WO2002040826A1 - Well treatment process - Google Patents
Well treatment process Download PDFInfo
- Publication number
- WO2002040826A1 WO2002040826A1 PCT/GB2001/005081 GB0105081W WO0240826A1 WO 2002040826 A1 WO2002040826 A1 WO 2002040826A1 GB 0105081 W GB0105081 W GB 0105081W WO 0240826 A1 WO0240826 A1 WO 0240826A1
- Authority
- WO
- WIPO (PCT)
- Prior art keywords
- particles
- precursor
- chemical
- well
- scissile
- Prior art date
Links
- 238000011282 treatment Methods 0.000 title claims abstract description 39
- 238000000034 method Methods 0.000 title claims abstract description 14
- 239000002245 particle Substances 0.000 claims abstract description 85
- 239000000126 substance Substances 0.000 claims abstract description 50
- 239000002243 precursor Substances 0.000 claims abstract description 37
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 21
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 21
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 21
- 229920000642 polymer Polymers 0.000 claims description 21
- 230000015572 biosynthetic process Effects 0.000 claims description 20
- 239000003112 inhibitor Substances 0.000 claims description 11
- 239000000203 mixture Substances 0.000 claims description 10
- 238000004519 manufacturing process Methods 0.000 claims description 9
- 239000007788 liquid Substances 0.000 claims description 7
- 239000002455 scale inhibitor Substances 0.000 claims description 7
- 239000002253 acid Substances 0.000 claims description 6
- 150000007513 acids Chemical class 0.000 claims description 5
- 239000003795 chemical substances by application Substances 0.000 claims description 5
- 230000007797 corrosion Effects 0.000 claims description 5
- 238000005260 corrosion Methods 0.000 claims description 5
- -1 disulphide Chemical class 0.000 claims description 4
- 229910052751 metal Chemical class 0.000 claims description 4
- 239000002184 metal Chemical class 0.000 claims description 4
- 241000894006 Bacteria Species 0.000 claims description 3
- 108090000790 Enzymes Chemical class 0.000 claims description 3
- 102000004190 Enzymes Human genes 0.000 claims description 3
- 229940123973 Oxygen scavenger Drugs 0.000 claims description 2
- 150000001408 amides Chemical class 0.000 claims description 2
- 239000003139 biocide Substances 0.000 claims description 2
- 150000005690 diesters Chemical class 0.000 claims description 2
- 150000002148 esters Chemical class 0.000 claims description 2
- 239000004094 surface-active agent Substances 0.000 claims description 2
- 230000001737 promoting effect Effects 0.000 claims 1
- 239000011159 matrix material Substances 0.000 description 8
- YXFVVABEGXRONW-UHFFFAOYSA-N Toluene Chemical compound CC1=CC=CC=C1 YXFVVABEGXRONW-UHFFFAOYSA-N 0.000 description 6
- 239000003921 oil Substances 0.000 description 6
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 6
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 4
- 239000007789 gas Substances 0.000 description 4
- 239000011435 rock Substances 0.000 description 4
- 238000010504 bond cleavage reaction Methods 0.000 description 3
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 230000007017 scission Effects 0.000 description 3
- RWSOTUBLDIXVET-UHFFFAOYSA-N Dihydrogen sulfide Chemical compound S RWSOTUBLDIXVET-UHFFFAOYSA-N 0.000 description 2
- DGAQECJNVWCQMB-PUAWFVPOSA-M Ilexoside XXIX Chemical compound C[C@@H]1CC[C@@]2(CC[C@@]3(C(=CC[C@H]4[C@]3(CC[C@@H]5[C@@]4(CC[C@@H](C5(C)C)OS(=O)(=O)[O-])C)C)[C@@H]2[C@]1(C)O)C)C(=O)O[C@H]6[C@@H]([C@H]([C@@H]([C@H](O6)CO)O)O)O.[Na+] DGAQECJNVWCQMB-PUAWFVPOSA-M 0.000 description 2
- 229920001202 Inulin Polymers 0.000 description 2
- 239000000919 ceramic Substances 0.000 description 2
- 150000001875 compounds Chemical class 0.000 description 2
- 238000004132 cross linking Methods 0.000 description 2
- 230000008021 deposition Effects 0.000 description 2
- 238000009826 distribution Methods 0.000 description 2
- 239000012634 fragment Substances 0.000 description 2
- 229910052809 inorganic oxide Inorganic materials 0.000 description 2
- 239000000178 monomer Substances 0.000 description 2
- 239000003129 oil well Substances 0.000 description 2
- 238000006384 oligomerization reaction Methods 0.000 description 2
- 230000035515 penetration Effects 0.000 description 2
- 239000000377 silicon dioxide Substances 0.000 description 2
- 229910052708 sodium Inorganic materials 0.000 description 2
- 239000011734 sodium Substances 0.000 description 2
- 239000000243 solution Substances 0.000 description 2
- 239000000725 suspension Substances 0.000 description 2
- 239000001993 wax Substances 0.000 description 2
- NWUYHJFMYQTDRP-UHFFFAOYSA-N 1,2-bis(ethenyl)benzene;1-ethenyl-2-ethylbenzene;styrene Chemical compound C=CC1=CC=CC=C1.CCC1=CC=CC=C1C=C.C=CC1=CC=CC=C1C=C NWUYHJFMYQTDRP-UHFFFAOYSA-N 0.000 description 1
- DREPONDJUKIQLX-UHFFFAOYSA-N 1-[ethenyl(ethoxy)phosphoryl]oxyethane Chemical compound CCOP(=O)(C=C)OCC DREPONDJUKIQLX-UHFFFAOYSA-N 0.000 description 1
- OMPJBNCRMGITSC-UHFFFAOYSA-N Benzoylperoxide Chemical compound C=1C=CC=CC=1C(=O)OOC(=O)C1=CC=CC=C1 OMPJBNCRMGITSC-UHFFFAOYSA-N 0.000 description 1
- IMQLKJBTEOYOSI-GPIVLXJGSA-N Inositol-hexakisphosphate Chemical compound OP(O)(=O)O[C@H]1[C@H](OP(O)(O)=O)[C@@H](OP(O)(O)=O)[C@H](OP(O)(O)=O)[C@H](OP(O)(O)=O)[C@@H]1OP(O)(O)=O IMQLKJBTEOYOSI-GPIVLXJGSA-N 0.000 description 1
- ABLZXFCXXLZCGV-UHFFFAOYSA-N Phosphorous acid Chemical class OP(O)=O ABLZXFCXXLZCGV-UHFFFAOYSA-N 0.000 description 1
- IMQLKJBTEOYOSI-UHFFFAOYSA-N Phytic acid Natural products OP(O)(=O)OC1C(OP(O)(O)=O)C(OP(O)(O)=O)C(OP(O)(O)=O)C(OP(O)(O)=O)C1OP(O)(O)=O IMQLKJBTEOYOSI-UHFFFAOYSA-N 0.000 description 1
- 239000004372 Polyvinyl alcohol Substances 0.000 description 1
- 229920002125 Sokalan® Polymers 0.000 description 1
- PNEYBMLMFCGWSK-UHFFFAOYSA-N aluminium oxide Inorganic materials [O-2].[O-2].[O-2].[Al+3].[Al+3] PNEYBMLMFCGWSK-UHFFFAOYSA-N 0.000 description 1
- 150000001412 amines Chemical group 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 239000002585 base Substances 0.000 description 1
- 235000019400 benzoyl peroxide Nutrition 0.000 description 1
- 239000003124 biologic agent Substances 0.000 description 1
- 239000002775 capsule Substances 0.000 description 1
- 239000000969 carrier Substances 0.000 description 1
- 238000006243 chemical reaction Methods 0.000 description 1
- 239000003153 chemical reaction reagent Substances 0.000 description 1
- 230000021615 conjugation Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 239000003431 cross linking reagent Substances 0.000 description 1
- 239000010779 crude oil Substances 0.000 description 1
- 238000009109 curative therapy Methods 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000005553 drilling Methods 0.000 description 1
- 238000000605 extraction Methods 0.000 description 1
- 238000001914 filtration Methods 0.000 description 1
- 239000000499 gel Substances 0.000 description 1
- 239000007903 gelatin capsule Substances 0.000 description 1
- 230000007062 hydrolysis Effects 0.000 description 1
- 238000006460 hydrolysis reaction Methods 0.000 description 1
- 125000002887 hydroxy group Chemical group [H]O* 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 230000002401 inhibitory effect Effects 0.000 description 1
- 229910010272 inorganic material Inorganic materials 0.000 description 1
- 239000011147 inorganic material Substances 0.000 description 1
- 229910052816 inorganic phosphate Inorganic materials 0.000 description 1
- 229940029339 inulin Drugs 0.000 description 1
- 239000003456 ion exchange resin Substances 0.000 description 1
- 229920003303 ion-exchange polymer Polymers 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 229910052976 metal sulfide Inorganic materials 0.000 description 1
- DCUFMVPCXCSVNP-UHFFFAOYSA-N methacrylic anhydride Chemical compound CC(=C)C(=O)OC(=O)C(C)=C DCUFMVPCXCSVNP-UHFFFAOYSA-N 0.000 description 1
- 230000000813 microbial effect Effects 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 150000002978 peroxides Chemical class 0.000 description 1
- 150000003014 phosphoric acid esters Chemical class 0.000 description 1
- 229940068041 phytic acid Drugs 0.000 description 1
- 235000002949 phytic acid Nutrition 0.000 description 1
- 239000000467 phytic acid Substances 0.000 description 1
- 229920002401 polyacrylamide Polymers 0.000 description 1
- 238000006116 polymerization reaction Methods 0.000 description 1
- 229920002451 polyvinyl alcohol Polymers 0.000 description 1
- 235000019422 polyvinyl alcohol Nutrition 0.000 description 1
- 239000011148 porous material Substances 0.000 description 1
- 230000002035 prolonged effect Effects 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000013535 sea water Substances 0.000 description 1
- 150000003573 thiols Chemical group 0.000 description 1
- 231100000331 toxic Toxicity 0.000 description 1
- 230000002588 toxic effect Effects 0.000 description 1
Classifications
-
- C—CHEMISTRY; METALLURGY
- C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
- C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
- C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
- C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
- C09K8/536—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
-
- 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
- C09K8/54—Compositions for in situ inhibition of corrosion in boreholes or wells
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S507/00—Earth boring, well treating, and oil field chemistry
- Y10S507/902—Controlled release agent
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S507/00—Earth boring, well treating, and oil field chemistry
- Y10S507/939—Corrosion inhibitor
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10T—TECHNICAL SUBJECTS COVERED BY FORMER US CLASSIFICATION
- Y10T428/00—Stock material or miscellaneous articles
- Y10T428/29—Coated or structually defined flake, particle, cell, strand, strand portion, rod, filament, macroscopic fiber or mass thereof
- Y10T428/2982—Particulate matter [e.g., sphere, flake, etc.]
Definitions
- This invention relates to a method of treating a hydrocarbon well with well treatment chemicals, in particular by down-hole placement of polymeric particles carrying well treatment chemicals or precursors or generators thereof, and to such particles and compositions and structures containing them.
- hydrocarbon well i.e. a gas or oil well
- hydrocarbon flow- inhibiting deposition e.g. of scale, gas clathrates, metal sulphides, waxes, gel polymers, microbial debris, etc.
- generation of toxic hydrogen sulphide by sulphate-reducing bacteria increased water flow into the producer bore, etc.
- sea water is injected through an injection bore hole into an oil-bearing stratum to drive oil through the formation (i.e. the rock) into the producer well hole
- differences in solutes in the injection water and the water already present in the formation can cause metal salts to precipitate as scale so causing gradually increasing clogging of the producer well hole.
- the producer bore hole in an oil well is generally lined in the hydrocarbon bearing stratum with "gravel packs", sand containing filter elements, which serve to trap formation fragments and it has been proposed to include in such gravel packs ceramic particles coated with or impregnated with well treatment chemicals such as scale inhibitors (see EP-A-656459 and WO 96/27070) or bacteria (see WO 99/36667) .
- well treatment chemicals such as scale inhibitors (see EP-A-656459 and WO 96/27070) or bacteria (see WO 99/36667) .
- treatment of the formation surrounding the producer well bore hole with well treatment; chemicals before hydrocarbon production begins has also been proposed, e.g. in GB-A-2290096 and WO 99/54592.
- ion exchange resin particles see US-A- 4787455
- acrylamide polymer particles see EP-A- 193369
- gelatin capsules see US-3676363
- oligomeric matrices and capsules see US-A-4986353 and US-A- 4986354
- ceramic particles see WO 99/54592, WO 96/27070 and EP-A-656459
- particles of the well treatment chemical itself see WO 97/45625
- Particles coated or impregnated with or encapsulating a well treatment chemical however have the inherent problem that release of the well treatment chemical will take place relatively rapidly once the particles encounter water down-hole. Accordingly the protection they provide is relatively short lived.
- the present invention thus provides a method for the treatment of a hydrocarbon well which method comprises administering down said well polymeric particles having covalently bound to a polymeric component thereof a well treatment chemical or a precursor thereof, said particles containing covalent bonds scissile in an aqueous environment to release or expose said chemical or precursor.
- the invention provides polymeric particles having covalently bound to a polymeric component thereof a well treatment chemical or a precursor thereof, said particles containing covalent bonds scissile in an aqueous environment to release or expose said chemical or precursor.
- the invention provides the use for the manufacture of hydrocarbon well treatment compositions of polymeric particles having covalently bound to a polymeric component thereof a well treatment chemical or a precursor thereof, said particles containing covalent bonds scissile in an aqueous environment to release or expose said chemical or precursor.
- the invention comprises a hydrocarbon well treatment composition
- a hydrocarbon well treatment composition comprising a carrier liquid containing polymeric particles having covalently bound to a polymeric component thereof a well treatment chemical or a precursor thereof, said particles containing covalent bonds scissile in an aqueous environment to release or expose said chemical or precursor.
- the invention comprises a tubular filter for down-hole placement containing polymeric particles having covalently bound to a polymeric component thereof a well treatment chemical or a precursor thereof, said particles containing covalent bonds scissile in an aqueous environment to release or expose said chemical or precursor.
- the polymer particles may be placed down hole before and/or after hydrocarbon production (i.e. extraction of oil or gas from the well) has begun.
- hydrocarbon production i.e. extraction of oil or gas from the well
- the particles are placed down hole before production has begun, especially in the completion phase of well construction.
- the particles may be placed within the bore hole (e.g. in the hydrocarbon bearing strata or in ratholes) or within the surrounding formation (e.g. in fissures or within the rock itself) .
- the particles are conveniently contained within a tubular filter, e.g. a gravel pack or a filter structure as disclosed in EP-A-656459 or WO 96/27070; in the latter case, the particles are preferably positioned by squeezing a liquid composition containing the particles down the bore hole.
- the particles are placed both within the bore in a filter and wjithin the surrounding formation.
- the pressure used should be sufficient to cause the particles to penetrate at least lm, more preferably at least 1.5m, still more preferably at least 2m, into the formation.
- the particles may be applied in conjunction with proppant particles (e.g. as described in WO 99/54592) to achieve a penetration of up to about 100m into the formation.
- proppant particles e.g. as described in WO 99/54592
- the polymer particles of the invention may have a wide range of possible structures, several of which are illustrated schematically in the accompanying drawings.
- Figure 1 illustrates the case where the chemical or precursor is bonded via a scissile bond to the polymer matrix
- Figure 2 illustrates the case where the chemical or precusor is itself a component of a polymeric or oligomeric part of the particle which is degradable to release the chemical or precursor
- Figure 3 illustrates the case where the chemical or precursor is a releasable part of the overall polymer matrix
- Figures 4 and 5 illustrate cases where the scissile bonds are present in the backbone or cross-links of a polymer matrix to which the chemical or precursor is covalently bound, whereby bond scission breaks down the particle exposing the chemical or precursor.
- dotted lines represent scissile bonds, continuous lines polymer or oligomer backbones and X the chemical or precursor.
- the scissile bonds in the polymer particles of the invention may be any bonds subject to scission in the presence of formation or injection water under the temperature conditions experienced down hole, e.g. 70 to 150°C. Suitable such bonds include amide, ester, disulphide, diester, peroxide, etc. bonds. These bonds may be formed by conjugation of the chemical or precursor to a functionalized polymer matrix (e.g.
- the particles may be impregnated with agents which, under down-hole conditions, will promote scission of the scissile bonds, e.g. enzymes, acids, bases, metal complexes, etc.
- the rate of chemical or precursor release can accordingly be selected or controlled by selection of the properties of the particles (e.g. choice of monomer, degree of cross-linking, polymer molecular weight, particle size, porosity, nature of the scissile bonds, nature of other materials impregnated into the particles, etc.) to match properties of the down-hole environment, e.g. temperature, salinity, pH etc.
- the particles according to the invention advantageously have mode particle sizes (e.g. as measured with a Coulter particle size analyser) of 1 ⁇ m to 5 mm, more preferably 10 ⁇ m to 1000 ⁇ m, especially 250 to 800 ⁇ m.
- the mode particle size is preferably 1 to 50 ⁇ m, especially 2 to 20 ⁇ m.
- formation permeability (which correlates to the pore throat sizes in the formation) may redily be determined using rock samples taken during drilling and the optimum particle size may thus be determined. If the particles have a low dispersity (i.e. size variation), a highly uniform deposition and deep penetration into the formation can be achieved. For this reason, the particles preferably have a coefficient of variation (CV) of less than 10%, more preferably less than 5%, still more preferably less than 2%.
- CV coefficient of variation
- CV is preferably calculated on the main mode, i.e. by fitting a monomodal distribution curve to the detected particle size distribution. Thus some particles below or above mode size may be discounted in the calculation which may for example be based on about 90% of total particle number (of detectable particles that is) . Such a determination of CV is performable on a Coulter LS 130 particle size analyzer.
- the particles preferably have mode particle sizes of 50 to 5000 ⁇ m, more especially 50 to 1000 ⁇ m, still more preferably 100 to 500 ⁇ m.
- the particles preferably constitute 1 to 99% wt, more preferably 2 to 30% wt, still more preferably 5 to 20% wt of the particulate filter matrix, the remaining matrix comprising particulate oil- and water-insoluble inorganic material, preferably an inorganic oxide such as silica, alumina or alumina-silica .
- the inorganic oxide has a mode particle size which is similar to that of the polymer particles, e.g. within 20%, more preferably within 10%.
- the polymer particles preferably have low dispersity, e.g. a CV of less than 10%, more preferably less than 5%, still more preferably less than 2%.
- the low dispersity serves to hinder clogging of the filters.
- the polymer matrix of the particles has a softening point above the temperatures encountered down hole, e.g. one above 70°C, more preferably above 100°C, still more preferably above 150°C.
- the well treatment chemicals or precursors thereof which the particles contain may be any agents capable of tackling down hole problems, such as corrosion, hydrocarbon flow reduction, or H 2 S generation.
- agents include scale inhibitors, foamers, corrosion inhibitors, biocides, surfactants, oxygen scavengers , etc .
- the particles may contain a well treatment chemical itself or a precursor chemical compound which in situ will react, e.g. break down, to produce a well treatment chemical , or alternatively it may be a biological agent , e.g. an enzyme which produces a well treatment chemical.
- typical scale inhibitors include inorganic and organic phosphonates (e.g. sodium aminotrismethylenephosphonate) , polyaminocarboxylic acids, polyacrylamines, polycarboxylic acids, polysulphonic acids, phosphate esters, inorganic phosphates, polyacrylic acids, inulins (e.g. sodium carboxymethyl inulin) , phytic acid and derivatives (especially carboxylic derivatives) thereof, polyaspartates, etc.
- inorganic and organic phosphonates e.g. sodium aminotrismethylenephosphonate
- polyaminocarboxylic acids e.g. sodium aminotrismethylenephosphonate
- polyacrylamines e.g. sodium aminotrismethylenephosphonate
- polycarboxylic acids e.g. sodium aminotrismethylenephosphonate
- polysulphonic acids e.g. sodium aminotrismethylenephosphonate
- phosphate esters e.g. sodium carboxymethyl inulin
- polyacrylic acids
- Examples of preferred well treatment chemicals include: hydrate inhibitors, scale inhibitors, asphaltene inhibitors, wax inhibitors and corrosion inhibitors. Such inhibitors are well known to those working in the field of well treatment.
- the partices are placed within the formation, they are preferably applied as a dispersion in a liquid carrier.
- the liquid carrier preferably comprises a non-aqueous organic liquid, e.g. a hydrocarbon or hydrocarbon mixture, typically a C 3 to C 15 hydrocarbon, or oil, e.g. crude oil.
- the liquid carrier may be aqueous or non-aqueous.
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)
- Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
- Solid-Sorbent Or Filter-Aiding Compositions (AREA)
- Acyclic And Carbocyclic Compounds In Medicinal Compositions (AREA)
- Drilling And Boring (AREA)
- Mechanical Treatment Of Semiconductor (AREA)
- Electrical Discharge Machining, Electrochemical Machining, And Combined Machining (AREA)
- Liquid Crystal (AREA)
- Medicines That Contain Protein Lipid Enzymes And Other Medicines (AREA)
Abstract
Description
Claims
Priority Applications (7)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
EA200300497A EA005107B1 (en) | 2000-11-20 | 2001-11-19 | Well treatment process |
AU2002223825A AU2002223825A1 (en) | 2000-11-20 | 2001-11-19 | Well treatment process |
US10/432,190 US7473672B2 (en) | 2000-11-20 | 2001-11-19 | Well treatment process |
EP01996669A EP1339946B1 (en) | 2000-11-20 | 2001-11-19 | Well treatment process |
DE60116800T DE60116800T2 (en) | 2000-11-20 | 2001-11-19 | METHOD FOR THE TREATMENT OF BORING HOLES |
NO20032244A NO319204B1 (en) | 2000-11-20 | 2003-05-19 | Bronnbehandlingsprosess |
US12/276,191 US7807609B2 (en) | 2000-11-20 | 2008-11-21 | Well treatment process |
Applications Claiming Priority (2)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GBGB0028268.1 | 2000-11-20 | ||
GBGB0028268.1A GB0028268D0 (en) | 2000-11-20 | 2000-11-20 | Well treatment |
Related Child Applications (2)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10432190 A-371-Of-International | 2001-11-19 | ||
US12/276,191 Continuation US7807609B2 (en) | 2000-11-20 | 2008-11-21 | Well treatment process |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2002040826A1 true WO2002040826A1 (en) | 2002-05-23 |
Family
ID=9903507
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB2001/005081 WO2002040826A1 (en) | 2000-11-20 | 2001-11-19 | Well treatment process |
Country Status (9)
Country | Link |
---|---|
US (2) | US7473672B2 (en) |
EP (1) | EP1339946B1 (en) |
AT (1) | ATE316193T1 (en) |
AU (1) | AU2002223825A1 (en) |
DE (1) | DE60116800T2 (en) |
EA (1) | EA005107B1 (en) |
GB (1) | GB0028268D0 (en) |
NO (1) | NO319204B1 (en) |
WO (1) | WO2002040826A1 (en) |
Families Citing this family (15)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US7781387B2 (en) * | 2008-01-22 | 2010-08-24 | Access Business Group International, Llc. | Automatic phosphate-free dishwashing detergent providing improved spotting and filming performance |
US8343904B2 (en) | 2008-01-22 | 2013-01-01 | Access Business Group International Llc | Phosphate and phosphonate-free automatic gel dishwashing detergent providing improved spotting and filming performance |
US20100216219A1 (en) | 2009-02-23 | 2010-08-26 | E. I. Du Pont De Nemours And Company | Method of in situ bioremediation of hydrocarbon-contaminated sites using an enriched anaerobic steady state microbial consortium |
US8528634B2 (en) * | 2009-02-23 | 2013-09-10 | E.I. Du Pont De Nemours And Company | Method of improving oil recovery from an oil reservoir using an enriched anaerobic steady state microbial consortium |
US8753865B2 (en) * | 2009-02-23 | 2014-06-17 | E I Du Pont De Nemours And Company | Steady state anaerobic denitrifying consortium for application in in-situ bioremediation of hydrocarbon-contaminated sites and enhanced oil recovery |
WO2011005988A1 (en) * | 2009-07-10 | 2011-01-13 | Schlumberger Canada Limited | Apparatus and methods for inserting and removing tracer materials in downhole screens |
US8230731B2 (en) | 2010-03-31 | 2012-07-31 | Schlumberger Technology Corporation | System and method for determining incursion of water in a well |
US8596354B2 (en) | 2010-04-02 | 2013-12-03 | Schlumberger Technology Corporation | Detection of tracers used in hydrocarbon wells |
US9422793B2 (en) | 2010-10-19 | 2016-08-23 | Schlumberger Technology Corporation | Erosion tracer and monitoring system and methodology |
EP2794811B1 (en) * | 2011-12-21 | 2019-05-22 | Akzo Nobel Chemicals International B.V. | Particles containing one or more controlled release cross-linked active agents |
US9863228B2 (en) | 2012-03-08 | 2018-01-09 | Schlumberger Technology Corporation | System and method for delivering treatment fluid |
CA2897502C (en) | 2013-01-08 | 2021-07-20 | Cidra Corporate Services Inc. | Smart proppant technology for fracking and well production performance monitoring |
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WO2018039340A1 (en) * | 2016-08-23 | 2018-03-01 | University Of Kansas | Enzymatic compositions for the degradation of polymers |
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- 2001-11-19 EP EP01996669A patent/EP1339946B1/en not_active Expired - Lifetime
- 2001-11-19 WO PCT/GB2001/005081 patent/WO2002040826A1/en active IP Right Grant
- 2001-11-19 AU AU2002223825A patent/AU2002223825A1/en not_active Abandoned
- 2001-11-19 EA EA200300497A patent/EA005107B1/en not_active IP Right Cessation
- 2001-11-19 AT AT01996669T patent/ATE316193T1/en not_active IP Right Cessation
- 2001-11-19 US US10/432,190 patent/US7473672B2/en not_active Expired - Fee Related
- 2001-11-19 DE DE60116800T patent/DE60116800T2/en not_active Expired - Lifetime
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- 2003-05-19 NO NO20032244A patent/NO319204B1/en not_active IP Right Cessation
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- 2008-11-21 US US12/276,191 patent/US7807609B2/en not_active Expired - Fee Related
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US5437331A (en) * | 1994-08-24 | 1995-08-01 | The Western Company Of North America | Method for fracturing subterranean formations using controlled release breakers and compositions useful therein |
WO2001034939A1 (en) * | 1999-11-12 | 2001-05-17 | M-I L.L.C. | Method and composition for the triggered release of polymer-degrading agents for oil field use |
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US7807609B2 (en) | 2010-10-05 |
EP1339946B1 (en) | 2006-01-18 |
AU2002223825A1 (en) | 2002-05-27 |
US20090163385A1 (en) | 2009-06-25 |
NO20032244D0 (en) | 2003-05-19 |
EA200300497A1 (en) | 2003-12-25 |
US20040074644A1 (en) | 2004-04-22 |
EA005107B1 (en) | 2004-10-28 |
EP1339946A1 (en) | 2003-09-03 |
NO20032244L (en) | 2003-07-14 |
DE60116800T2 (en) | 2006-07-20 |
US7473672B2 (en) | 2009-01-06 |
NO319204B1 (en) | 2005-06-27 |
GB0028268D0 (en) | 2001-01-03 |
ATE316193T1 (en) | 2006-02-15 |
DE60116800D1 (en) | 2006-04-06 |
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