a molecular weight of 62 up to 2000 and include, for example, monomeric and polymeric polyols having two or more hydroxyl groups.
  • the monomeric polyols include ethylene glycol, propylene glycol, butylene glycol, hexamethylene glycol, cyclohexamethylenediol 1,1,1-trimethylolpropane, pentaerythritol, and the like.
  • polymeric polyols examples include the polyoxyalkylene polyols (i.e., the diols, triols, and tetrols), the polyester diols, triols, and tetrols of organic dicarboxylic acids and polyhydric alcohols, and the polylactone diols, triols, and tetrols having a molecular weight of 106 to about 2000.
  • polyoxyalkylene polyols i.e., the diols, triols, and tetrols
  • polyester diols, triols, and tetrols of organic dicarboxylic acids and polyhydric alcohols
  • polylactone diols, triols, and tetrols having a molecular weight of 106 to about 2000.
  • Suitable polyols include: glycerine monoalkanoates (e.g., glycerine monostearates); dimer fatty alcohols; diethylene glycol; triethylene glycol; tetraethylene glycol; 1,4- dimethylolcyclohexane; dodecanediol; bisphenol-A; hydrogenated bisphenol A; 1,3- hexanediol; 1,3-octanediol; 1,3-decanediol; 3-methyl-l,5-pentanediol; 3,3-dimethyl- 1,2-butanediol; 2-methyl-l,3-pentanediol; 2-methyl-2,4-pentanediol; 3- hydroxymethyl-4-heptanol; 2-hydroxymethyl-2,3-dimethyl-l -pentanol; glycerine; trimethylol ethane; trimethylol propane; trimerized fatty alcohol
  • Suitable hydroxy-functional esters may be prepared by the addition of the above-mentioned polyols with epsilon- caprolactone or reacted in a condensation reaction with an aromatic or aliphatic diacid. These polyols may be reacted with any of the isocyanates described above. Further, in addition to such polyols, one skill in the art would appreciate that polyurethane prepolymers formed from isocyanates and polyols may also be reacted with the polycarbodiimide crosslinking agents to form a gel in accordance with the present disclosure.
  • Aliphatic polyamines useful in preparing polyureas may have a molecular weight of 60 to 2000 and include monomeric and polymeric primary and secondary aliphatic amines having at least two amino groups.
  • alkylene diamines such as ethylene diamine; 1,2-diaminopropane; 1,3-diaminopropane; 2,5- diamino-2,5-dimethylhexane; 1,11-diaminoundecane; 1,12-diaminododecane; piperazine, as well as other aliphatic polyamines such as polyethylenimines (PEI), which are ethylenediamine polymers and are commercially available under the trade name Lupasol® from BASF (Germany).
  • PEI polyethylenimines
  • LUPASOL® PEIs may vary in degree of branching and therefore may vary in degree of crosslinking.
  • LUPASOL® PEIs may be small molecular weight constructs such as LUPASOL ® FG with an average molecular weight of 800 or large molecular weight constructs such as LUPASOL® SK with average molecular weight of 2,000,000.
  • Cycloaliphatic diamines suitable for use may include those such as isophoronediamine; ethylenediamine; 1 ,2-propylenediamine; 1,3-propylenediamine; N-methyl-propylene- 1,3 -diamine; 1 ,6-hexamethylenediamine; 1 ,4-diaminocyclohexane; 1 ,3-diaminocyclohexane; N,N'-dimethylethylenediamine; and 4,4'-dicyclohexyl-methanediamine for example, in addition to aromatic diamines, such as 2,4-diaminotoluene; 2,6-diaminotoluene; 3,5-diethyl-2,4-diaminotoluene; and 3,5-diethyl-2,6-diaminotoluene for example; and primary, mono-, di-, tri- or tetraalkyl-substituted 4,4'-
  • the aliphatic amine may be a polyetheramine such as those commercially available under the trade name JEFF AMINE® Huntsman Performance Products (Woodlands, TX).
  • useful JEFFAMINE ® products may include triamines JEFFAMINE ® T-5000 and JEFFAMINE ® T-3000 or diamines such as JEFFAMINE ® D-400 and JEFFAMINE ® D-2000.
  • Useful polyetheramines may possess a repeating polyether backbone and may vary in molecular weight from about 200 to about 5000 g/mol.
  • hydrazino comounds such as adipic dihydrazide or ethylene dihydrazine may be used, as may also, alkanolamines such as ethanolamine, diethanolamine, and tris(hydroxyethy)ethylenediamine.
  • the polyamine may be a polyethylenimine (PEI), which are ethylenediamine polymers and are commercially available under the trade name Lupasol® from BASF (Germany). PEIs may vary in degree of branching and therefore may vary in degree of crosslinking.
  • various carboxylate containing polymers may include such as polymers as polyacrylates (formed from monomers such as acrylic acid, itaconic acid, maleic acid, fumaric acid, and chrotonic acid or an anhydride thereof with an acrylic ester such as methyl acrylate, ethyl acrylate, butyl acrylate, 2-ethylhexyl acrylate, and 2-hydroxyethyl acrylate, methyl methacrylate, and TMPTA with a non-acrylic acid comonomer such as acrylamide and acrylonitrile, and optionally ⁇ -methylstyrene, vinyl acetate or the like), polyesters (formed by a monoesterification reaction between glycol or polyester glycol terminated with a hydroxyl group and tetracarboxylic acid dianhydride to thereby extend the chain), polyaspartates (which also contain amides), and polylacetates, amide containing polymers such as polyacrylamide, in addition to other
  • an aliphatic base fluid such as a long chain ester of acrylic or methacrylic acid, a vinyl ester of a long chain acid, a vinyl alkyl ether, ethylene, propylene, butadiene or isoprene, a hydroxyl group-containing long chain fatty acid, poly-t-butyl styrene terminated with amine, hydroxyl, carboxyl or unsaturated groups, or polyisobutylene, polybutadiene or polyisoprene terminated with amine, hydroxyl or carboxyl groups.
  • a longer chain compound such as a long chain ester of acrylic or methacrylic acid, a vinyl ester of a long chain acid, a vinyl alkyl ether, ethylene, propylene, butadiene or isoprene, a hydroxyl group-containing long chain fatty acid, poly-t-butyl styrene terminated with amine, hydroxyl, carboxyl or unsaturated groups, or
  • base fluid includes aromatic hydrocarbons
  • somewhat shorter chain analogs of these polymers may be employed, such as polymers of methyl or ethoxyethyl methacrylate, ethyl acrylate, styrene or vinyl toluene.
  • base fluid is weakly polar, e.g., a higher alcohol, ketone or ester
  • suitable solvatable components include aliphatic polyethers, polyesters from short-chain difunctional acids and alcohols, short-chain alcohol esters of acrylic or methacrylic acids, and polymers of short-chain hydroxy-acids.
  • the polymer may include polymers of acrylic or methacrylic acids, ethylene oxide or vinyl pyrrolidone, polyvinyl alcohol or polymers of glycerol or glycol monomethacrylates.
  • a synthetic polymer may be formed from comonomers possessing functional groups such as hydroxyl, cishydroxyl, carboxyl, sulfate, sulfonate, amino or amide.
  • comonomers including, for example, vinyl phosphonic acid, vinyl phosphoric acid, vinyl sulfonic acid, vinyl sulfuric acid, vinyl arsonic acid, vinyl arsenic acid, vinyl selenonic acid, vinyl selenic acid, vinyl benzoic acid, acrylic acid, or derivatives thereof, including salts and esters (mono or bis) derivatives thereof and styrene derivatives thereof, so that desired crosslinking with carbodiimides may occur.
  • combinations of any of the above listed materials to be crosslinked may be used.
  • the crosslinking agent may be present in an amount effective to crosslink the gelling agent.
  • the crosslinking agent may be used in an amount ranging from about 0.05 to about 50 weight percent based on the total weight of the gelling agent(s).
  • the crosslinking agent may be used in an amount ranging from about 5 to about 40 weight percent based on the total weight of the gelling agent(s); from about 10 to about 35 weight percent in yet other embodiments.
  • a weight ratio of the crosslinking agent to the gelling agent may be from 1 :2000 to 1 :1 ; from 1 :20 to 1 :2 in other embodiments, and from 1 :10 to about 1 :3 in yet other embodiments.
  • the amount of crosslinking agent may affect the hardness of the resulting gel.
  • the gelling agent and the crosslinking agent may be reacted at a temperature from -50 to 300 0 C. In other embodiments, the gelling agent and the crosslinking agent may be reacted at a temperature from 25 to 250°C; from 50 to 150 0 C in other embodiments; and from 60 to 100 0 C in yet other embodiments. In certain embodiments, the reaction temperature determines the amount of time required for gel formation.
  • Embodiments of the gels disclosed herein may be formed by mixing a gelling agent with a crosslinking agent.
  • a gel may form immediately upon mixing the gelling agent and the crosslinking agent.
  • a gel may form within 1 minute of mixing; within 5 minutes of mixing in other embodiments; within 30 minutes of mixing in other embodiments.
  • a gel may form within 1 hour of mixing; within 8 hours in other embodiments; within 16 hours in other embodiments; within 80 hours in other embodiments; within 120 hours in yet other embodiments.
  • the gelling agent and the crosslinking agent may be reacted in a medium having a pH greater than 4. In other embodiments, the gelling agent and the crosslinking agent may be reacted in a medium having a pH greater than 6; a pH greater than 7 in other embodiments; a pH greater than 8 in other embodiments; a pH greater than 9 in yet other embodiments.
  • Reagents which may be used to adjust the pH may include alkali metal hydroxides, such as sodium hydroxide, potassium hydroxide, calcium hydroxide, and rubidium hydroxide, lithium hydroxides, benzyltrimethylammonium hydroxides, and the partially neutralized salts of organic acids, such as tri-sodium ethylenediaminetetraacetic acid.
  • the alkali metal hydroxide, pH adjusting agent, or buffer may act as a catalyst, effecting or enhancing the crosslinking reaction between the gelling agent and the crosslinking agent.
  • a solution of gelling agent(s) and crosslinking agent(s) in water may initially have a viscosity similar to that of water.
  • a water-like viscosity may allow the solution to effectively penetrate voids, small pores, and crevices, such as encountered in fine sands, coarse silts, and other formations.
  • the viscosity may be varied to obtain a desired degree of flow sufficient for decreasing the flow of water through or increasing the load-bearing capacity of a formation.
  • the viscosity of the solution may be varied by increasing or decreasing the amount of water relative to the crosslinking and gelling agents, by employing viscosifying agents, or by other techniques common in the art.
  • the combined amount of gelling agents and crosslinking agents may range from 0.5 to 100 weight percent, based upon the total weight of water in the solution. In other embodiments, the combined amount of gelling agents and crosslinking agents may range from 5 to 100 weight percent, based upon the total weight of water in the solution; from 20 to 70 weight percent in other embodiments; from 25 to 65 weight percent in yet other embodiments. As used herein, total weight of water is exclusive of any additional water added with pH adjusting reagents.
  • the gelling agent and the crosslinking agent may react to form gel beads.
  • bead formation may be effected by agitation of the solution.
  • bead formation may be effected by forming an emulsion or suspension of the reactants in water.
  • an emulsion or suspension may be formed using an organic solvent, emulsifying agents, or combinations thereof.
  • the reaction of the gelling agent and the crosslinking agent may produce gels having a consistency ranging from a viscous sludge to a hard gel.
  • the reaction of the gelling agent and the crosslinking agent may result in a soft elastic gel.
  • the reaction may result in a good gel; in a hard gel in yet other embodiments.
  • the hardness of the gel is the force necessary to break the gel structure, which may be quantified by measuring the force required for a needle to penetrate the crosslinked structure. Hardness is a measure of the ability of the gel to resist to an established degree the penetration of a weighted test needle.
  • Hardness may be measured by using a Brookfield QTS-25 Texture Analysis
  • This instrument consists of a probe of changeable design that is connected to a load cell.
  • the probe may be driven into a test sample at specific speeds or loads to measure the following parameters or properties of a sample: springiness, adhesiveness, curing, breaking strength, fracturability, peel strength, hardness, cohesiveness, relaxation, recovery, tensile strength burst point, and spreadability.
  • the hardness may be measured by driving a 2.5mm diameter, cylindrical, flat faced probe into the gel sample at a constant speed of 30 mm per minute. When the probe is in contact with the gel, a force is applied to the probe due to the resistance of the gel structure until it fails, which is recorded via the load cell and computer software. As the probe travels through the sample, the force on the probe and the depth of penetration are measured. The force on the probe may be recorded at various depths of penetration, such as 20, 25, and 30mm, providing an indication of the gel's overall hardness.
  • the resulting gel may have a hardness value from 10 to
  • the resulting gel may be a soft elastic gel having a hardness value in the range from 10 to 100 gram-force. In other embodiments, the resulting gel may be a firm gel having a hardness value from 100 to 500 gram-force. In other embodiments, the resulting gel may range from hard to tough, having a hardness value from 500 to 100000 gram- force; from 1500 to 75000 gram-force in other embodiments; from 2500 to 50000 gram-force in yet other embodiments; from 5000 to 30000 gram-force in yet other embodiments. [0059] In other embodiments, the hardness of the gel may vary with the depth of penetration.
  • the gel may have a hardness of 1500 gram-force or greater at a penetration depth of 20 mm in some embodiments. In other embodiments, the gel may have a hardness of 5000 gram-force or greater at a penetration depth of 20 mm; 15,000 gram-force or greater at a penetration depth of 20 mm in other embodiments; and 25000 gram- force or greater at a penetration depth of 25 mm in yet other embodiments.
  • Some embodiments of the gels disclosed herein may be formed in a one- solution single component system, where the crosslinking agent(s) are premixed with the gelling agent (material to be crosslinked). The gel may then be placed or injected prior to cure. The gel times may be adjusted by changing the quantity of water (or other solvent) in the solution.
  • Other embodiments of the gels disclosed herein may also be formed in a two-component system, where the crosslinking and gelling agents may be mixed separately and combined immediately prior to injection.
  • one reagent, the crosslinking or gelling agent may be placed in the wellbore or the near-wellbore region where it may then be contacted by the other reagent, either the crosslinking or gelling agent as required.
  • Embodiments of the gels disclosed herein may be used in applications including: as an additive in drilling muds; as an additive for enhancing oil recovery (EOR); as one additive in loss circulation material (LCM) pills; wellbore (WB) strengthening treatments; soil stabilization; as a dust suppressant; as a water retainer or a soil conditioner; as hydrotreating (HT) fluid loss additives, and others.
  • EOR oil recovery
  • LCM loss circulation material
  • WB wellbore
  • soil stabilization as a dust suppressant
  • HT hydrotreating
  • Drilling fluids or muds typically include a base fluid (for example water, diesel or mineral oil, or a synthetic compound), weighting agents (for example, barium sulfate or barite may be used), bentonite clay, and various additives that serve specific functions, such as polymers, corrosion inhibitors, emulsifiers, and lubricants.
  • a base fluid for example water, diesel or mineral oil, or a synthetic compound
  • weighting agents for example, barium sulfate or barite may be used
  • bentonite clay various additives that serve specific functions, such as polymers, corrosion inhibitors, emulsifiers, and lubricants.
  • the mud is injected through the center of the drill string to the drill bit and exits in the annulus between the drill string and the wellbore, fulfilling, in this manner, the cooling and lubrication of the bit, casing of the well, and transporting the drill cuttings to the surface.
  • the gels disclosed herein may be used as an additive in drilling mud.
  • the gels may form a filter cake or one component of a filter cake that forms along the wellbore as drilling progresses.
  • the gels contained in the drilling fluid may be deposited along the wellbore throughout the drilling process, potentially strengthening the wellbore by stabilizing shale formations and other sections encountered while drilling. Improved wellbore stability may reduce the occurrence of stuck pipe, hole collapse, hole enlargement, lost circulation, and may improve well control.
  • Wellbore stability may also be enhanced by the injection of a low viscosity mixture of a gelling agent and a crosslinking agent into formations along the wellbore.
  • the mixture may then continue to react, strengthening the formation along the wellbore upon gellation of the mixture.
  • the gels disclosed herein may aid in lifting solid debris from tubing walls and through the tubing annulus. Hard gels circulating through the drill pipe during drilling may scrape and clean the drill pipe, removing any pipe scale, mud, clay, or other agglomerations that may have adhered to the drill pipe or drill tubing. In this manner, the drill pipe may be maintained free of obstructions that could otherwise hinder removal of drilled solids from the drill pipe during drilling. [0069] Enhanced Oil Recovery
  • Embodiments of the gels disclosed herein may be used to enhance secondary oil recovery efforts.
  • secondary oil recovery it is common to use an injection well to inject a treatment fluid, such as water or brine, downhole into an oil-producing formation to force oil toward a production well.
  • a treatment fluid such as water or brine
  • Thief zones and other permeable strata may allow a high percentage of the injected fluid to pass through only a small percentage of the volume of the reservoir, for example, and may thus require an excessive amount of treatment fluid to displace a high percentage of crude oil from a reservoir.
  • embodiments of the gels disclosed herein may be injected into the formation. Gels injected into the formation may partially or wholly restrict flow through the highly conductive zones. In this manner, the gels may effectively reduce channeling routes through the formation, forcing the treating fluid through less porous zones, and potentially decreasing the quantity of treating fluid required and increasing the oil recovery from the reservoir.
  • gels may also be formed in situ within the formation to combat the thief zones.
  • Gelling agents may be injected into the formation, allowing the gelling agents to penetrate further into the formation than if a gel was injected.
  • the crosslinking agents may then be injected, causing the previously injected gelling agents to crosslink within the formation.
  • gels disclosed herein may be used as one component in a drilling fluid.
  • the gels may form part of a filter cake, minimizing seepage of drilling fluids to underground formations and lining the wellbore.
  • embodiments of the gels disclosed herein may be used as one component in loss circulation material (LCM) pills that are used when excessive seepage or circulation loss problems are encountered, requiring a higher concentration of loss circulation additives.
  • LCM pills are used to prevent or decrease loss of drilling fluids to porous underground formations encountered while drilling.
  • the crosslinking agent and gelling agent / material may be mixed prior to injection of the pill into the drilled formation.
  • the mixture may be injected while maintaining a low viscosity, prior to gel formation, such that the gel may be formed downhole.
  • the gelling material and crosslinking agent may be injected into the formation in separate shots, mixing and reacting to form a gel in situ (in the formation following injection of the LCM pill shots). In this manner, premature gel formation may be avoided.
  • a first mixture containing a gelling agent may be injected into the wellbore and into the lost circulation zone.
  • a second mixture containing a crosslinking agent and/or pH modifier may be injected, causing the gelling agent to crosslink in situ to the point that the gel expands in size.
  • the expanded and hardened gel may plug fissures and thief zones, closing off the lost circulation zone.
  • Gels described herein may be used as one component of a soil stabilizer.
  • lignosulfonates may be used for stabilizing road base courses and the like.
  • Pulverized soil may be mixed and worked with the stabilizing composition in a single or multiple layer, compacting each layer as it is laid down. The compaction may be by any suitable method such as rubber-tied rollers or sheepsfoot rollers.
  • the amount of stabilizing composition used depends on the type of soil, moisture content and other factors. The exact amount of stabilizing composition and the amount of water dilution vary with soil type, moisture content and other factors.
  • Gels described herein may also be utilized for dust control, dust suppression, dust palliative treatment, road stabilization and many other dust binding applications.
  • the lignin molecule functions by adsorbing on the substrate and the binding effect results from intermolecular forces between the lignin molecule and the substrate.
  • the lignin molecule is unique as it has several different polar groups and aromatic systems. This increases the affinity of the molecule which results in improved adhesion, and makes it suitable for a wide range of substrates.
  • the binding property of lignin-based products may be utilized in many types of dust control and dust prevention, such as dust-suppression in roads, parking lots, racing tracks, quarries, paddocks, and construction sites, dust-palliative or dust prevention treatment of public and private roads, road and soil-stabilization of secondary roads and areas, sand dune and earth stabilization on areas to be kept free from dust and wind erosion, and others.
  • embodiments disclosed herein provide for the formation of a gel formed using low or non-toxic crosslinking agents. These gels have the benefit of being formed from materials that provide a better health, safety, and environmental profile as compared dichromates, aldehydes, and epichlorohydrins.
  • the crosslinking agents disclosed herein may also provide a low-cost alternative for the formation of desired gels.
  • Embodiments of the gels disclosed herein may form a soft elastic gel.
  • Other embodiments of the gels disclosed herein may form a hard gel.

Landscapes

  • Chemical & Material Sciences (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Soil Sciences (AREA)
  • Polyurethanes Or Polyureas (AREA)
  • Heterocyclic Carbon Compounds Containing A Hetero Ring Having Oxygen Or Sulfur (AREA)
  • Processes Of Treating Macromolecular Substances (AREA)

Abstract

L’invention concerne un procédé pour le traitement d’une formation qui comprend les étapes consistant à injecter un agent gélifiant, comportant au moins un atome d’hydrogène actif, dans la formation ; à injecter un agent de réticulation à base de polycarbodiimide dans la formation; et à permettre à l’agent gélifiant et à l’agent de réticulation à base de polycarbodiimide de former un gel.
PCT/IB2009/005037 2008-02-26 2009-02-05 Agents de réticulation pour la production de gels pour des applications dans des champs de pétrole WO2009106987A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US3157708P 2008-02-26 2008-02-26
US61/031,577 2008-02-26

Publications (1)

Publication Number Publication Date
WO2009106987A1 true WO2009106987A1 (fr) 2009-09-03

Family

ID=40791300

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/IB2009/005037 WO2009106987A1 (fr) 2008-02-26 2009-02-05 Agents de réticulation pour la production de gels pour des applications dans des champs de pétrole

Country Status (2)

Country Link
AR (1) AR070476A1 (fr)
WO (1) WO2009106987A1 (fr)

Cited By (9)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009006253A2 (fr) 2007-06-28 2009-01-08 M-I Llc Gels dégradables dans des applications d'isolation zonale
WO2010122302A1 (fr) * 2009-04-24 2010-10-28 Halliburton Energy Services, Inc. Procédé pour améliorer la stabilité de fluides de forage à base d'huile à des températures élevées
WO2011039544A1 (fr) * 2009-09-30 2011-04-07 M-I Drilling Fluids Uk Limited Agents de réticulation pour la fabrication de gels et de billes polymères pour applications pétrolifères
WO2011117578A1 (fr) * 2010-03-24 2011-09-29 Halliburton Energy Services, Inc. Méthodes et compositions permettant de limiter le sable dans les puits d'injection
US8936087B2 (en) 2010-03-24 2015-01-20 Halliburton Energy Services, Inc. Methods and compositions for sand control in injection wells
WO2016137608A1 (fr) * 2015-02-26 2016-09-01 Halliburton Energy Services, Inc. Composition d'agent d'étanchéité destiné à être utilisé dans des formations souterraines
US9970246B2 (en) 2012-04-09 2018-05-15 M-I L.L.C. Triggered heating of wellbore fluids by carbon nanomaterials
CN109777387A (zh) * 2019-03-05 2019-05-21 中国石油大学(华东) 一种重复压裂暂堵剂及其制备方法与应用
CN111040663A (zh) * 2019-12-27 2020-04-21 北京林业大学 一种人造板用的豆基蛋白胶黏剂及其制备方法

Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0686626A1 (fr) * 1994-06-10 1995-12-13 Nisshinbo Industries, Inc. Tétraméthylxylylènecarbodiimides hydrophiliques
EP0878496A1 (fr) * 1997-05-16 1998-11-18 Nisshinbo Industries, Inc. Agent réticulant carbodiimide, son procédé de préparation et matériau de revêtement en comprenant
US20070039732A1 (en) * 2005-08-18 2007-02-22 Bj Services Company Methods and compositions for improving hydrocarbon recovery by water flood intervention
WO2007050520A2 (fr) * 2005-10-24 2007-05-03 Bayer Materialscience Llc Compositions de polyurethane solides, et procedes de reparation d'infrastructures et de stabilisation geographique

Patent Citations (4)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
EP0686626A1 (fr) * 1994-06-10 1995-12-13 Nisshinbo Industries, Inc. Tétraméthylxylylènecarbodiimides hydrophiliques
EP0878496A1 (fr) * 1997-05-16 1998-11-18 Nisshinbo Industries, Inc. Agent réticulant carbodiimide, son procédé de préparation et matériau de revêtement en comprenant
US20070039732A1 (en) * 2005-08-18 2007-02-22 Bj Services Company Methods and compositions for improving hydrocarbon recovery by water flood intervention
WO2007050520A2 (fr) * 2005-10-24 2007-05-03 Bayer Materialscience Llc Compositions de polyurethane solides, et procedes de reparation d'infrastructures et de stabilisation geographique

Non-Patent Citations (1)

* Cited by examiner, † Cited by third party
Title
K. WAGNER ET AL: "alpha,omega-Diisocyanato-carbodiimide und -polycarbodiimide sowie ihre Derivate", ANGEWANDTE CHEMIE, vol. 93, 1981, pages 855 - 866, XP002534592 *

Cited By (13)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2009006253A2 (fr) 2007-06-28 2009-01-08 M-I Llc Gels dégradables dans des applications d'isolation zonale
WO2010122302A1 (fr) * 2009-04-24 2010-10-28 Halliburton Energy Services, Inc. Procédé pour améliorer la stabilité de fluides de forage à base d'huile à des températures élevées
WO2011039544A1 (fr) * 2009-09-30 2011-04-07 M-I Drilling Fluids Uk Limited Agents de réticulation pour la fabrication de gels et de billes polymères pour applications pétrolifères
WO2011117578A1 (fr) * 2010-03-24 2011-09-29 Halliburton Energy Services, Inc. Méthodes et compositions permettant de limiter le sable dans les puits d'injection
US8875786B2 (en) 2010-03-24 2014-11-04 Halliburton Energy Services, Inc. Methods and compositions for sand control in injection wells
US8936087B2 (en) 2010-03-24 2015-01-20 Halliburton Energy Services, Inc. Methods and compositions for sand control in injection wells
US9970246B2 (en) 2012-04-09 2018-05-15 M-I L.L.C. Triggered heating of wellbore fluids by carbon nanomaterials
WO2016137608A1 (fr) * 2015-02-26 2016-09-01 Halliburton Energy Services, Inc. Composition d'agent d'étanchéité destiné à être utilisé dans des formations souterraines
US10294406B2 (en) 2015-02-26 2019-05-21 Halliburton Energy Services, Inc. Sealant composition for use in subterranean formations
CN109777387A (zh) * 2019-03-05 2019-05-21 中国石油大学(华东) 一种重复压裂暂堵剂及其制备方法与应用
CN109777387B (zh) * 2019-03-05 2021-06-08 中国石油大学(华东) 一种重复压裂暂堵剂及其制备方法与应用
CN111040663A (zh) * 2019-12-27 2020-04-21 北京林业大学 一种人造板用的豆基蛋白胶黏剂及其制备方法
CN111040663B (zh) * 2019-12-27 2021-09-07 北京林业大学 一种人造板用的豆基蛋白胶黏剂及其制备方法

Also Published As

Publication number Publication date
AR070476A1 (es) 2010-04-07

Similar Documents

Publication Publication Date Title
WO2009106987A1 (fr) Agents de réticulation pour la production de gels pour des applications dans des champs de pétrole
CA2775996C (fr) Agents de reticulation pour la fabrication de gels et de billes polymeres pour applications petroliferes
CA2685206C (fr) Utilisation d'elastomeres afin de produire des gels en vue de traiter un puits de forage
EP2247702B1 (fr) Systèmes de gel non aqueux dégradables
US8377853B2 (en) Aqueous gels for well bore strengthening
US7727938B2 (en) Non-aqueous gels for consolidating and stabilizing wellbore formations
US8207097B2 (en) Degradable gels in zonal isolation applications
CA2754359A1 (fr) Fluide de forage de puits et procedes de traitement d'une formation terrestre
CA2783662C (fr) Utilisation d'elastomeres pour produire des gels pour le traitement d'un puits de forage
WO2010015639A1 (fr) Agents de réticulation aziridines pour la fabrication de gels non aqueux et de billes de polymère pour des applications en champ pétrolifère

Legal Events

Date Code Title Description
121 Ep: the epo has been informed by wipo that ep was designated in this application

Ref document number: 09714876

Country of ref document: EP

Kind code of ref document: A1

NENP Non-entry into the national phase

Ref country code: DE

122 Ep: pct application non-entry in european phase

Ref document number: 09714876

Country of ref document: EP

Kind code of ref document: A1