WO2016156956A1 - Fluido de tratamiento entrecruzado y métodos de fracturación de formaciones subterráneas basados en agua de retorno, agua de producción, agua de mar, agua dulce y mezclas de las mismas - Google Patents
Fluido de tratamiento entrecruzado y métodos de fracturación de formaciones subterráneas basados en agua de retorno, agua de producción, agua de mar, agua dulce y mezclas de las mismas Download PDFInfo
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- XHAZMZWXAOBLQG-UHFFFAOYSA-N (1-hydroxy-1-phosphonopropyl)phosphonic acid Chemical compound CCC(O)(P(O)(O)=O)P(O)(O)=O XHAZMZWXAOBLQG-UHFFFAOYSA-N 0.000 description 1
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- XYJLPCAKKYOLGU-UHFFFAOYSA-N 2-phosphonoethylphosphonic acid Chemical compound OP(O)(=O)CCP(O)(O)=O XYJLPCAKKYOLGU-UHFFFAOYSA-N 0.000 description 1
- ROPQINLWRARCTM-UHFFFAOYSA-N 2-phosphonopropan-2-ylphosphonic acid Chemical compound OP(=O)(O)C(C)(C)P(O)(O)=O ROPQINLWRARCTM-UHFFFAOYSA-N 0.000 description 1
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- WDYVUKGVKRZQNM-UHFFFAOYSA-N 6-phosphonohexylphosphonic acid Chemical compound OP(O)(=O)CCCCCCP(O)(O)=O WDYVUKGVKRZQNM-UHFFFAOYSA-N 0.000 description 1
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- 101100325797 Arabidopsis thaliana BCA5 gene Proteins 0.000 description 1
- BTBUEUYNUDRHOZ-UHFFFAOYSA-N Borate Chemical compound [O-]B([O-])[O-] BTBUEUYNUDRHOZ-UHFFFAOYSA-N 0.000 description 1
- VYZAMTAEIAYCRO-UHFFFAOYSA-N Chromium Chemical compound [Cr] VYZAMTAEIAYCRO-UHFFFAOYSA-N 0.000 description 1
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- SHZGCJCMOBCMKK-UHFFFAOYSA-N D-mannomethylose Natural products CC1OC(O)C(O)C(O)C1O SHZGCJCMOBCMKK-UHFFFAOYSA-N 0.000 description 1
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- 101000805941 Homo sapiens Usherin Proteins 0.000 description 1
- QNAYBMKLOCPYGJ-REOHCLBHSA-N L-alanine Chemical compound C[C@H](N)C(O)=O QNAYBMKLOCPYGJ-REOHCLBHSA-N 0.000 description 1
- CKLJMWTZIZZHCS-REOHCLBHSA-N L-aspartic acid Chemical compound OC(=O)[C@@H](N)CC(O)=O CKLJMWTZIZZHCS-REOHCLBHSA-N 0.000 description 1
- SHZGCJCMOBCMKK-JFNONXLTSA-N L-rhamnopyranose Chemical compound C[C@@H]1OC(O)[C@H](O)[C@H](O)[C@H]1O SHZGCJCMOBCMKK-JFNONXLTSA-N 0.000 description 1
- PNNNRSAQSRJVSB-UHFFFAOYSA-N L-rhamnose Natural products CC(O)C(O)C(O)C(O)C=O PNNNRSAQSRJVSB-UHFFFAOYSA-N 0.000 description 1
- JLVVSXFLKOJNIY-UHFFFAOYSA-N Magnesium ion Chemical compound [Mg+2] JLVVSXFLKOJNIY-UHFFFAOYSA-N 0.000 description 1
- PWHULOQIROXLJO-UHFFFAOYSA-N Manganese Chemical compound [Mn] PWHULOQIROXLJO-UHFFFAOYSA-N 0.000 description 1
- ZOKXTWBITQBERF-UHFFFAOYSA-N Molybdenum Chemical compound [Mo] ZOKXTWBITQBERF-UHFFFAOYSA-N 0.000 description 1
- 208000000474 Poliomyelitis Diseases 0.000 description 1
- 101000725027 Saccharomyces cerevisiae (strain ATCC 204508 / S288c) 60S ribosomal protein L11-A Proteins 0.000 description 1
- 101000725541 Saccharomyces cerevisiae (strain ATCC 204508 / S288c) 60S ribosomal protein L11-B Proteins 0.000 description 1
- 239000007983 Tris buffer Substances 0.000 description 1
- XSQUKJJJFZCRTK-UHFFFAOYSA-N Urea Natural products NC(N)=O XSQUKJJJFZCRTK-UHFFFAOYSA-N 0.000 description 1
- 102100037930 Usherin Human genes 0.000 description 1
- NGVYCQKCQKSDRK-UHFFFAOYSA-N [5,6-dibutyl-6-(2-phosphonoethyl)decan-5-yl]phosphonic acid Chemical compound CCCCC(CCCC)(CCP(O)(O)=O)C(CCCC)(CCCC)P(O)(O)=O NGVYCQKCQKSDRK-UHFFFAOYSA-N 0.000 description 1
- 235000004279 alanine Nutrition 0.000 description 1
- 150000001298 alcohols Chemical class 0.000 description 1
- WQZGKKKJIJFFOK-PHYPRBDBSA-N alpha-D-galactose Chemical compound OC[C@H]1O[C@H](O)[C@H](O)[C@@H](O)[C@H]1O WQZGKKKJIJFFOK-PHYPRBDBSA-N 0.000 description 1
- 150000001412 amines Chemical class 0.000 description 1
- 239000007864 aqueous solution Substances 0.000 description 1
- 229910052785 arsenic Inorganic materials 0.000 description 1
- RQNWIZPPADIBDY-UHFFFAOYSA-N arsenic atom Chemical compound [As] RQNWIZPPADIBDY-UHFFFAOYSA-N 0.000 description 1
- 235000003704 aspartic acid Nutrition 0.000 description 1
- 239000011324 bead Substances 0.000 description 1
- OQFSQFPPLPISGP-UHFFFAOYSA-N beta-carboxyaspartic acid Natural products OC(=O)C(N)C(C(O)=O)C(O)=O OQFSQFPPLPISGP-UHFFFAOYSA-N 0.000 description 1
- 230000003115 biocidal effect Effects 0.000 description 1
- 150000001642 boronic acid derivatives Chemical class 0.000 description 1
- 229910052791 calcium Inorganic materials 0.000 description 1
- 229910001424 calcium ion Inorganic materials 0.000 description 1
- DKVNPHBNOWQYFE-UHFFFAOYSA-N carbamodithioic acid Chemical compound NC(S)=S DKVNPHBNOWQYFE-UHFFFAOYSA-N 0.000 description 1
- 229910052799 carbon Inorganic materials 0.000 description 1
- 125000004432 carbon atom Chemical group C* 0.000 description 1
- 150000001735 carboxylic acids Chemical class 0.000 description 1
- 239000001913 cellulose Substances 0.000 description 1
- 229920002678 cellulose Polymers 0.000 description 1
- 229910021540 colemanite Inorganic materials 0.000 description 1
- 239000012141 concentrate Substances 0.000 description 1
- 235000009508 confectionery Nutrition 0.000 description 1
- 238000005520 cutting process Methods 0.000 description 1
- 230000007812 deficiency Effects 0.000 description 1
- 125000004177 diethyl group Chemical group [H]C([H])([H])C([H])([H])* 0.000 description 1
- 239000012990 dithiocarbamate Substances 0.000 description 1
- 230000008030 elimination Effects 0.000 description 1
- 238000003379 elimination reaction Methods 0.000 description 1
- 230000002255 enzymatic effect Effects 0.000 description 1
- 229930182830 galactose Natural products 0.000 description 1
- 239000011521 glass Substances 0.000 description 1
- 150000004676 glycans Chemical class 0.000 description 1
- 125000004836 hexamethylene group Chemical group [H]C([H])([*:2])C([H])([H])C([H])([H])C([H])([H])C([H])([H])C([H])([H])[*:1] 0.000 description 1
- 230000003993 interaction Effects 0.000 description 1
- NAALTSITEQTADZ-UHFFFAOYSA-N l-n-carboxymethylserine Chemical compound OCC(C(O)=O)NCC(O)=O NAALTSITEQTADZ-UHFFFAOYSA-N 0.000 description 1
- 229910001425 magnesium ion Inorganic materials 0.000 description 1
- 159000000003 magnesium salts Chemical class 0.000 description 1
- 229910052748 manganese Inorganic materials 0.000 description 1
- 239000011572 manganese Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- MBKDYNNUVRNNRF-UHFFFAOYSA-N medronic acid Chemical compound OP(O)(=O)CP(O)(O)=O MBKDYNNUVRNNRF-UHFFFAOYSA-N 0.000 description 1
- QSHDDOUJBYECFT-UHFFFAOYSA-N mercury Chemical compound [Hg] QSHDDOUJBYECFT-UHFFFAOYSA-N 0.000 description 1
- 229910052753 mercury Inorganic materials 0.000 description 1
- 229910052750 molybdenum Inorganic materials 0.000 description 1
- 239000011733 molybdenum Substances 0.000 description 1
- 239000003345 natural gas Substances 0.000 description 1
- 229920005615 natural polymer Polymers 0.000 description 1
- 239000012457 nonaqueous media Substances 0.000 description 1
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- 230000001590 oxidative effect Effects 0.000 description 1
- 239000003208 petroleum Substances 0.000 description 1
- 229920001282 polysaccharide Polymers 0.000 description 1
- 239000005017 polysaccharide Substances 0.000 description 1
- 125000002924 primary amino group Chemical group [H]N([H])* 0.000 description 1
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- 239000000126 substance Substances 0.000 description 1
- 239000001384 succinic acid Substances 0.000 description 1
- 229920001059 synthetic polymer Polymers 0.000 description 1
- 230000009885 systemic effect Effects 0.000 description 1
- 239000011135 tin Substances 0.000 description 1
- 238000012549 training Methods 0.000 description 1
- 238000004457 water analysis Methods 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/887—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
- C09K8/02—Well-drilling compositions
- C09K8/04—Aqueous well-drilling compositions
- C09K8/14—Clay-containing compositions
- C09K8/18—Clay-containing compositions characterised by the organic compounds
- C09K8/22—Synthetic organic compounds
- C09K8/24—Polymers
-
- 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
- C09K8/04—Aqueous well-drilling compositions
- C09K8/06—Clay-free compositions
- C09K8/08—Clay-free compositions containing natural organic compounds, e.g. polysaccharides, or derivatives thereof
- C09K8/10—Cellulose or derivatives thereof
-
- 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
- C09K8/42—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells
- C09K8/46—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
- C09K8/467—Compositions for cementing, e.g. for cementing casings into boreholes; Compositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
- C09K8/487—Fluid loss control additives; Additives for reducing or preventing circulation loss
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/602—Compositions for stimulating production by acting on the underground formation containing surfactants
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/62—Compositions for forming crevices or fractures
- C09K8/66—Compositions based on water or polar solvents
- C09K8/68—Compositions based on water or polar solvents containing organic compounds
- C09K8/685—Compositions based on water or polar solvents containing organic 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/84—Compositions based on water or polar solvents
- C09K8/86—Compositions based on water or polar solvents containing organic compounds
- C09K8/88—Compositions based on water or polar solvents containing organic compounds macromolecular compounds
- C09K8/90—Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
-
- 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
- C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
- C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
- C09K8/605—Compositions for stimulating production by acting on the underground formation containing biocides
Definitions
- the present invention relates to crosslinked and delayed fracturing fluids, based on return water, production water, seawater, freshwater and mixtures thereof, and methods of using formation fracturing fluids. underground penetrated by production wells. Description of the prior art
- Hydraulic fracturing is achieved by injecting a viscous fracturing fluid through the well pipe in an underground formation to be fractured, and the application of sufficient fluid pressure in the formation to cause the production of one or more fractures in it.
- the fracturing fluid can be prepared using return water, production water, sea water, fresh water or mixtures thereof, to hydrate a gelling agent and form a viscous aqueous fluid. To promote adequate viscosity for increasing depths of wells, they can be incorporated into
- Billing fluids buffers and crosslinking agents such as compounds capable of fiberation of borate ions.
- Fracturing fluids crosslinked with borates based on return water, production water, seawater, fresh water or mixtures thereof perform satisfactorily in low to medium temperature fracturing applications, up to a range of 90 to 120 ° C (200 to 250 ° F).
- the pH required to form a sufficiently crosslinked gel is in a range of 8.5 to 9.5.
- a sufficiently crosslinked gel can be defined having a reference viscosity of about 100 centipoise or more at a shear rate of 100 / sec.
- the initial pH of a borate crosslinked fracturing fluid must be in a range greater than 8.5 to 9.5.
- the elevation of the fracture fluid pH to a level in excess of 9.5 poses some operational problems.
- return water, production water, sea water, fresh water or mixtures thereof contain multivalent ions such as calcium and magnesium ions, which form insoluble precipitates at a pH greater than a range of 9.5 to 10.0, if chelating agents or sequestrants that inhibit multivalent ions are not used.
- the presence of solid precipitates reduces the effective conductivity of the support agent within the fracture, and ultimately affects the productivity of the fracturing operation.
- Figure 1 represents the results of tests carried out to verify the reoiological behavior with a crosslinked gel.
- the present invention provides crosslinked fracturing fluids and methods of using fluids to fracture underground formations that meet the needs described above and overcome the deficiencies of the prior art.
- Fracturing fluids and inventive methods are particularly useful for use in oil and gas fields where the management of return and production water has involved different complications such as those in which there are no injector wells or in which it exceeded the flow of water production above the injection rates.
- the fluids are based on return water, production water, sea water, fresh water or mixtures thereof, the cross-linking can be delayed and controlled in order to facilitate the injection of the fluid and control other aspects of Fracturing operation
- composition of the invention is a high temperature delayed crosslinked fracturing fluid, comprising:
- an iron control agent capable of controlling the presence of iron and other metals such as manganese, cobalt, copper, molybdenum, tin, etc .;
- boron control agent capable of maintaining control of the concentration of boron in the return water, production water, sea water, fresh water or mixtures thereof, to avoid any potential action! thereof on the crosslinking reaction
- an alkaline buffer capable of increasing the pH, even at low concentrations under conditions of high salinity and hardness; a cross-linking agent, capable of causing a delayed cross-linking of the gelling agent at a pH in the range of 8.5 to 9.5, whereby the cross-linking delay is about 1 minute or more;
- the system can include many other additives as widely used in the art: biocides, clay stabilizers, surfactants, surfactants, non-emulsifiers, return improvers, temperature stabilizers, friction reducers, gas hydrate inhibitors, control additives of return of support agents, fluid loss control additives, foaming agents, coupling agents, suspension additives for support agents, solvents, mutual solvents, paraffin / asphaltene control additives, relative permeability modifiers, activators of resin, scale inhibitors, and any other additives that may be useful for the specific stimulation work design.
- the method of the invention for fracturing an underground formation penetrated by a well and having a temperature up to a range of 90 to 120 ° C (200 to 250 ° F) basically comprises the following steps:
- the fracturing fluids of the invention are also useful in relation to other operations.
- fluids can be used in combined fracturing / stapling operations.
- a major advantage of the crosslinked fracturing fluids of the present invention is that the fluids can be prepared with return water, production water, sea water, fresh water or mixtures thereof pumped from any source (injector wells, wells of elimination, oceans, seas, rivers, etc.) to the site of the fracturing operation, regardless of where the work is performed.
- the present compositions are economical and easy to prepare, using either batch mixing procedures or continuous pumping envelope.
- the crosslinked fracturing fluids of the present invention are stable at temperatures up to a range of 90 to 120 "C (200 to 250 ° F) and at a pH that is in a range of 8.5 to 9, 5. Due to the lower pH, the fluids are compatible with enzymatic breaking agents, and the calcium and magnesium salts remain in solution, even when the gelling agent has been hydrated with return water, production water, seawater, fresh water or mixtures of same, the fracturing fluid provides a delay in crosslinking, conducive to fracturing underground formations at greater depths and / or with lower pumping rates. Thus, the fracturing fluid has an initial viscosity that is high enough for the transport of the support agent, but is not so high as to make pumping difficult.
- the crosslinked fracturing fluids of the present invention comprise a gelling agent; return water, production water, sea water, fresh water or mixtures thereof, present in at least an amount sufficient to hydrate the gelling agent, thereby forming a gelled aqueous fluid; an iron control agent capable of controlling the presence of iron and other metals; a boron control agent capable of maintaining control of the concentration of boron in the return water, production water, sea water, fresh water or mixtures thereof; an alkaline buffer capable of increasing the pH, even at low concentrations under conditions of high salinity and hardness; a cross-linking agent, capable of causing a delayed cross-linking of the gelling agent at a pH in the range of 8.5 to 9.5, whereby the cross-linking delay is about 1 minute or more; and a rupture system to break the liquid and improve the cleanliness of the fracture.
- Suitable gelling agents include galactomannan type gums, modified or derived galactomannan type gums and cellulose derivatives. Additional examples of gelling agents that can be used in the present invention include, but are not limited to guar gum, hydroxypropylguar, carboxymethylhydroxypropylguar, carboxymethylguar, carboxymethylcellulose, carboxymethylhydroxyethylcellulose, and mixtures thereof. Preferred gelling agents include guar gum and hydroxypropylguar. Other natural or synthetic polymers that are known in the art, but not specifically mentioned herein, can also be used.
- the gelling agent is present in the fracturing fluid in an amount in the range of 25.75 to 103.02 Kg / m 3 (15 to 60 pounds per 000 gallons) of return water, production water, sea water, fresh water or mixtures thereof, preferably from 34.34 to 77.27 Kg / m 3 (20 to 45 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof , and most preferably from 42.92 to 61 Kg / m 3 (25 to 35 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof.
- the return water, production water, sea water, fresh water or mixtures thereof, is present in at least an amount sufficient to hydrate the gelling agent, thereby forming a gelled aqueous fluid.
- the fracturing fluids of the present invention comprise an iron control agent capable of controlling the presence of Iron and other metals such as e) Manganese, Cobalt, Copper, Moiibdene, Tin, etc.
- Suitable iron control agents or complainants include, but are not limited to compounds of chelating agents such as, for example, thiourea; ethylenediaminetetraacetic acid (EDTA); propylenediaminetetraacetic acid (PDTA); nitrilotriacetic acid (NTA); N- (2- hydroxyethyl) ethylenediaminetriacetic acid (HEDTA); diethylenetriaminepentaacetic acid (DTPA); hydroxyethyliminodiacetic acid (HEIDA); Cyclohexylenediaminetetraacetic acid (CDTA); diphenylaminosulfonic acid (DPAS); ethylenediamino-di (o-hydroxyphenylacetic acid) (EDDHA); saicylic acid; sul
- succinic acid CEAA
- 2- (2- carboxymethylamino) succinic acid CMAA
- Diethylenetriamino-N, N "-disuccinic acid triethylenetetramino-N ⁇ disuccinic acid; 1, 6-hexamethylenediamine-N t N'-disuccinic acid; tetraethylenepentarnin-N, ⁇ '''' - disuccinic acid; 2-hydroxypropylene- 1,3-diamino-N, N'-disuccinic; 1,2-propylenediamino-N, N'-disuccinic acid; 1,3-propi!
- alkylenediphosphonic acids any salt thereof, any derivative thereof, any mixture thereof and the like, are effective for this invention as inhibitors for iron and similar substances.
- Illustrative alkylenediphosphonic acid compounds include, but are not limited to, methylenediphosphonic acid; ethylidendiphosphonic acid; isopropylidendiphosphonic acid; 1- hydroxy ethiidenediphosphonic acid; hexamethylene diphosphonic acid; trimethylene diphosphonic acid; decamethyl diphosphonic acid; 1-hydroxy propylidendiphosphonic acid; 1,6-d-hydroxy, 1, 6- dimethyl, hexanethylene diphosphonic acid; 1,4-dihydroxy, 1,4-diethyl!
- iron controf agents are formic acid, sulfamic acid, gluconic acid and thiocyanic acid.
- the iron control agent is generally present in the fracturing fluid in an amount in the range of 0 to 85.85 kg / m 3 (0 to 50 pounds per 1000 gallons), preferably in the range of 1.72 to 42 , 93 Kg / m 3 (1 to 25 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof, and more preferably in the range of 4.29 to 25.76 Kg / m 3 (2.5 to 15 pounds per 000 gallons) of return water, production water, sea water, fresh water or mixtures thereof.
- the fracturing fluids of the present invention comprise a boron control agent capable of maintaining control of the concentration of boron in the return water, production water, sea water, fresh water or mixtures thereof, to avoid any their potential action on the crosslinking reaction.
- Said boron control agent may be selected from the group consisting of "polyhydric alcohols" or "polyols”.
- polyhydric alcohols or “polyols” means an organic compound having adjacent hydroxyl groups in a cis orientation, that is, cis-hydroxyls. Therefore, the poiiol may comprise materials such as saccharides, which include, but are not limited to, monosaccharides, oligosaccharides having a molecular weight of up to about 2000, and polysaccharides that include natural and synthetic gums. Also included in the term “polyols” is the acid, acid salt, ester, hydrogenation derivatives and ammonium of the poiiol provided that the polio! have and continue to have at least one set of cis-hydroxyl groups.
- glucose is a monosaccharide.
- Monosaccharides are any of several simple sugars that have the formula C 6 H 12 0 6 .
- Gluconic acid is the acid derived from glucose.
- a gluconate for example sodium gluconate, is the salt of gluconic acid Therefore, a gluconate is the salt of an acid derived from a saccharide.
- the little man! and sorbitol are both hexahydroxyl alcohols with one hydroxyl group per carbon atom, and both are derived from hydrogenation of glucose, which is a monosaccharide or, generically, a saccharide.
- Suitable polyols are those that provide adequate interaction with boron in return water, production water, sea water, fresh water or mixtures thereof, and stabilize the fracturing fluid under the final use conditions of the fracture process .
- Suitable polyols are preferably those that have an equilibrium constant of the complex in the same range as guar derivatives or guar gum (Keq at least 10 3 , preferably at least 10 4 ).
- suitable polyols include fructose, sorbitol, gluconic acid and its salts, for example, sodium gluconate, glucoheptanoic acid and its salts, for example, sodium giucoheptanoate, mannitol, ribose, arabinose, and xylose.
- Polyols that have been shown not to be suitable for guar derivatives or guar gum, but may be useful for other polymers, include glucose, ethylene glycol, glycerol, mannose, rhamnose, galactose, tartaric acid, citric acid, EDTA.
- the boron control agent is generally present in the fracturing fluid in an amount in the range of 0 to 17.17 Kg / m 3 (0 to 10 pounds per 1000 gallons), preferably in the range of 0.086 to 8.58 Kg / m3 (0.05 to 5 pounds per 1000 gallons) of return water, production water, sea water, water or mixtures thereof, and more preferably in the range of 0.17 to 4, 29 Kg / m3 (0.1 to 2.5 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof.
- the fracturing fluids of the present invention comprise an alkaline buffer capable of increasing the pH, even at low concentrations under conditions of high salinity and hardness, said alkaline buffer is selected from the group consisting of mono-, di-, tri- and / or polyamines, mono-, di-, tri- and / or poly-substituted and / or mixtures thereof.
- Suitable alkaline buffers include, but are not limited to, methylamine; dimethylamine; trimethiamine; ethylamine; diethylamine; triethylamine; n-butylamine; n-decylamine; dodecylamine (DDA); monoethanolamine (MEA); diethanolamine (DEA); triethanolamine (ASD); düsopropylamine; tetramethylenediamine (TMDA); hexamethylenediamine (HMD); 1, 6- hexanodine; diethylenetriamine (DETA); triethylenetetramine (TETA); hexamethylene tetramine (HMTA); tetraethylenepentamine (TEPA); pentaethylenehexamine (PEHA); and their mixtures. Of these, monoethanolamine (MEA) are preferred; diethanolamine (DEA); triethanolamine (ASD); hexamethylenediamine (HMD); diethylenetriamine (DETA), and / or mixtures thereof.
- the alkaline buffer is generally present in the fracturing fluid in an amount in the range of 0 to 34.34 kg / m 3 (0 to 20 pounds per 1000 gallons), preferably in the range of 0.86 to 25.75 kg / m 3 (0.5 to 15 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof, and more preferably in the range of 1, 71 to 17.17 Kg / m 3 to (1 to 10 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof.
- the crosslinking agent used in the present invention is capable of causing a delay in the crosslinking of the gelling agent at a pH that is in the range of 8.5 to 9.5 for pipe transit times greater than 5 minutes. Therefore, the delay in crosslinking exhibited by the compositions of the present invention is approximately 5 minutes or more.
- Suitable crosslinking agents include, but are not limited to boron oxide, boric acid, boronic acids, metaborate salts, octoborate salts, tetraborate salts, Colemanite, Frolovite, Ginorite, Gowerite, Hydroboracite, Inderborite, inderite, Inyoita, Kaliborite (Heintzite), Kurnakovite, Meyerhofferite, Nobleite, Paternoite, Pinnoite, Preobrazhenskite, Priceite, Probertite, Tertschite, Ulexite, Veatchite, and mixtures of the same.
- the crosslinking agent used consists of a concentrated suspension having an equivalent concentration of 15 to 18% of B 2 0 3 .
- the delayed crosslinking agent is generally combined with the geiified aqueous fluid in an amount sufficient to provide a concentration of boron in the range of 0.01 to 0.1 weight percent of said gelling agent.
- Support agents can also be added to the fracturing fluids of the present invention to keep the fractures open after the fracturing fluid flows back into the well.
- support agents must have sufficient compressive strength to resist e! crushing, but they must also be non-abrasive and non-angular enough to prevent cutting and embedding in the formation.
- suitable support agents include, but are not limited to sands, gravel gravels, glass beads, sintered bauxites, resin sintered bauxites, resin sands, ceramics, and resin ceramics.
- the support agents may be present in the composition of the invention in an amount in the range of 0 to 2.99 kg / L (0 to 25 pounds per gallon), preferably in an amount in the range of 0.012 to 2.16 kg / L ⁇ 0.1 to 18 pounds per gallon), and most preferably in an amount in the range of 0.03 to 1.44 kg / L (0.25 to 12 pounds each gaffon).
- the fracturing fluids of the present invention also comprise a gel breaker that "breaks" or decreases the viscosity of the fracturing fluid so that it recovers more easily from the fracture during cleaning.
- breakers suitable for use with the fracturing fluids of the invention include oxidizing agents, enzymes, acids and esters. The most preferred being a combination of oxidizing agents and esters.
- ester based breakers also provides another advantage to the fluid of the present invention: the esters decompose to the carboxylic acids after being exposed to the bottomhole conditions. The presence of an acid in the fluid will reduce the pH to destabilize the fluid and improve the viscosity decrease, but at the same time it will help reduce the possibility of scale formation.
- the oxidative gel breaker is generally present in the fracturing fluid in an amount in the range of 0 to 34.34 kg / m 3 (0 to 20 pounds per 1000 gallons), preferably in the range of 8.58 to 25, 76 Kg / m 3 (5 to 15 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof, and more preferably in the range of 8.58 to 17.17 Kg / m 3 (5 to 10 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof.
- ester type gel breaker is usually present in e!
- fracturing fluid in an amount in the range of 0 to 17.17 Kg / m 3 ⁇ 0 to 10 pounds per 1000 gallons), preferably in the range of 0.43 to 8.58 Kg / m 3 (0.25 a 5 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof, and more preferably in the range of 0.43 to 4.29 kg / m 3 (0.25 at 2.5 pounds per 1000 gallons) of return water, production water, sea water, fresh water or mixtures thereof.
- the fracturing fluid may include a variety of other conventional additives, such as biocides, clay stabilizers, surfactants, surfactants, non-emulsifiers, return improvers, temperature stabilizers, friction reducers, gas hydrate inhibitors, additives return control of support agents, fluid loss control additives, foaming agents, coupling agents, suspension additives for support agents, solvents, mutual solvents, paraffin / asphaltene control additives, relative permeability modifiers, activators of resin, scale inhibitors, and the like that may be useful for the design of specific stimulation work, which do not react unfavorably with fracturing fluids or do not affect their properties in an unwanted way.
- additives such as biocides, clay stabilizers, surfactants, surfactants, non-emulsifiers, return improvers, temperature stabilizers, friction reducers, gas hydrate inhibitors, additives return control of support agents, fluid loss control additives, foaming agents, coupling agents, suspension additives for support agents, solvents,
- All components of the present invention can be manufactured and handled in solid presentations, aqueous solutions, aqueous suspensions, non-aqueous solutions, non-aqueous suspensions.
- one or more additives detailed by themselves or mixed with one or more additives can be added to reduce the amount of products to be dosed during operations.
- the crosslinked fracturing fluids of the present invention can be prepared by dissolving a gelling agent in return water, production water, seawater, fresh water or mixtures thereof to form a gelled aqueous fluid, and by combination with the gelled aqueous fluid of a delayed crosslinking agent, capable of causing a delay in the crosslinking of the gelling agent at a pH in the range of 8.5 to 9.5.
- the gelling agent is added to return water, production water, sea water, fresh water or mixtures thereof, either as a solid or a liquid gel concentrate in a pre-hydrated form or in suspension using mixing processes. and conventional pumping equipment.
- the delayed crosslinking composition is combined with the gelled aqueous fluid.
- the crosslinker can be pumped and dosed into the gelled aqueous fluid as the gelled aqueous fluid is pumped into the well.
- the present invention also provides a method for fracturing an underground formation penetrated by a well and having a temperature up to a range of 90 to 120 ° C (200 to 250 ° F), which basically comprises the following steps: (a) preparing a crosslinked and delayed fracturing fluid based on return water, production water, sea water, fresh water or a mixture thereof comprising a gelling agent; return water, production water, sea water, fresh water or mixtures thereof present in at least an amount sufficient to hydrate e!
- an iron control agent capable of controlling the presence of iron and other metals
- a boron control agent capable of maintaining control of the concentration of boron in the return water, production water, sea water, fresh water or mixtures thereof
- an alkaline buffer capable of increasing the pH, even at low concentrations under conditions of high salinity and hardness
- a cross-linking agent capable of causing a delayed cross-linking of the gelling agent at a pH in the range of 8.5 to 9.5, whereby the cross-linking delay is about 1 minute or more
- a rupture system to break the liquid and improve fracture cleanliness
- Example 1 Base Water The base water was prepared by mixing 50% v / v return water collected in a separation battery, without any treatment, and 50% fresh river water (regular stimulation water) , in the instant before carrying out the following examples.
- Table 1 is presented below, where the water analysis for the return water and the analysis for fresh river water are detailed: Table 1
- the crosslinked gel of Example 3 was evaluated through the following steps: a) A 52 ml aliquot of crosslinked gei was transferred to the rotor (R1) of a Grace Instruments Model M5600 rheometer,
- fluids with a viscosity greater than 100 centipoise at 100 / s are suitable for fracturing operations.
- the stability of a fracturing fluid is defined in terms of its ability to maintain a adequate viscosity for a prolonged period of time at a given temperature. Referring to Table 2, the data shows that the fluid based on the mixture of return water without treatment and fresh water formulated by the examples has a viscosity greater than 350 centipoise at 100 / s after 90 minutes at a temperature up to range from 90 to 120 ° C (200 to 250T). Therefore, the data illustrates that the crosslinked water-based fracturing fluids of the present invention are stable for prolonged periods of time at temperatures above 93 ° C (200 ° F).
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Abstract
Description
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Priority Applications (9)
Application Number | Priority Date | Filing Date | Title |
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RU2017132327A RU2017132327A (ru) | 2015-03-30 | 2015-12-16 | Сшитый флюид для обработки приствольной зоны и способы гидроразрыва подземного пласта на основе возвратной воды, добытой воды, морской воды, пресной воды и их смесей |
BR112017012599-4A BR112017012599A2 (pt) | 2015-03-30 | 2015-12-16 | fluido de fraturação reticulado retardado e método para a fraturação de uma formação subterrânea |
CA2959126A CA2959126A1 (en) | 2015-03-30 | 2015-12-16 | Crosslinked fluid treatment and methods for fracturing underground formations based on flowback, production water, seawater, fresh water, and mixtures of same |
MX2017004150A MX2017004150A (es) | 2015-03-30 | 2015-12-16 | Fluido de tratamiento entrecruzado y metodos de fracturacion de formaciones subterraneas basados en agua de retorno, agua de produccion, agua de mar, agua dulce y mezclas de las mismas. |
AU2015389879A AU2015389879A1 (en) | 2015-03-30 | 2015-12-16 | Crosslinked fluid treatment and methods for fracturing underground formations based on flowback, production water, seawater, fresh water, and mixtures of same |
CN201580071921.XA CN107109200A (zh) | 2015-03-30 | 2015-12-16 | 基于回水、采出水、海水、淡水及其混合物的交联处理液及压裂地下地层的方法 |
US15/531,987 US20180016486A1 (en) | 2015-03-30 | 2015-12-16 | Crosslinked fluid treatment and methods for fracturing underground formations based on flowback, production water, seawater, fresh water, and mixtures of same |
EP15887389.3A EP3178900A4 (en) | 2015-03-30 | 2015-12-16 | Crosslinked fluid treatment and methods for fracturing underground formations based on flowback, production water, seawater, fresh water, and mixtures of same |
CONC2017/0003240A CO2017003240A2 (es) | 2015-03-30 | 2017-04-03 | Fluido de tratamiento entrecruzado y métodos de fracturación de formaciones subterráneas basados en agua de retorno, agua de producción, agua de mar, agua dulce y mezclas de las mismas |
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ARP150100952A AR102026A1 (es) | 2015-03-30 | 2015-03-30 | Fluido de tratamiento entrecruzado y métodos de fracturación de formaciones subterráneas basados en agua de retorno, agua de producción, agua de mar, agua dulce y mezclas de las mismas |
AR20150100952 | 2015-03-30 |
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PCT/ES2016/070222 WO2016156651A1 (es) | 2015-03-30 | 2016-03-30 | Fluido de tratamiento entrecruzado y métodos de fracturación de formaciones subterráneas basados en agua de retorno, agua de producción, agua de mar, agua dulce y mezclas de las mismas |
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US (1) | US20180016486A1 (es) |
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CN (1) | CN107109200A (es) |
AR (1) | AR102026A1 (es) |
AU (1) | AU2015389879A1 (es) |
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CA (1) | CA2959126A1 (es) |
CO (1) | CO2017003240A2 (es) |
EC (1) | ECSP17014548A (es) |
MX (1) | MX2017004150A (es) |
PE (1) | PE20171075A1 (es) |
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BR112019025431A2 (pt) * | 2017-05-31 | 2020-06-16 | Total Marketing Services | Composto compreendendo funcionalidade de poliamina, ácida e de boro e seu uso como aditivo lubrificante |
CN110317601A (zh) * | 2019-07-29 | 2019-10-11 | 北京宝丰春石油技术有限公司 | 一种高温酸性植物胶压裂液及其制备方法 |
US11441067B2 (en) * | 2019-09-18 | 2022-09-13 | Halliburton Energy Services, Inc. | Screening method for friction reducer precipitation |
US11435330B2 (en) | 2019-09-18 | 2022-09-06 | Halliburton Energy Services, Inc. | Mitigation of friction reducer precipitation |
CN111364964B (zh) * | 2020-02-03 | 2020-09-25 | 西南石油大学 | 一种固体缓速酸的注入方法 |
CN111154477B (zh) * | 2020-02-03 | 2020-07-31 | 西南石油大学 | 一种对储层无伤害的高效缓速固体酸体系 |
CN112322273A (zh) * | 2020-10-15 | 2021-02-05 | 中国科学院广州能源研究所 | 一种海底天然气水合物矿藏用压裂液 |
US11447691B1 (en) | 2021-07-28 | 2022-09-20 | Halliburton Energy Services, Inc. | Methods of making and using a wellbore servicing fluid for iron mitigation |
CN114262353B (zh) * | 2021-12-31 | 2023-11-07 | 昆山京昆油田化学科技有限公司 | 一种环氧琥珀酸改性甘露糖甲苷及其制备方法和应用、压裂液交联剂、压裂液 |
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- 2015-12-16 RU RU2017132327A patent/RU2017132327A/ru not_active Application Discontinuation
- 2015-12-16 CA CA2959126A patent/CA2959126A1/en not_active Abandoned
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CA2959126A1 (en) | 2016-10-06 |
EP3178900A1 (en) | 2017-06-14 |
ECSP17014548A (es) | 2018-03-31 |
BR112017012599A2 (pt) | 2018-01-16 |
RU2017132327A3 (es) | 2019-06-24 |
US20180016486A1 (en) | 2018-01-18 |
CN107109200A (zh) | 2017-08-29 |
MX2017004150A (es) | 2017-09-12 |
CO2017003240A2 (es) | 2017-06-20 |
RU2017132327A (ru) | 2019-03-15 |
AU2015389879A1 (en) | 2017-03-16 |
PE20171075A1 (es) | 2017-08-03 |
AR102026A1 (es) | 2017-02-01 |
EP3178900A4 (en) | 2018-01-17 |
WO2016156651A1 (es) | 2016-10-06 |
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