CA2777449C - Liquefied industrial gas based solution in hydraulic fracturing - Google Patents
Liquefied industrial gas based solution in hydraulic fracturing Download PDFInfo
- Publication number
- CA2777449C CA2777449C CA2777449A CA2777449A CA2777449C CA 2777449 C CA2777449 C CA 2777449C CA 2777449 A CA2777449 A CA 2777449A CA 2777449 A CA2777449 A CA 2777449A CA 2777449 C CA2777449 C CA 2777449C
- Authority
- CA
- Canada
- Prior art keywords
- cryogenic
- fracturing fluid
- subterranean
- subterranean fracturing
- combination
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Active
Links
- 239000012530 fluid Substances 0.000 claims abstract description 67
- 239000007789 gas Substances 0.000 claims abstract description 48
- 239000000654 additive Substances 0.000 claims abstract description 47
- 230000000996 additive effect Effects 0.000 claims abstract description 30
- IJGRMHOSHXDMSA-UHFFFAOYSA-N Atomic nitrogen Chemical compound N#N IJGRMHOSHXDMSA-UHFFFAOYSA-N 0.000 claims abstract description 28
- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 claims abstract description 28
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims abstract description 28
- 230000015572 biosynthetic process Effects 0.000 claims abstract description 26
- 239000007788 liquid Substances 0.000 claims abstract description 26
- XEEYBQQBJWHFJM-UHFFFAOYSA-N Iron Chemical compound [Fe] XEEYBQQBJWHFJM-UHFFFAOYSA-N 0.000 claims abstract description 18
- 239000001569 carbon dioxide Substances 0.000 claims abstract description 14
- 229910002092 carbon dioxide Inorganic materials 0.000 claims abstract description 14
- 229910052757 nitrogen Inorganic materials 0.000 claims abstract description 14
- 239000003139 biocide Substances 0.000 claims abstract description 13
- 239000002253 acid Substances 0.000 claims abstract description 12
- 230000003115 biocidal effect Effects 0.000 claims abstract description 11
- 239000000203 mixture Substances 0.000 claims abstract description 11
- 239000003349 gelling agent Substances 0.000 claims abstract description 10
- 239000003638 chemical reducing agent Substances 0.000 claims abstract description 9
- 238000005260 corrosion Methods 0.000 claims abstract description 9
- 230000007797 corrosion Effects 0.000 claims abstract description 9
- 239000003995 emulsifying agent Substances 0.000 claims abstract description 9
- 229910052742 iron Inorganic materials 0.000 claims abstract description 9
- 239000004971 Cross linker Substances 0.000 claims abstract description 8
- 239000004927 clay Substances 0.000 claims abstract description 8
- 239000003112 inhibitor Substances 0.000 claims abstract description 8
- 239000003002 pH adjusting agent Substances 0.000 claims abstract description 8
- 239000003381 stabilizer Substances 0.000 claims abstract description 8
- 239000004094 surface-active agent Substances 0.000 claims abstract description 8
- 229940123973 Oxygen scavenger Drugs 0.000 claims abstract description 7
- 239000002455 scale inhibitor Substances 0.000 claims abstract description 7
- 239000002002 slurry Substances 0.000 claims abstract description 6
- CBENFWSGALASAD-UHFFFAOYSA-N Ozone Chemical compound [O-][O+]=O CBENFWSGALASAD-UHFFFAOYSA-N 0.000 claims abstract description 4
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 claims description 45
- OKKJLVBELUTLKV-UHFFFAOYSA-N Methanol Chemical compound OC OKKJLVBELUTLKV-UHFFFAOYSA-N 0.000 claims description 27
- QTBSBXVTEAMEQO-UHFFFAOYSA-N Acetic acid Chemical compound CC(O)=O QTBSBXVTEAMEQO-UHFFFAOYSA-N 0.000 claims description 18
- 239000003209 petroleum derivative Substances 0.000 claims description 18
- 229940093476 ethylene glycol Drugs 0.000 claims description 15
- KFZMGEQAYNKOFK-UHFFFAOYSA-N Isopropanol Chemical compound CC(C)O KFZMGEQAYNKOFK-UHFFFAOYSA-N 0.000 claims description 12
- FAPWRFPIFSIZLT-UHFFFAOYSA-M Sodium chloride Chemical compound [Na+].[Cl-] FAPWRFPIFSIZLT-UHFFFAOYSA-M 0.000 claims description 12
- 238000000034 method Methods 0.000 claims description 12
- ZMXDDKWLCZADIW-UHFFFAOYSA-N N,N-Dimethylformamide Chemical compound CN(C)C=O ZMXDDKWLCZADIW-UHFFFAOYSA-N 0.000 claims description 9
- KWYUFKZDYYNOTN-UHFFFAOYSA-M Potassium hydroxide Chemical compound [OH-].[K+] KWYUFKZDYYNOTN-UHFFFAOYSA-M 0.000 claims description 9
- HEMHJVSKTPXQMS-UHFFFAOYSA-M Sodium hydroxide Chemical group [OH-].[Na+] HEMHJVSKTPXQMS-UHFFFAOYSA-M 0.000 claims description 9
- KRKNYBCHXYNGOX-UHFFFAOYSA-N citric acid Chemical compound OC(=O)CC(O)(C(O)=O)CC(O)=O KRKNYBCHXYNGOX-UHFFFAOYSA-N 0.000 claims description 9
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 6
- CDBYLPFSWZWCQE-UHFFFAOYSA-L Sodium Carbonate Chemical compound [Na+].[Na+].[O-]C([O-])=O CDBYLPFSWZWCQE-UHFFFAOYSA-L 0.000 claims description 6
- ROOXNKNUYICQNP-UHFFFAOYSA-N ammonium persulfate Chemical compound [NH4+].[NH4+].[O-]S(=O)(=O)OOS([O-])(=O)=O ROOXNKNUYICQNP-UHFFFAOYSA-N 0.000 claims description 6
- BDAGIHXWWSANSR-UHFFFAOYSA-N methanoic acid Natural products OC=O BDAGIHXWWSANSR-UHFFFAOYSA-N 0.000 claims description 6
- BWHMMNNQKKPAPP-UHFFFAOYSA-L potassium carbonate Chemical compound [K+].[K+].[O-]C([O-])=O BWHMMNNQKKPAPP-UHFFFAOYSA-L 0.000 claims description 6
- 239000011780 sodium chloride Substances 0.000 claims description 6
- CWERGRDVMFNCDR-UHFFFAOYSA-N thioglycolic acid Chemical compound OC(=O)CS CWERGRDVMFNCDR-UHFFFAOYSA-N 0.000 claims description 6
- 229920002907 Guar gum Polymers 0.000 claims description 4
- 239000000665 guar gum Substances 0.000 claims description 4
- 235000010417 guar gum Nutrition 0.000 claims description 4
- 229960002154 guar gum Drugs 0.000 claims description 4
- PQUXFUBNSYCQAL-UHFFFAOYSA-N 1-(2,3-difluorophenyl)ethanone Chemical compound CC(=O)C1=CC=CC(F)=C1F PQUXFUBNSYCQAL-UHFFFAOYSA-N 0.000 claims description 3
- 239000001763 2-hydroxyethyl(trimethyl)azanium Substances 0.000 claims description 3
- OSWFIVFLDKOXQC-UHFFFAOYSA-N 4-(3-methoxyphenyl)aniline Chemical compound COC1=CC=CC(C=2C=CC(N)=CC=2)=C1 OSWFIVFLDKOXQC-UHFFFAOYSA-N 0.000 claims description 3
- HRPVXLWXLXDGHG-UHFFFAOYSA-N Acrylamide Chemical compound NC(=O)C=C HRPVXLWXLXDGHG-UHFFFAOYSA-N 0.000 claims description 3
- NLXLAEXVIDQMFP-UHFFFAOYSA-N Ammonia chloride Chemical compound [NH4+].[Cl-] NLXLAEXVIDQMFP-UHFFFAOYSA-N 0.000 claims description 3
- UXVMQQNJUSDDNG-UHFFFAOYSA-L Calcium chloride Chemical compound [Cl-].[Cl-].[Ca+2] UXVMQQNJUSDDNG-UHFFFAOYSA-L 0.000 claims description 3
- 235000019743 Choline chloride Nutrition 0.000 claims description 3
- SXRSQZLOMIGNAQ-UHFFFAOYSA-N Glutaraldehyde Chemical group O=CCCCC=O SXRSQZLOMIGNAQ-UHFFFAOYSA-N 0.000 claims description 3
- 239000004354 Hydroxyethyl cellulose Substances 0.000 claims description 3
- 229920000663 Hydroxyethyl cellulose Polymers 0.000 claims description 3
- SPAGIJMPHSUYSE-UHFFFAOYSA-N Magnesium peroxide Chemical compound [Mg+2].[O-][O-] SPAGIJMPHSUYSE-UHFFFAOYSA-N 0.000 claims description 3
- OKIZCWYLBDKLSU-UHFFFAOYSA-M N,N,N-Trimethylmethanaminium chloride Chemical compound [Cl-].C[N+](C)(C)C OKIZCWYLBDKLSU-UHFFFAOYSA-M 0.000 claims description 3
- 229920000142 Sodium polycarboxylate Polymers 0.000 claims description 3
- GSEJCLTVZPLZKY-UHFFFAOYSA-N Triethanolamine Chemical compound OCCN(CCO)CCO GSEJCLTVZPLZKY-UHFFFAOYSA-N 0.000 claims description 3
- QCWXUUIWCKQGHC-UHFFFAOYSA-N Zirconium Chemical compound [Zr] QCWXUUIWCKQGHC-UHFFFAOYSA-N 0.000 claims description 3
- YSVZGWAJIHWNQK-UHFFFAOYSA-N [3-(hydroxymethyl)-2-bicyclo[2.2.1]heptanyl]methanol Chemical compound C1CC2C(CO)C(CO)C1C2 YSVZGWAJIHWNQK-UHFFFAOYSA-N 0.000 claims description 3
- IKHGUXGNUITLKF-XPULMUKRSA-N acetaldehyde Chemical compound [14CH]([14CH3])=O IKHGUXGNUITLKF-XPULMUKRSA-N 0.000 claims description 3
- BIGPRXCJEDHCLP-UHFFFAOYSA-N ammonium bisulfate Chemical group [NH4+].OS([O-])(=O)=O BIGPRXCJEDHCLP-UHFFFAOYSA-N 0.000 claims description 3
- 229910001870 ammonium persulfate Inorganic materials 0.000 claims description 3
- ZGTNBBQKHJMUBI-UHFFFAOYSA-N bis[tetrakis(hydroxymethyl)-lambda5-phosphanyl] sulfate Chemical compound OCP(CO)(CO)(CO)OS(=O)(=O)OP(CO)(CO)(CO)CO ZGTNBBQKHJMUBI-UHFFFAOYSA-N 0.000 claims description 3
- 229910021538 borax Inorganic materials 0.000 claims description 3
- KGBXLFKZBHKPEV-UHFFFAOYSA-N boric acid Chemical compound OB(O)O KGBXLFKZBHKPEV-UHFFFAOYSA-N 0.000 claims description 3
- 239000004327 boric acid Substances 0.000 claims description 3
- 150000001642 boronic acid derivatives Chemical class 0.000 claims description 3
- 239000001110 calcium chloride Substances 0.000 claims description 3
- 229910001628 calcium chloride Inorganic materials 0.000 claims description 3
- SGMZJAMFUVOLNK-UHFFFAOYSA-M choline chloride Chemical compound [Cl-].C[N+](C)(C)CCO SGMZJAMFUVOLNK-UHFFFAOYSA-M 0.000 claims description 3
- 229960003178 choline chloride Drugs 0.000 claims description 3
- 229920001577 copolymer Polymers 0.000 claims description 3
- UQGFMSUEHSUPRD-UHFFFAOYSA-N disodium;3,7-dioxido-2,4,6,8,9-pentaoxa-1,3,5,7-tetraborabicyclo[3.3.1]nonane Chemical compound [Na+].[Na+].O1B([O-])OB2OB([O-])OB1O2 UQGFMSUEHSUPRD-UHFFFAOYSA-N 0.000 claims description 3
- IIRVGTWONXBBAW-UHFFFAOYSA-M disodium;dioxido(oxo)phosphanium Chemical compound [Na+].[Na+].[O-][P+]([O-])=O IIRVGTWONXBBAW-UHFFFAOYSA-M 0.000 claims description 3
- MOTZDAYCYVMXPC-UHFFFAOYSA-N dodecyl hydrogen sulfate Chemical group CCCCCCCCCCCCOS(O)(=O)=O MOTZDAYCYVMXPC-UHFFFAOYSA-N 0.000 claims description 3
- 229940043264 dodecyl sulfate Drugs 0.000 claims description 3
- 235000019253 formic acid Nutrition 0.000 claims description 3
- 150000004676 glycans Chemical class 0.000 claims description 3
- 235000019447 hydroxyethyl cellulose Nutrition 0.000 claims description 3
- 239000000395 magnesium oxide Substances 0.000 claims description 3
- CPLXHLVBOLITMK-UHFFFAOYSA-N magnesium oxide Inorganic materials [Mg]=O CPLXHLVBOLITMK-UHFFFAOYSA-N 0.000 claims description 3
- 229960004995 magnesium peroxide Drugs 0.000 claims description 3
- AXZKOIWUVFPNLO-UHFFFAOYSA-N magnesium;oxygen(2-) Chemical compound [O-2].[Mg+2] AXZKOIWUVFPNLO-UHFFFAOYSA-N 0.000 claims description 3
- 229920002401 polyacrylamide Polymers 0.000 claims description 3
- 229920001282 polysaccharide Polymers 0.000 claims description 3
- 239000005017 polysaccharide Substances 0.000 claims description 3
- 229910000027 potassium carbonate Inorganic materials 0.000 claims description 3
- JVUYWILPYBCNNG-UHFFFAOYSA-N potassium;oxido(oxo)borane Chemical compound [K+].[O-]B=O JVUYWILPYBCNNG-UHFFFAOYSA-N 0.000 claims description 3
- 229940047670 sodium acrylate Drugs 0.000 claims description 3
- 229910000029 sodium carbonate Inorganic materials 0.000 claims description 3
- 235000010352 sodium erythorbate Nutrition 0.000 claims description 3
- 239000004320 sodium erythorbate Substances 0.000 claims description 3
- 239000004328 sodium tetraborate Substances 0.000 claims description 3
- 235000010339 sodium tetraborate Nutrition 0.000 claims description 3
- RBWSWDPRDBEWCR-RKJRWTFHSA-N sodium;(2r)-2-[(2r)-3,4-dihydroxy-5-oxo-2h-furan-2-yl]-2-hydroxyethanolate Chemical compound [Na+].[O-]C[C@@H](O)[C@H]1OC(=O)C(O)=C1O RBWSWDPRDBEWCR-RKJRWTFHSA-N 0.000 claims description 3
- 229910052726 zirconium Inorganic materials 0.000 claims description 3
- 239000000126 substance Substances 0.000 abstract description 10
- 229930195733 hydrocarbon Natural products 0.000 abstract description 6
- 150000002430 hydrocarbons Chemical class 0.000 abstract description 6
- 239000011435 rock Substances 0.000 abstract description 6
- -1 proppants Substances 0.000 abstract description 5
- 239000004215 Carbon black (E152) Substances 0.000 abstract description 4
- 238000011109 contamination Methods 0.000 abstract 1
- 238000005755 formation reaction Methods 0.000 description 20
- VYPSYNLAJGMNEJ-UHFFFAOYSA-N Silicium dioxide Chemical compound O=[Si]=O VYPSYNLAJGMNEJ-UHFFFAOYSA-N 0.000 description 12
- 239000004576 sand Substances 0.000 description 7
- 239000000919 ceramic Substances 0.000 description 4
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 238000002347 injection Methods 0.000 description 3
- 239000007924 injection Substances 0.000 description 3
- 239000000463 material Substances 0.000 description 3
- 239000011324 bead Substances 0.000 description 2
- 239000011521 glass Substances 0.000 description 2
- 239000003345 natural gas Substances 0.000 description 2
- 239000000377 silicon dioxide Substances 0.000 description 2
- 102000004190 Enzymes Human genes 0.000 description 1
- 108090000790 Enzymes Proteins 0.000 description 1
- 240000007049 Juglans regia Species 0.000 description 1
- 235000009496 Juglans regia Nutrition 0.000 description 1
- 239000006004 Quartz sand Substances 0.000 description 1
- 239000003570 air Substances 0.000 description 1
- XAGFODPZIPBFFR-UHFFFAOYSA-N aluminium Chemical compound [Al] XAGFODPZIPBFFR-UHFFFAOYSA-N 0.000 description 1
- 229910052782 aluminium Inorganic materials 0.000 description 1
- 229910001570 bauxite Inorganic materials 0.000 description 1
- 230000007423 decrease Effects 0.000 description 1
- 238000005516 engineering process Methods 0.000 description 1
- 239000000945 filler Substances 0.000 description 1
- 239000006260 foam Substances 0.000 description 1
- 239000013505 freshwater Substances 0.000 description 1
- 239000000499 gel Substances 0.000 description 1
- 229910052500 inorganic mineral Inorganic materials 0.000 description 1
- 238000004519 manufacturing process Methods 0.000 description 1
- 239000011707 mineral Substances 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012544 monitoring process Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 229920003023 plastic Polymers 0.000 description 1
- 239000004033 plastic Substances 0.000 description 1
- 230000002265 prevention Effects 0.000 description 1
- 238000005086 pumping Methods 0.000 description 1
- 230000002285 radioactive effect Effects 0.000 description 1
- 238000004064 recycling Methods 0.000 description 1
- 239000011347 resin Substances 0.000 description 1
- 229920005989 resin Polymers 0.000 description 1
- 150000003839 salts Chemical class 0.000 description 1
- 239000000243 solution Substances 0.000 description 1
- 239000011800 void material Substances 0.000 description 1
- 235000020234 walnut Nutrition 0.000 description 1
- 239000002351 wastewater Substances 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
- C09K8/605—Compositions for stimulating production by acting on the underground formation containing biocides
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/25—Methods for stimulating production
- E21B43/26—Methods for stimulating production by forming crevices or fractures
- E21B43/2605—Methods for stimulating production by forming crevices or fractures using gas or liquefied gas
-
- 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
- C09K8/70—Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
Abstract
Hydraulic fracturing is commonly performed by injecting a liquid, gas or two-phase fluid down a well bore at sufficient pressure and flow rate to fracture the subterranean formation. The fluid injected into the rock is typically a slurry of water, proppants, and chemical additives. At the end of the fracturing treatment, the well is commonly flushed with water, and the injected fluid is recovered and treated to some degree. Although the concentrations of chemical additives are very low, the recovered fluid may be harmful due in part to hydrocarbon contamination.
The present invention presents a hydraulic fracturing treatment that is substantially free of water. Specifically, the present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a first additive.
The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The liquefied industrial gas mixture should be substantially free of water.
In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. The first additive may be a biocide.
In addition to the first additive, a proppant may be added to the fracturing fluid. In addition to the biocide and/or proppant, additional additives may be added to the liquefied industrial gas as required. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
The present invention presents a hydraulic fracturing treatment that is substantially free of water. Specifically, the present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a first additive.
The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The liquefied industrial gas mixture should be substantially free of water.
In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. The first additive may be a biocide.
In addition to the first additive, a proppant may be added to the fracturing fluid. In addition to the biocide and/or proppant, additional additives may be added to the liquefied industrial gas as required. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
Description
Serie 9189 LIQUEFIED INDUSTRIAL GAS BASED SOLUTION IN HYDRAULIC
FRACTURING
Technical Field This invention relates to a method of fracturing subterranean formations penetrated by a well bore utilizing liquid carbon dioxide or liquid nitrogen as the carrier for chemicals and/or biocides instead of water.
Background The treatment of subterranean formations penetrated by a well bore to stimulate the production of hydrocarbons therefrom or the ability of the formation to accept injected fluids has long been known in the art. One of the most common methods of increasing productivity of a hydrocarbon-bearing formation is to subject the formation to a fracturing treatment. This treatment is effected by injecting a liquid, gas or two-phase fluid which generally is referred to as a fracturing fluid down the well bore at sufficient pressure and flow rate to fracture the subterranean formation. A
proppant material such as sand, fine gravel, sintered bauxite, glass beads or the like can be introduced into the fractures to keep them open. The propped fracture provides larger flow channels through which an increased quantity of a hydrocarbon can flow, thereby increasing the productive capability of a well.
A traditional hydraulic fracturing technique utilizes a water or oil-based fluid to fracture a hydrocarbon-bearing formation.
Serie 9189 Summary The present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a first additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The first additive may be a biocide. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the first additive, a proppant may be added to the fracturing fluid. Non-limiting examples of a biocide include glutaraldehyde, quaternary ammonium chloride, tetrakis hydroxymethyl-phosphonium sulfate, or a combination thereof. In addition to the biocide and/or proppant additional additives may be added to the liquefied industrial gas as required. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
Non-limiting examples of a cross-linker include petroleum distillate, hydrotreated light petroleum distillate, potassium metaborate, triethanolamine zirconate, sodium tetraborate, boric acid, zirconium complex, borate salts, ethyleneglycol, methanol, or a combination thereof.
Non-limiting examples of a non-emulsifier include lauryl sulfate, isopronanol, ethylene glycol, or a combination thereof. Non-limiting examples of a pH
adjusting agent include sodium hydroxide, potassium hydroxide, acetic acid, sodium carbonate, potassium carbonate, or a combination thereof.
Non-limiting examples of an acid include hydrochloric acid. Non-limiting examples of a gelling agent include one or more of the following: guar gum, petroleum distillate, hydrotreated light petroleum distillate, methanol, polysaccharide blend, ethylene glycol, hydroxyethyl cellulose, or a combination thereof.
FRACTURING
Technical Field This invention relates to a method of fracturing subterranean formations penetrated by a well bore utilizing liquid carbon dioxide or liquid nitrogen as the carrier for chemicals and/or biocides instead of water.
Background The treatment of subterranean formations penetrated by a well bore to stimulate the production of hydrocarbons therefrom or the ability of the formation to accept injected fluids has long been known in the art. One of the most common methods of increasing productivity of a hydrocarbon-bearing formation is to subject the formation to a fracturing treatment. This treatment is effected by injecting a liquid, gas or two-phase fluid which generally is referred to as a fracturing fluid down the well bore at sufficient pressure and flow rate to fracture the subterranean formation. A
proppant material such as sand, fine gravel, sintered bauxite, glass beads or the like can be introduced into the fractures to keep them open. The propped fracture provides larger flow channels through which an increased quantity of a hydrocarbon can flow, thereby increasing the productive capability of a well.
A traditional hydraulic fracturing technique utilizes a water or oil-based fluid to fracture a hydrocarbon-bearing formation.
Serie 9189 Summary The present invention is a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas and a first additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. The first additive may be a biocide. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the first additive, a proppant may be added to the fracturing fluid. Non-limiting examples of a biocide include glutaraldehyde, quaternary ammonium chloride, tetrakis hydroxymethyl-phosphonium sulfate, or a combination thereof. In addition to the biocide and/or proppant additional additives may be added to the liquefied industrial gas as required. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
Non-limiting examples of a cross-linker include petroleum distillate, hydrotreated light petroleum distillate, potassium metaborate, triethanolamine zirconate, sodium tetraborate, boric acid, zirconium complex, borate salts, ethyleneglycol, methanol, or a combination thereof.
Non-limiting examples of a non-emulsifier include lauryl sulfate, isopronanol, ethylene glycol, or a combination thereof. Non-limiting examples of a pH
adjusting agent include sodium hydroxide, potassium hydroxide, acetic acid, sodium carbonate, potassium carbonate, or a combination thereof.
Non-limiting examples of an acid include hydrochloric acid. Non-limiting examples of a gelling agent include one or more of the following: guar gum, petroleum distillate, hydrotreated light petroleum distillate, methanol, polysaccharide blend, ethylene glycol, hydroxyethyl cellulose, or a combination thereof.
2 Serie 9189 Non-limiting examples of a breaker include one or more of the following:
ammonium persulfate, magnesium peroxide, magnesium oxide, calcium chloride, sodium chloride, or a combination thereof.
Non-limiting examples of a corrosion inhibitor include one or more of the following:
isopropanol , methanol , formic Acid , acetaldehyde, N,N-dimethyl formamide, or a combination thereof. Non-limiting examples of an oxygen scavenger include ammonium bisulfate.
Non-limiting examples of a surfactant include isopropanol. Non-limiting examples of a clay stabilizer include one or more of the following: choline chloride, tetramethyl ammonium chloride, sodium chloride, or a combination thereof.
Non-limiting examples of a friction reducer include one or more of the following:
polyacrylamide, petroleum distillate, hydrotreated light petroleum distillate, methanol, ethylene glycol, or a combination thereof.
Non-limiting examples of a scale inhibitor include one or more of the following:
ethylene glycol, copolymer of acrylamide and sodium acrylate, sodium polycarboxylate, phosphonic acid salt, or a combination thereof.
Non-limiting examples of an iron controller include one or more of the following: citric acid, acetic acid, thioglycolic acid, 2-hydroxy 1, 2, 3-propaneticoboxylic acid, sodium erythorbate, or a combination thereof.
In accordance with another aspect of the present invention, there is provided a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a first additive, and a proppant, wherein said liquefied industrial gas, and said first additive are substantially free of water.
2a Serie 9189 In accordance with another aspect of the present invention, there is provided the cryogenic subterranean fracturing fluid wherein said first additive is introduced into said liquefied industrial gas prior to said introduction into said formation, and stored in admixed liquid form.
In accordance with another aspect of the present invention, there is provided the cryogenic subterranean fracturing fluid wherein said first additive is introduced into said liquid carbon dioxide In such a way as to form miscible liquid with liquid carbon dioxide.
In accordance with another aspect of the present invention, there is provided the cryogenic subterranean fracturing fluid wherein said first additive is introduced into said liquid nitrogen in such a way as to form discrete, frozen masses, thereby producing a slurry with the liquid nitrogen.
In accordance with another aspect of the present invention, there is provided a method of fracturing a subterranean formation penetrated by a well bore comprising:
introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation.
In accordance with another aspect of the present invention, there is provided a method of fracturing a subterranean formation penetrated by a well bore comprising:
introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation, wherein said cryogenic subterranean fracturing fluid is substantially free of water.
Description of Preferred Embodiments Illustrative embodiments of the invention are described below. While particular embodiments of the present invention have been described, it would be obvious to those skilled in the art that various other changes and modifications can be made.
2b Serie 9189 The scope of the claims should not be limited by the embodiments set forth in the description, but should be given the broadest interpretation consistent with the specification as a whole.
It will of course be appreciated that in the development of any such actual embodiment, numerous implementation-specific decisions must be made to achieve the developer's specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another.
Moreover, it will be appreciated that such a development effort might be complex 2c Serie 9189 and time-consuming, but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.
A hydraulic fracture is formed by pumping the fracturing fluid into the wellbore at a rate sufficient to increase pressure downhole to exceed that of the fracture gradient of the rock. The rock cracks and the fracture fluid continues farther into the rock, extending the crack still farther, and so on. Operators typically try to maintain "fracture width", or slow its decline, following treatment by introducing a proppant into the injected fluid, a material, such as grains of sand, ceramic, or other particulates, that prevent the fractures from closing when the injection is stopped.
Consideration of proppant strengths and prevention of proppant failure becomes more important at deeper depths where pressure and stresses on fractures are higher. The propped fracture is permeable enough to allow the flow of formation fluids to the well. Formation fluids include gas, oil, salt water, fresh water and fluids introduced to the formation during completion of the well during fracturing.
The location of one or more fractures along the length of the borehole is strictly controlled by various different methods which create or seal-off holes in the side of the wellbore. Typically, hydraulic fracturing is performed in cased wellbores and the zones to be fractured are accessed by perforating the casing at those locations.
The fluid injected into the rock is typically a slurry of water, proppants, and chemical additives. Additionally, gels, foams, and compressed gases, including nitrogen, carbon dioxide and air can be injected.
Various types of proppant include silica sand, resin-coated sand, and man-made ceramics. These vary depending on the type of permeability or grain strength needed. The most commonly utilized proppant is silica sand. However, proppants of uniform size and shape, such as a ceramic proppant, is believed to be more effective. Due to a higher porosity within the fracture, a greater amount of oil and natural gas is liberated. Sand containing naturally radioactive minerals is sometimes used so that the fracture trace along the wellbore can be measured.
ammonium persulfate, magnesium peroxide, magnesium oxide, calcium chloride, sodium chloride, or a combination thereof.
Non-limiting examples of a corrosion inhibitor include one or more of the following:
isopropanol , methanol , formic Acid , acetaldehyde, N,N-dimethyl formamide, or a combination thereof. Non-limiting examples of an oxygen scavenger include ammonium bisulfate.
Non-limiting examples of a surfactant include isopropanol. Non-limiting examples of a clay stabilizer include one or more of the following: choline chloride, tetramethyl ammonium chloride, sodium chloride, or a combination thereof.
Non-limiting examples of a friction reducer include one or more of the following:
polyacrylamide, petroleum distillate, hydrotreated light petroleum distillate, methanol, ethylene glycol, or a combination thereof.
Non-limiting examples of a scale inhibitor include one or more of the following:
ethylene glycol, copolymer of acrylamide and sodium acrylate, sodium polycarboxylate, phosphonic acid salt, or a combination thereof.
Non-limiting examples of an iron controller include one or more of the following: citric acid, acetic acid, thioglycolic acid, 2-hydroxy 1, 2, 3-propaneticoboxylic acid, sodium erythorbate, or a combination thereof.
In accordance with another aspect of the present invention, there is provided a cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a first additive, and a proppant, wherein said liquefied industrial gas, and said first additive are substantially free of water.
2a Serie 9189 In accordance with another aspect of the present invention, there is provided the cryogenic subterranean fracturing fluid wherein said first additive is introduced into said liquefied industrial gas prior to said introduction into said formation, and stored in admixed liquid form.
In accordance with another aspect of the present invention, there is provided the cryogenic subterranean fracturing fluid wherein said first additive is introduced into said liquid carbon dioxide In such a way as to form miscible liquid with liquid carbon dioxide.
In accordance with another aspect of the present invention, there is provided the cryogenic subterranean fracturing fluid wherein said first additive is introduced into said liquid nitrogen in such a way as to form discrete, frozen masses, thereby producing a slurry with the liquid nitrogen.
In accordance with another aspect of the present invention, there is provided a method of fracturing a subterranean formation penetrated by a well bore comprising:
introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation.
In accordance with another aspect of the present invention, there is provided a method of fracturing a subterranean formation penetrated by a well bore comprising:
introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation, wherein said cryogenic subterranean fracturing fluid is substantially free of water.
Description of Preferred Embodiments Illustrative embodiments of the invention are described below. While particular embodiments of the present invention have been described, it would be obvious to those skilled in the art that various other changes and modifications can be made.
2b Serie 9189 The scope of the claims should not be limited by the embodiments set forth in the description, but should be given the broadest interpretation consistent with the specification as a whole.
It will of course be appreciated that in the development of any such actual embodiment, numerous implementation-specific decisions must be made to achieve the developer's specific goals, such as compliance with system-related and business-related constraints, which will vary from one implementation to another.
Moreover, it will be appreciated that such a development effort might be complex 2c Serie 9189 and time-consuming, but would nevertheless be a routine undertaking for those of ordinary skill in the art having the benefit of this disclosure.
A hydraulic fracture is formed by pumping the fracturing fluid into the wellbore at a rate sufficient to increase pressure downhole to exceed that of the fracture gradient of the rock. The rock cracks and the fracture fluid continues farther into the rock, extending the crack still farther, and so on. Operators typically try to maintain "fracture width", or slow its decline, following treatment by introducing a proppant into the injected fluid, a material, such as grains of sand, ceramic, or other particulates, that prevent the fractures from closing when the injection is stopped.
Consideration of proppant strengths and prevention of proppant failure becomes more important at deeper depths where pressure and stresses on fractures are higher. The propped fracture is permeable enough to allow the flow of formation fluids to the well. Formation fluids include gas, oil, salt water, fresh water and fluids introduced to the formation during completion of the well during fracturing.
The location of one or more fractures along the length of the borehole is strictly controlled by various different methods which create or seal-off holes in the side of the wellbore. Typically, hydraulic fracturing is performed in cased wellbores and the zones to be fractured are accessed by perforating the casing at those locations.
The fluid injected into the rock is typically a slurry of water, proppants, and chemical additives. Additionally, gels, foams, and compressed gases, including nitrogen, carbon dioxide and air can be injected.
Various types of proppant include silica sand, resin-coated sand, and man-made ceramics. These vary depending on the type of permeability or grain strength needed. The most commonly utilized proppant is silica sand. However, proppants of uniform size and shape, such as a ceramic proppant, is believed to be more effective. Due to a higher porosity within the fracture, a greater amount of oil and natural gas is liberated. Sand containing naturally radioactive minerals is sometimes used so that the fracture trace along the wellbore can be measured.
3 Serie 9189 Chemical additives are applied to tailor the injected material to the specific geological situation, protect the well, and improve its operation, though the injected fluid is approximately 98-99.5% water, varying slightly based on the type of well. The composition of injected fluid is sometimes changed as the fracturing job proceeds.
Often, acid is initially used to scour the perforations and clean up the near-wellbore area. Afterward, high pressure fracture fluid is injected into the wellbore, with the pressure above the fracture gradient of the rock. This fracture fluid contains water-soluble gelling agents (such as guar gum) which increase viscosity and efficiently =
deliver the proppant into the formation. As the fracturing process proceeds, viscosity reducing agents such as oxidizers and enzyme breakers are sometimes then added to the fracturing fluid to deactivate the gelling agents and encourage flowback. The proppant's purpose is primarily to provide a permeable and permanent filler to fill the void created during the fracturing process.
At the end of the job the well is commonly flushed with water (sometimes blended with a friction reducing chemical) under pressure. Injected fluid is to some degree recovered and is managed by several methods, such as underground injection control, treatment and discharge, recycling, or temporary storage in pits or containers while new technology is being developed to better handle wastewater and improve reusability. Although the concentrations of the chemical additives are very low, the recovered fluid may be harmful due in part to hydrocarbons picked up from the formation.
Hydraulic fracturing equipment used in oil and natural gas fields usually consists of a slurry blender, one or more high pressure, high volume fracturing pumps (typically powerful triplex, or quintiplex pumps) and a monitoring unit. Associated equipment includes fracturing tanks, one or more units for storage and handling of proppant, high pressure treating iron, a chemical additive unit (used to accurately monitor chemical addition), low pressure flexible hoses, and many gauges and meters for flow rate, fluid density, and treating pressure. Fracturing equipment operates over a
Often, acid is initially used to scour the perforations and clean up the near-wellbore area. Afterward, high pressure fracture fluid is injected into the wellbore, with the pressure above the fracture gradient of the rock. This fracture fluid contains water-soluble gelling agents (such as guar gum) which increase viscosity and efficiently =
deliver the proppant into the formation. As the fracturing process proceeds, viscosity reducing agents such as oxidizers and enzyme breakers are sometimes then added to the fracturing fluid to deactivate the gelling agents and encourage flowback. The proppant's purpose is primarily to provide a permeable and permanent filler to fill the void created during the fracturing process.
At the end of the job the well is commonly flushed with water (sometimes blended with a friction reducing chemical) under pressure. Injected fluid is to some degree recovered and is managed by several methods, such as underground injection control, treatment and discharge, recycling, or temporary storage in pits or containers while new technology is being developed to better handle wastewater and improve reusability. Although the concentrations of the chemical additives are very low, the recovered fluid may be harmful due in part to hydrocarbons picked up from the formation.
Hydraulic fracturing equipment used in oil and natural gas fields usually consists of a slurry blender, one or more high pressure, high volume fracturing pumps (typically powerful triplex, or quintiplex pumps) and a monitoring unit. Associated equipment includes fracturing tanks, one or more units for storage and handling of proppant, high pressure treating iron, a chemical additive unit (used to accurately monitor chemical addition), low pressure flexible hoses, and many gauges and meters for flow rate, fluid density, and treating pressure. Fracturing equipment operates over a
4 Serie 9189 range of pressures and injection rates, and can reach up to 100 megapascals (15,000 psi) and 265 litres per second (9.4 cu ft/s) (100 barrels per minute).
The present invention is a cryogenic subterranean fracturing fluid, that includes at least a liquefied industrial gas and a first additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. Other liquefied industrial gases may be included in a mixture, but the primary components will be liquefied carbon dioxide or liquefied nitrogen. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the first additive, a proppant may be added to the fracturing fluid.
As discussed above, in hydraulic or gas fracturing, a number of additives are routinely added as the particular site requires. In the present invention, the first additive may be a biocide. The biocide may be any chemical known to one of ordinary skill in the art. Non-limiting examples of such biocides include glutaraldehyde, quaternary ammonium chloride, tetrakis hydroxymethyl-phosphonium sulfate, or a combination thereof.
In addition to the first additive, a proppant may be added to the fracturing fluid. Any proppant known in the art may be used. Non-limiting examples of such proppants include quartz sand, aluminum balls, walnut shells, glass beads, plastic balls, ceramic, and resin-clad sand.
In addition to the biocide and/or proppant, a second additive, or additional additives, may be added to the liquefied industrial gas as required. Any additional additives known in the art may be added. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
The present invention is a cryogenic subterranean fracturing fluid, that includes at least a liquefied industrial gas and a first additive. The liquefied industrial gas may be liquefied carbon dioxide, liquefied nitrogen, or a blend of the two. Other liquefied industrial gases may be included in a mixture, but the primary components will be liquefied carbon dioxide or liquefied nitrogen. The liquefied industrial gas mixture should be substantially free of water. In this context, substantially free of water means less than 10% water by volume, or preferably less than 5% water by volume. In addition to the first additive, a proppant may be added to the fracturing fluid.
As discussed above, in hydraulic or gas fracturing, a number of additives are routinely added as the particular site requires. In the present invention, the first additive may be a biocide. The biocide may be any chemical known to one of ordinary skill in the art. Non-limiting examples of such biocides include glutaraldehyde, quaternary ammonium chloride, tetrakis hydroxymethyl-phosphonium sulfate, or a combination thereof.
In addition to the first additive, a proppant may be added to the fracturing fluid. Any proppant known in the art may be used. Non-limiting examples of such proppants include quartz sand, aluminum balls, walnut shells, glass beads, plastic balls, ceramic, and resin-clad sand.
In addition to the biocide and/or proppant, a second additive, or additional additives, may be added to the liquefied industrial gas as required. Any additional additives known in the art may be added. Non-limiting examples of such additives include ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
5 Serie 9189 The combination of liquefied industrial gas, proppant, biocide and any additional additives should be substantially free of water.
The additives may be introduced into the liquefied industrial gas prior to the introduction into said formation, and stored in admixed liquid form. The additives may introduced into the liquid nitrogen in such a way as to form discrete, frozen masses, thereby producing a slurry with the liquid nitrogen. The additives may be introduced into the liquid carbon dioxide in such a way as to form miscible liquid with the liquid carbon dioxide.
Any cross-linker known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such cross-linkers include petroleum distillate, hydrotreated light petroleum distillate, potassium metaborate, triethanolamine zirconate, sodium tetraborate, boric acid, zirconium complex, borate salts, ethylene glycol, methanol, or a combination thereof.
Any non-emulsifier known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such non-emulsifiers include non-emulsifiers lauryl sulfate, isopronanol, ethylene glycol, or a combination thereof.
Any pH adjusting agent known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such pH adjusting agents include is sodium hydroxide, potassium hydroxide, acetic acid, sodium carbonate, potassium carbonate, or a combination thereof.
Any acid known to one skilled in the art may added, as needed, to the liquefied industrial gas. A non-limiting example of such an acid is hydrochloric acid.
The additives may be introduced into the liquefied industrial gas prior to the introduction into said formation, and stored in admixed liquid form. The additives may introduced into the liquid nitrogen in such a way as to form discrete, frozen masses, thereby producing a slurry with the liquid nitrogen. The additives may be introduced into the liquid carbon dioxide in such a way as to form miscible liquid with the liquid carbon dioxide.
Any cross-linker known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such cross-linkers include petroleum distillate, hydrotreated light petroleum distillate, potassium metaborate, triethanolamine zirconate, sodium tetraborate, boric acid, zirconium complex, borate salts, ethylene glycol, methanol, or a combination thereof.
Any non-emulsifier known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such non-emulsifiers include non-emulsifiers lauryl sulfate, isopronanol, ethylene glycol, or a combination thereof.
Any pH adjusting agent known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such pH adjusting agents include is sodium hydroxide, potassium hydroxide, acetic acid, sodium carbonate, potassium carbonate, or a combination thereof.
Any acid known to one skilled in the art may added, as needed, to the liquefied industrial gas. A non-limiting example of such an acid is hydrochloric acid.
6 Serie 9189 Any gelling agent known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such gelling agents include guar gum, petroleum distillate, hydrotreated light petroleum distillate, methanol, polysaccharide blend, ethylene glycol, hydroxyethyl cellulose, or a combination thereof.
Any breaker known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such breakers include ammonium persulfate, magnesium peroxide, magnesium oxide, calcium chloride, sodium chloride, or a combination thereof.
Any corrosion inhibiter known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such corrosion inhibitor include isopropanol , methanol , formic Acid , acetaldehyde, N,N-dimethyl formamide, or a combination thereof.
Any oxygen scavenger known to one skilled in the art may added, as needed, to the liquefied industrial gas. A non-limiting example of such a corrosion inhibitor is ammonium bisulfate.
Any surfactant known to one skilled in the art may added, as needed, to the liquefied industrial gas. A non-limiting example of such a surfactant is isopropanol.
Any clay stabilizer known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such clay stabilizer include choline chloride, tetramethyl ammonium chloride, sodium chloride, or a combination thereof.
Any friction reducer known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such friction reducer include
Any breaker known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such breakers include ammonium persulfate, magnesium peroxide, magnesium oxide, calcium chloride, sodium chloride, or a combination thereof.
Any corrosion inhibiter known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such corrosion inhibitor include isopropanol , methanol , formic Acid , acetaldehyde, N,N-dimethyl formamide, or a combination thereof.
Any oxygen scavenger known to one skilled in the art may added, as needed, to the liquefied industrial gas. A non-limiting example of such a corrosion inhibitor is ammonium bisulfate.
Any surfactant known to one skilled in the art may added, as needed, to the liquefied industrial gas. A non-limiting example of such a surfactant is isopropanol.
Any clay stabilizer known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such clay stabilizer include choline chloride, tetramethyl ammonium chloride, sodium chloride, or a combination thereof.
Any friction reducer known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such friction reducer include
7 Serie 9189 polyacrylamide, petroleum distillate, hydrotreated light petroleum distillate, methanol, ethylene glycol, or a combination thereof.
Any scale inhibiter known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such scale inhibitor include ethylene glycol, copolymer of acrylamide and sodium acrylate, sodium polycarboxylate, phosphonic acid salt, or a combination thereof.
Any iron controller known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such iron controller include citric acid, acetic acid, thioglycolic acid, 2-hydroxy 1, 2, 3-propaneticoboxylic acid, sodium erythorbate, or a combination thereof.
This invention also includes a method of fracturing a subterranean formation penetrated by a well bore comprising: introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation.
Any scale inhibiter known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such scale inhibitor include ethylene glycol, copolymer of acrylamide and sodium acrylate, sodium polycarboxylate, phosphonic acid salt, or a combination thereof.
Any iron controller known to one skilled in the art may added, as needed, to the liquefied industrial gas. Non-limiting examples of such iron controller include citric acid, acetic acid, thioglycolic acid, 2-hydroxy 1, 2, 3-propaneticoboxylic acid, sodium erythorbate, or a combination thereof.
This invention also includes a method of fracturing a subterranean formation penetrated by a well bore comprising: introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation.
8
Claims
What is claimed is:
Claim 1: A cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a first additive, and a proppant, wherein said liquefied industrial gas, and said first additive are substantially free of water.
Claim 2: The cryogenic subterranean fracturing fluid of claim 1, wherein there is less than 5% water by volume.
Claim 3: The cryogenic subterranean fracturing fluid of claim 1, wherein said first additive is a biocide.
Claim 4: The cryogenic subterranean fracturing fluid of claim 3, further comprising at least a second additive.
Claim 5: The cryogenic subterranean fracturing fluid of claim 4, wherein there is less than 5% water by volume.
Claim 6: The cryogenic subterranean fracturing fluid of claim 4, wherein said first additive is introduced into said liquefied industrial gas prior to said introduction into said formation, and stored in admixed liquid form.
Claim 7: The cryogenic subterranean fracturing fluid of claim 1, wherein said liquefied industrial gas is liquid carbon dioxide.
Claim 8: The cryogenic subterranean fracturing fluid of claim 1, wherein said liquefied industrial gas is liquid nitrogen.
Claim 9: The cryogenic subterranean fracturing fluid of claim 1, wherein said liquefied industrial gas is a combination of liquid carbon dioxide and liquid nitrogen.
Claim 10: The cryogenic subterranean fracturing fluid of claim 7, wherein said first additive is introduced into said liquid carbon dioxide In such a way as to form miscible liquid with liquid carbon dioxide.
Claim 11: The cryogenic subterranean fracturing fluid of claim 8, wherein said first additive is introduced into said liquid nitrogen in such a way as to form discrete, frozen masses, thereby producing a slurry with the liquid nitrogen.
Claim 12: The cryogenic subterranean fracturing fluid of claim 3, wherein said biocide is glutaraldehyde, quaternary ammonium chloride, tetrakis hydroxymethyl-phosphonium sulfate, or a combination thereof.
Claim 13: The cryogenic subterranean fracturing fluid of claim 4, wherein said second additive comprises one or more of the following: ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
Claim 14: The cryogenic subterranean fracturing fluid of claim 13, where said cross-linker is petroleum distillate, hydrotreated light petroleum distillate, potassium metaborate, triethanolamine zirconate, sodium tetraborate, boric acid, zirconium complex, borate salts, ethyleneglycol, methanol, or a combination thereof.
Claim 15: The cryogenic subterranean fracturing fluid of claim 13, where said non-emulsifier is lauryl sulfate, isopronanol, ethylene glycol, or a combination thereof.
Claim 16: The cryogenic subterranean fracturing fluid of claim 13, where said pH
adjusting agent is sodium hydroxide, potassium hydroxide, acetic acid, sodium carbonate, potassium carbonate, or a combination thereof.
Claim 17: The cryogenic subterranean fracturing fluid of claim 13, wherein said acid is hydrochloric acid.
Claim 18: The cryogenic subterranean fracturing fluid of claim 13, wherein said gelling agent comprises one or more of the following: guar gum, petroleum distillate, hydrotreated light petroleum distillate, methanol, polysaccharide blend, ethylene glycol, hydroxyethyl cellulose, or a combination thereof.
Claim 19: The cryogenic subterranean fracturing fluid of claim 13, wherein said breaker comprises one or more of the following: ammonium persulfate, magnesium peroxide, magnesium oxide, calcium chloride, sodium chloride, or a combination thereof.
Claim 20: The cryogenic subterranean fracturing fluid of claim 13, wherein said corrosion inhibitor comprises one or more of the following: isopropanol , methanol , formic Acid , acetaldehyde , N,N-dimethyl formamide, or a combination thereof.
Claim 21: The cryogenic subterranean fracturing fluid of claim 13, wherein said oxygen scavenger is ammonium bisulfate.
Claim 22: The cryogenic subterranean fracturing fluid of claim 13, wherein said surfactant is isopropanol.
Claim 23: The cryogenic subterranean fracturing fluid of claim 13, wherein said clay stabilizer comprises one or more of the following: choline chloride, tetramethyl ammonium chloride, sodium chloride, or a combination thereof.
Claim 24: The cryogenic subterranean fracturing fluid of claim 13, wherein said friction reducer comprises one or more of the following: polyacrylamide, petroleum distillate, hydrotreated light petroleum distillate, methanol, ethylene glycol, or a combination thereof.
Claim 25: The cryogenic subterranean fracturing fluid of claim 13, wherein said scale inhibitor comprises one or more of the following: ethylene glycol, copolymer of acrylamide and sodium acrylate, sodium polycarboxylate, phosphonic acid salt, or a combination thereof.
Claim 26: The cryogenic subterranean fracturing fluid of claim 13, wherein said iron controller comprises one or more of the following: citric acid, acetic acid, thioglycolic acid, 2-hydroxy 1, 2, 3-propaneticoboxylic acid, sodium erythorbate, or a combination thereof.
Claim 27: A method of fracturing a subterranean formation penetrated by a well bore comprising: introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation.
Claim 28: A method of fracturing a subterranean formation penetrated by a well bore comprising: introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation, wherein said cryogenic subterranean fracturing fluid is substantially free of water.
Claim 1: A cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a first additive, and a proppant, wherein said liquefied industrial gas, and said first additive are substantially free of water.
Claim 2: The cryogenic subterranean fracturing fluid of claim 1, wherein there is less than 5% water by volume.
Claim 3: The cryogenic subterranean fracturing fluid of claim 1, wherein said first additive is a biocide.
Claim 4: The cryogenic subterranean fracturing fluid of claim 3, further comprising at least a second additive.
Claim 5: The cryogenic subterranean fracturing fluid of claim 4, wherein there is less than 5% water by volume.
Claim 6: The cryogenic subterranean fracturing fluid of claim 4, wherein said first additive is introduced into said liquefied industrial gas prior to said introduction into said formation, and stored in admixed liquid form.
Claim 7: The cryogenic subterranean fracturing fluid of claim 1, wherein said liquefied industrial gas is liquid carbon dioxide.
Claim 8: The cryogenic subterranean fracturing fluid of claim 1, wherein said liquefied industrial gas is liquid nitrogen.
Claim 9: The cryogenic subterranean fracturing fluid of claim 1, wherein said liquefied industrial gas is a combination of liquid carbon dioxide and liquid nitrogen.
Claim 10: The cryogenic subterranean fracturing fluid of claim 7, wherein said first additive is introduced into said liquid carbon dioxide In such a way as to form miscible liquid with liquid carbon dioxide.
Claim 11: The cryogenic subterranean fracturing fluid of claim 8, wherein said first additive is introduced into said liquid nitrogen in such a way as to form discrete, frozen masses, thereby producing a slurry with the liquid nitrogen.
Claim 12: The cryogenic subterranean fracturing fluid of claim 3, wherein said biocide is glutaraldehyde, quaternary ammonium chloride, tetrakis hydroxymethyl-phosphonium sulfate, or a combination thereof.
Claim 13: The cryogenic subterranean fracturing fluid of claim 4, wherein said second additive comprises one or more of the following: ozone, a friction reducer, an acid, a gelling agent, a breaker, a scale inhibitor, a clay stabilizer, a corrosion inhibitor, an iron controller, an oxygen scavenger, a surfactant, a cross-linker, a non-emulsifier, a pH adjusting agent, or any combination thereof.
Claim 14: The cryogenic subterranean fracturing fluid of claim 13, where said cross-linker is petroleum distillate, hydrotreated light petroleum distillate, potassium metaborate, triethanolamine zirconate, sodium tetraborate, boric acid, zirconium complex, borate salts, ethyleneglycol, methanol, or a combination thereof.
Claim 15: The cryogenic subterranean fracturing fluid of claim 13, where said non-emulsifier is lauryl sulfate, isopronanol, ethylene glycol, or a combination thereof.
Claim 16: The cryogenic subterranean fracturing fluid of claim 13, where said pH
adjusting agent is sodium hydroxide, potassium hydroxide, acetic acid, sodium carbonate, potassium carbonate, or a combination thereof.
Claim 17: The cryogenic subterranean fracturing fluid of claim 13, wherein said acid is hydrochloric acid.
Claim 18: The cryogenic subterranean fracturing fluid of claim 13, wherein said gelling agent comprises one or more of the following: guar gum, petroleum distillate, hydrotreated light petroleum distillate, methanol, polysaccharide blend, ethylene glycol, hydroxyethyl cellulose, or a combination thereof.
Claim 19: The cryogenic subterranean fracturing fluid of claim 13, wherein said breaker comprises one or more of the following: ammonium persulfate, magnesium peroxide, magnesium oxide, calcium chloride, sodium chloride, or a combination thereof.
Claim 20: The cryogenic subterranean fracturing fluid of claim 13, wherein said corrosion inhibitor comprises one or more of the following: isopropanol , methanol , formic Acid , acetaldehyde , N,N-dimethyl formamide, or a combination thereof.
Claim 21: The cryogenic subterranean fracturing fluid of claim 13, wherein said oxygen scavenger is ammonium bisulfate.
Claim 22: The cryogenic subterranean fracturing fluid of claim 13, wherein said surfactant is isopropanol.
Claim 23: The cryogenic subterranean fracturing fluid of claim 13, wherein said clay stabilizer comprises one or more of the following: choline chloride, tetramethyl ammonium chloride, sodium chloride, or a combination thereof.
Claim 24: The cryogenic subterranean fracturing fluid of claim 13, wherein said friction reducer comprises one or more of the following: polyacrylamide, petroleum distillate, hydrotreated light petroleum distillate, methanol, ethylene glycol, or a combination thereof.
Claim 25: The cryogenic subterranean fracturing fluid of claim 13, wherein said scale inhibitor comprises one or more of the following: ethylene glycol, copolymer of acrylamide and sodium acrylate, sodium polycarboxylate, phosphonic acid salt, or a combination thereof.
Claim 26: The cryogenic subterranean fracturing fluid of claim 13, wherein said iron controller comprises one or more of the following: citric acid, acetic acid, thioglycolic acid, 2-hydroxy 1, 2, 3-propaneticoboxylic acid, sodium erythorbate, or a combination thereof.
Claim 27: A method of fracturing a subterranean formation penetrated by a well bore comprising: introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation.
Claim 28: A method of fracturing a subterranean formation penetrated by a well bore comprising: introducing cryogenic subterranean fracturing fluid, comprising a liquefied industrial gas, a proppant, and at least a first additive into said formation, wherein said cryogenic subterranean fracturing fluid is substantially free of water.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2777449A CA2777449C (en) | 2012-05-17 | 2012-05-17 | Liquefied industrial gas based solution in hydraulic fracturing |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2777449A CA2777449C (en) | 2012-05-17 | 2012-05-17 | Liquefied industrial gas based solution in hydraulic fracturing |
Publications (2)
| Publication Number | Publication Date |
|---|---|
| CA2777449A1 CA2777449A1 (en) | 2013-11-17 |
| CA2777449C true CA2777449C (en) | 2015-12-15 |
Family
ID=49626691
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA2777449A Active CA2777449C (en) | 2012-05-17 | 2012-05-17 | Liquefied industrial gas based solution in hydraulic fracturing |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2777449C (en) |
Families Citing this family (5)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CA2938313A1 (en) * | 2014-02-13 | 2015-08-20 | KMP Holdings, LLC | Aqueous emulsions for crosslinking |
| CN108641695B (en) * | 2018-06-13 | 2020-07-07 | 中国石油工程建设有限公司 | Corrosion inhibition bactericide for shale gas field |
| CN108659804B (en) * | 2018-06-13 | 2020-06-30 | 西南石油大学 | Clay anti-swelling agent with oil washing and sterilization effects for water injection |
| CN109057766A (en) * | 2018-10-18 | 2018-12-21 | 中国石油大学(北京) | Liquid nitrogen fracturing process and device |
| CN112878972B (en) * | 2021-01-19 | 2022-09-20 | 中国石油大学(北京) | Liquid nitrogen pulse fracturing system and fracturing method |
-
2012
- 2012-05-17 CA CA2777449A patent/CA2777449C/en active Active
Also Published As
| Publication number | Publication date |
|---|---|
| CA2777449A1 (en) | 2013-11-17 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| WO2013173725A2 (en) | Liquefied industrial gas based solution in hydraulic fracturing | |
| CN110809662B (en) | Improving the flow conductivity of acid cracks | |
| US9243182B2 (en) | Hydraulic fracturing with improved viscosity liquefied industrial gas based solution | |
| US7044224B2 (en) | Permeable cement and methods of fracturing utilizing permeable cement in subterranean well bores | |
| CA2901517C (en) | Method of enhancing the complexity of a fracture network within a subterranean formation | |
| NO20171076A1 (en) | Compositions and methods of improving hydraulic fracture network | |
| US10066157B2 (en) | Injecting polyelectrolyte based sacrificial agents for use in unconventional formations | |
| CA2777449C (en) | Liquefied industrial gas based solution in hydraulic fracturing | |
| EP2513420B1 (en) | Fracture fluid compositions comprising a mixture of mono and divalent cations and their methods of use in hydraulic fracturing of subterranean formations | |
| WO2017131707A1 (en) | Polylactic acid/acid-soluble hard particulate blends as degradable diverting agents | |
| US10421893B2 (en) | Encapsulated scale inhibitor for downhole applications in subterranean formations | |
| US10093850B2 (en) | Activator for breaking system in high-temperature fracturing fluids | |
| US11391139B2 (en) | Staged propping of fracture networks | |
| US11578259B1 (en) | Energized fracturing fluid by generation of nitrogen gas | |
| US10590335B2 (en) | Methods,treatment fluids and systems utilizing a particulate pack for acidizing a siliceous material | |
| US20150361777A1 (en) | Simultaneous injection of an acidic well treatment fluid and a proppant into a subterranean formation |