CA2478622A1 - Oil based drilling fluid - Google Patents
Oil based drilling fluid Download PDFInfo
- Publication number
- CA2478622A1 CA2478622A1 CA002478622A CA2478622A CA2478622A1 CA 2478622 A1 CA2478622 A1 CA 2478622A1 CA 002478622 A CA002478622 A CA 002478622A CA 2478622 A CA2478622 A CA 2478622A CA 2478622 A1 CA2478622 A1 CA 2478622A1
- Authority
- CA
- Canada
- Prior art keywords
- oil
- drilling fluid
- drilling
- base oil
- cuttings
- 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.)
- Abandoned
Links
- 238000005553 drilling Methods 0.000 title claims abstract description 65
- 239000012530 fluid Substances 0.000 title claims abstract description 32
- 238000000034 method Methods 0.000 claims abstract description 17
- 239000004215 Carbon black (E152) Substances 0.000 claims abstract description 11
- 229930195733 hydrocarbon Natural products 0.000 claims abstract description 11
- 150000002430 hydrocarbons Chemical class 0.000 claims abstract description 11
- 239000003921 oil Substances 0.000 claims description 44
- 239000002199 base oil Substances 0.000 claims description 20
- 239000010426 asphalt Substances 0.000 claims description 17
- 238000005520 cutting process Methods 0.000 claims description 10
- 239000003795 chemical substances by application Substances 0.000 claims description 8
- 125000003118 aryl group Chemical group 0.000 claims description 7
- 229910019142 PO4 Inorganic materials 0.000 claims description 5
- 239000010452 phosphate Substances 0.000 claims description 5
- NLYAJNPCOHFWQQ-UHFFFAOYSA-N kaolin Chemical compound O.O.O=[Al]O[Si](=O)O[Si](=O)O[Al]=O NLYAJNPCOHFWQQ-UHFFFAOYSA-N 0.000 claims description 4
- 239000002184 metal Substances 0.000 claims description 4
- 239000012188 paraffin wax Substances 0.000 claims description 4
- 239000004711 α-olefin Substances 0.000 claims description 4
- 229920013639 polyalphaolefin Polymers 0.000 claims description 3
- 150000004696 coordination complex Chemical class 0.000 claims 4
- -1 phosphate ester Chemical class 0.000 claims 4
- 230000002401 inhibitory effect Effects 0.000 claims 1
- 239000000203 mixture Substances 0.000 description 8
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 7
- LYCAIKOWRPUZTN-UHFFFAOYSA-N Ethylene glycol Chemical compound OCCO LYCAIKOWRPUZTN-UHFFFAOYSA-N 0.000 description 6
- 230000015572 biosynthetic process Effects 0.000 description 6
- 238000005755 formation reaction Methods 0.000 description 6
- 239000007787 solid Substances 0.000 description 5
- PEDCQBHIVMGVHV-UHFFFAOYSA-N Glycerine Chemical compound OCC(O)CO PEDCQBHIVMGVHV-UHFFFAOYSA-N 0.000 description 3
- 238000010796 Steam-assisted gravity drainage Methods 0.000 description 3
- 239000003995 emulsifying agent Substances 0.000 description 3
- 238000004519 manufacturing process Methods 0.000 description 3
- LXOFYPKXCSULTL-UHFFFAOYSA-N 2,4,7,9-tetramethyldec-5-yne-4,7-diol Chemical class CC(C)CC(C)(O)C#CC(C)(O)CC(C)C LXOFYPKXCSULTL-UHFFFAOYSA-N 0.000 description 2
- 238000010793 Steam injection (oil industry) Methods 0.000 description 2
- 239000000654 additive Substances 0.000 description 2
- 150000004945 aromatic hydrocarbons Chemical class 0.000 description 2
- 239000012267 brine Substances 0.000 description 2
- 229920001577 copolymer Polymers 0.000 description 2
- 150000002009 diols Chemical class 0.000 description 2
- 238000000605 extraction Methods 0.000 description 2
- 238000002347 injection Methods 0.000 description 2
- 239000007924 injection Substances 0.000 description 2
- 239000007791 liquid phase Substances 0.000 description 2
- 239000012764 mineral filler Substances 0.000 description 2
- 239000003209 petroleum derivative Substances 0.000 description 2
- 238000004064 recycling Methods 0.000 description 2
- 239000011347 resin Substances 0.000 description 2
- 229920005989 resin Polymers 0.000 description 2
- 238000000926 separation method Methods 0.000 description 2
- HPALAKNZSZLMCH-UHFFFAOYSA-M sodium;chloride;hydrate Chemical compound O.[Na+].[Cl-] HPALAKNZSZLMCH-UHFFFAOYSA-M 0.000 description 2
- 239000000758 substrate Substances 0.000 description 2
- 239000002699 waste material Substances 0.000 description 2
- 230000009471 action Effects 0.000 description 1
- 238000013019 agitation Methods 0.000 description 1
- 230000004075 alteration Effects 0.000 description 1
- 230000008901 benefit Effects 0.000 description 1
- 239000003638 chemical reducing agent Substances 0.000 description 1
- 239000004927 clay Substances 0.000 description 1
- 239000002734 clay mineral Substances 0.000 description 1
- 239000000356 contaminant Substances 0.000 description 1
- 238000001816 cooling Methods 0.000 description 1
- 239000006185 dispersion Substances 0.000 description 1
- 238000004090 dissolution Methods 0.000 description 1
- 238000005265 energy consumption Methods 0.000 description 1
- 230000007613 environmental effect Effects 0.000 description 1
- 238000009472 formulation Methods 0.000 description 1
- 230000005484 gravity Effects 0.000 description 1
- 238000011065 in-situ storage Methods 0.000 description 1
- 239000004615 ingredient Substances 0.000 description 1
- 239000007788 liquid Substances 0.000 description 1
- 239000000463 material Substances 0.000 description 1
- 230000001483 mobilizing effect Effects 0.000 description 1
- 230000004048 modification Effects 0.000 description 1
- 238000012986 modification Methods 0.000 description 1
- 231100000252 nontoxic Toxicity 0.000 description 1
- 230000003000 nontoxic effect Effects 0.000 description 1
- 239000003027 oil sand Substances 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 239000012071 phase Substances 0.000 description 1
- NBIIXXVUZAFLBC-UHFFFAOYSA-K phosphate Chemical compound [O-]P([O-])([O-])=O NBIIXXVUZAFLBC-UHFFFAOYSA-K 0.000 description 1
- 229920000223 polyglycerol Polymers 0.000 description 1
- 229920001451 polypropylene glycol Polymers 0.000 description 1
- 230000008569 process Effects 0.000 description 1
- 238000007670 refining Methods 0.000 description 1
- 239000011435 rock Substances 0.000 description 1
- 239000004576 sand Substances 0.000 description 1
- 239000004094 surface-active agent Substances 0.000 description 1
- 238000009736 wetting Methods 0.000 description 1
Classifications
-
- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B7/00—Special methods or apparatus for drilling
-
- 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
- C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
-
- 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
- C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
- C09K8/34—Organic liquids
-
- 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
- C09K8/32—Non-aqueous well-drilling compositions, e.g. oil-based
- C09K8/36—Water-in-oil emulsions
Landscapes
- Chemical & Material Sciences (AREA)
- Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Organic Chemistry (AREA)
- Materials Engineering (AREA)
- Geology (AREA)
- Mining & Mineral Resources (AREA)
- Physics & Mathematics (AREA)
- Environmental & Geological Engineering (AREA)
- Fluid Mechanics (AREA)
- Geochemistry & Mineralogy (AREA)
- Earth Drilling (AREA)
Abstract
A method of forming bore holes in conventional and non-conventional hydrocarbon deposits, comprising the steps of circulating a drilling fluid through the bore hole during the drilling thereof, the drilling fluid being oil based.
Description
OIL BASED DRILLING >=LUID
Field of the Invention The present invention relates to drilling fluids and more particularly to oil based drilling fluids used in the drilling of wells in both conventional and nonconventional oil and/or gas bearing formations.
Large hydrocarbon reserves exist in the form of nonconventional deposits, particularly oil sands of the type found in the Fort McMurray area of northern Alberta.
These deposits are non-conventional in the sense that, unlike conventional hydrocarbon deposits, the hydrocarbon exists in the form of a highly viscous bitumen that adheres to a particulate substrate, typically sand. As such, the bitumen will not flow to the well bore under formation pressure, nor can the bitumen be pumped from the well to the surface. To date, the principle means of extraction has been to mine the oil sands, and to then treat the mined product to separate the bitumen from the substrate. The separation techniques are numerous and increasing.
Amongst operators in the oil sands, a methodology attracting more interest due to improved economics is referred to as steam assisted gravity drainage (SAGD).
This technique involves the drilling of large diameter (200-311 mm) horizontal holes through the oil sand formation to form producer well bores. Additional adjacent wells, which may also have diameters in the 311 mm range; are then drilled for the injection of steam. The steam injection is required in order to allow the in situ bitumen to mobilize and be produced from the producer well. The produced bitumen is then refined to recover its usable hydrocarbon component.
A major problem when drilling into oil sands is the accretion of highly viscous and tacky bitumen onto the metal surfaces of the drilling tools and pipe, be it jointed pipe or coiled tubing. The bitumen accretion can become so severe that pipe and tools _1_ can become stuck in the well bore, preventing their extraction. The accretions result in additional operational challenges well known in the industry including plugging and increased energy consumption required to overcome the resistance of the bitumen against formation walls and other component and tool surfaces.
To date, the most prevalent method of preventing accretion has been to physically cool the drilling mud used when drilling the well bores. The cooled mud preserves the bitumen's inherent viscosity, which prevents it from mobilizing due to the frictional heat generated by drilling, and thereby limiting its accretion onto metal surfaces.
However, cooling of the drilling mud is far from completely effective, and adds considerably to drilling costs. Cooled drilling muds are themselves more viscous, increasing horsepower requirements for their circulation.
Another primary concern with SAGD is waste management. The muds used to drill the production and injection wells are water based which after use incorporate two liquid phases and a solids phase. The first liquid phase is of course the water which can be recycled but which must be significantly processed prior to recycling in order to remove drilled solids and liquid hydrocarbon contaminants. This is time consuming and costly. Moreover, since water is required for steam injection, use of water in drilling muds reduces the supply available for steam generation. This is a not insignificant consideration in the Fort McMurray area where water deposits are limited.
Further, the drilling process often results in the production of cuttings -small pieces of rock that break away from the formation due to the action of the drill bit teeth. One problem that can occur is that oil and drilling mud is adsorbed onto the cuttings. Due to environmental regulations, the oil and drilling mud must be removed before the cuttings can be disposed of.
_2_ It is an object of the present invention to provide a drilling mud or drilling fluid which obviates and mitigates from the disadvantages of the prior art. In this patent, the terms drilling mud and drilling fluid are used interchangeably and have the same meaning.
It is a further object of the present invention to provide an oil based drilling mud for use in the drilling of well bores in nonconventional oil sands deposits.
~rilling with oil will reduce the waste stream to only solids and oil. By eliminating water, extra time normally required for separation of oil and drilled solids from water based fluids is not required when recycling the recoverable and reusable oil component of the drilling mud. if the oil sands are drilled with an oil based mud, the problem of accretion and subsequent differential sticking can be reduced or perhaps even eliminated.
The use of a low aromatic base oil such as a linear alpha olefin, because of the absence or near absence of aromatics, will help prevent dissolution of the bitumen being drilled to limit accretion. If the bitumen is not being dissolved, an anciNary benefit should be greater bore hole integrity, meaning that the drilling mud provides a superior ability to support the drilling of large diameter holes.
It is a further object of the present invention to provide an oil based drilling mud that facilitates the removal of oil on cuttings. The use of a low aromatic base oil and associated additives results in a drilling mud that is easily removed from drill cuttings by mechanical intervention such as centrifuging and agitation in shale shakers. It is conjectured that the low aromatic base oil and associated additives acts to prevent accretion of any oily residues, thus allowing the drilling mud and oil to be removed from the cuttings by mechanical intervention.
It is a further object of the present invention to provide an oil based drilling mud that provides a stable wellbore in both conventional and unconventional oil and gas reservoirs.
The mud system proposed by the present invention consists of a low aromatic hydrocarbon base oil with viscosifying agents. This fluid would have the necessary rheological properties for drilling purposes.
Suitable low or no aromatic base oils can include the following: Amodrill 1500 (linear alpha olefin), orAmodrill 2110 (poly alpha olefin) available from BP, Pure DriIIT"" HT-40N, HT-30N (paraffin base oils),1 A-35 or IA-35 LV (paraffin base oils) available from PetroCanada, Enviro-DriIITM, or DriIIsoIT""
In one embodiment, the base oils can be gelled with a phosphate esterlmetal complex such as ChemoiLT"" Gel or ChemoilT"" Link, for example.
It has been found, however, that this system may not be stable under all conditions.
Accordingly, in a second embodiment a viscosifying agent such as Bentone 150, an organophilic clay viscosifying agent, may alternatively be used.
Additional ingredients may include a primary emulsifiers, for example a mixture of alkylarylalkoxylate (30-60% by weight), acetylenic diol (30-60% by weight) and ethylene glycol (16% by weight). A secondary emulsifier rnay also be included, such as a mixture of ethoxylated 2,4,7,9-tetramethyl 5 decyn-4,7-diol (at least 65%
by weight) and tetramethyl-5-decyne-4,7-diol,2,4,7,9- (at least 25% by weight).
Fluid loss reducers may be added, such as a mixture of a granular refined petroleum distillate resin (75%) and mineral filler 925%), or a substituted styrene acrylate copolymer (pre-crosslinked, 100% active).
A brine consisting of a mixture of glycerol, polyglycerols, polypropylene glycols and other non-toxic materials, such as New100, may also be included.
in order to re-use the drilling mud, any bitumen that may have been incorporated into the drilling mud can also be separated such as by centrifuging, utilizing its higher specific gravity compared to the low aromatic base oil being used for the drilling fluid.
The low aromatic hydrocarbon base oil can then be reused for drilling, the solids disposed of and any bitumen separated out can be directed to the refining facility to be blended with produced bitumen.
The present oil based fluid described above does not require oil wetting surfactants or emulsifiers of the sort normally used in oil based systems. As such, there is no concern with wettability alterations to the reservoir. A hydrocarbon based drilling fluid will also prevent the dispersion of clay minerals which could otherwise leach into the formation to diminish its permeability and impair production.
Example 1 The following formulation constitutes one possible embodiment of the invention:
Amodrill 1500 10-20 kglm3 Bentone 150 10-20 kglm' Mixture of an alkylarylakloxylate (30-60% by weight), an acetylenic diol (30-60% by weight), and ethylene glycol (16% by weight) 2 Um3 Mixture of an ethoxylated 2,4,7,9-tetramethyl 5 decyn-4,7-diol (>65% by weight) and tetramethyl-5-decyne-4,7-diol,2,4,7,9- (>25% by weight) 2 Um3 New100 Brine 50Um~
Mixture of a granular refined petroleum distillate resin (75%) and a mineral filler (25%) 10 kg/m~
Substituted styrene acrylate copolymer (pre-crosslinked, 100% active) 10 kglm3 The above-described embodiments of the present invention are meant to be illustrative of preferred embodiments and are not intended to limit the scope of the present invention. Various modifications, which would be readily apparent to one skilled in the art, are intended to be within the scope of the present invention. The only limitations to the scope of the present invention are set forth in the following claims appended hereto.
Field of the Invention The present invention relates to drilling fluids and more particularly to oil based drilling fluids used in the drilling of wells in both conventional and nonconventional oil and/or gas bearing formations.
Large hydrocarbon reserves exist in the form of nonconventional deposits, particularly oil sands of the type found in the Fort McMurray area of northern Alberta.
These deposits are non-conventional in the sense that, unlike conventional hydrocarbon deposits, the hydrocarbon exists in the form of a highly viscous bitumen that adheres to a particulate substrate, typically sand. As such, the bitumen will not flow to the well bore under formation pressure, nor can the bitumen be pumped from the well to the surface. To date, the principle means of extraction has been to mine the oil sands, and to then treat the mined product to separate the bitumen from the substrate. The separation techniques are numerous and increasing.
Amongst operators in the oil sands, a methodology attracting more interest due to improved economics is referred to as steam assisted gravity drainage (SAGD).
This technique involves the drilling of large diameter (200-311 mm) horizontal holes through the oil sand formation to form producer well bores. Additional adjacent wells, which may also have diameters in the 311 mm range; are then drilled for the injection of steam. The steam injection is required in order to allow the in situ bitumen to mobilize and be produced from the producer well. The produced bitumen is then refined to recover its usable hydrocarbon component.
A major problem when drilling into oil sands is the accretion of highly viscous and tacky bitumen onto the metal surfaces of the drilling tools and pipe, be it jointed pipe or coiled tubing. The bitumen accretion can become so severe that pipe and tools _1_ can become stuck in the well bore, preventing their extraction. The accretions result in additional operational challenges well known in the industry including plugging and increased energy consumption required to overcome the resistance of the bitumen against formation walls and other component and tool surfaces.
To date, the most prevalent method of preventing accretion has been to physically cool the drilling mud used when drilling the well bores. The cooled mud preserves the bitumen's inherent viscosity, which prevents it from mobilizing due to the frictional heat generated by drilling, and thereby limiting its accretion onto metal surfaces.
However, cooling of the drilling mud is far from completely effective, and adds considerably to drilling costs. Cooled drilling muds are themselves more viscous, increasing horsepower requirements for their circulation.
Another primary concern with SAGD is waste management. The muds used to drill the production and injection wells are water based which after use incorporate two liquid phases and a solids phase. The first liquid phase is of course the water which can be recycled but which must be significantly processed prior to recycling in order to remove drilled solids and liquid hydrocarbon contaminants. This is time consuming and costly. Moreover, since water is required for steam injection, use of water in drilling muds reduces the supply available for steam generation. This is a not insignificant consideration in the Fort McMurray area where water deposits are limited.
Further, the drilling process often results in the production of cuttings -small pieces of rock that break away from the formation due to the action of the drill bit teeth. One problem that can occur is that oil and drilling mud is adsorbed onto the cuttings. Due to environmental regulations, the oil and drilling mud must be removed before the cuttings can be disposed of.
_2_ It is an object of the present invention to provide a drilling mud or drilling fluid which obviates and mitigates from the disadvantages of the prior art. In this patent, the terms drilling mud and drilling fluid are used interchangeably and have the same meaning.
It is a further object of the present invention to provide an oil based drilling mud for use in the drilling of well bores in nonconventional oil sands deposits.
~rilling with oil will reduce the waste stream to only solids and oil. By eliminating water, extra time normally required for separation of oil and drilled solids from water based fluids is not required when recycling the recoverable and reusable oil component of the drilling mud. if the oil sands are drilled with an oil based mud, the problem of accretion and subsequent differential sticking can be reduced or perhaps even eliminated.
The use of a low aromatic base oil such as a linear alpha olefin, because of the absence or near absence of aromatics, will help prevent dissolution of the bitumen being drilled to limit accretion. If the bitumen is not being dissolved, an anciNary benefit should be greater bore hole integrity, meaning that the drilling mud provides a superior ability to support the drilling of large diameter holes.
It is a further object of the present invention to provide an oil based drilling mud that facilitates the removal of oil on cuttings. The use of a low aromatic base oil and associated additives results in a drilling mud that is easily removed from drill cuttings by mechanical intervention such as centrifuging and agitation in shale shakers. It is conjectured that the low aromatic base oil and associated additives acts to prevent accretion of any oily residues, thus allowing the drilling mud and oil to be removed from the cuttings by mechanical intervention.
It is a further object of the present invention to provide an oil based drilling mud that provides a stable wellbore in both conventional and unconventional oil and gas reservoirs.
The mud system proposed by the present invention consists of a low aromatic hydrocarbon base oil with viscosifying agents. This fluid would have the necessary rheological properties for drilling purposes.
Suitable low or no aromatic base oils can include the following: Amodrill 1500 (linear alpha olefin), orAmodrill 2110 (poly alpha olefin) available from BP, Pure DriIIT"" HT-40N, HT-30N (paraffin base oils),1 A-35 or IA-35 LV (paraffin base oils) available from PetroCanada, Enviro-DriIITM, or DriIIsoIT""
In one embodiment, the base oils can be gelled with a phosphate esterlmetal complex such as ChemoiLT"" Gel or ChemoilT"" Link, for example.
It has been found, however, that this system may not be stable under all conditions.
Accordingly, in a second embodiment a viscosifying agent such as Bentone 150, an organophilic clay viscosifying agent, may alternatively be used.
Additional ingredients may include a primary emulsifiers, for example a mixture of alkylarylalkoxylate (30-60% by weight), acetylenic diol (30-60% by weight) and ethylene glycol (16% by weight). A secondary emulsifier rnay also be included, such as a mixture of ethoxylated 2,4,7,9-tetramethyl 5 decyn-4,7-diol (at least 65%
by weight) and tetramethyl-5-decyne-4,7-diol,2,4,7,9- (at least 25% by weight).
Fluid loss reducers may be added, such as a mixture of a granular refined petroleum distillate resin (75%) and mineral filler 925%), or a substituted styrene acrylate copolymer (pre-crosslinked, 100% active).
A brine consisting of a mixture of glycerol, polyglycerols, polypropylene glycols and other non-toxic materials, such as New100, may also be included.
in order to re-use the drilling mud, any bitumen that may have been incorporated into the drilling mud can also be separated such as by centrifuging, utilizing its higher specific gravity compared to the low aromatic base oil being used for the drilling fluid.
The low aromatic hydrocarbon base oil can then be reused for drilling, the solids disposed of and any bitumen separated out can be directed to the refining facility to be blended with produced bitumen.
The present oil based fluid described above does not require oil wetting surfactants or emulsifiers of the sort normally used in oil based systems. As such, there is no concern with wettability alterations to the reservoir. A hydrocarbon based drilling fluid will also prevent the dispersion of clay minerals which could otherwise leach into the formation to diminish its permeability and impair production.
Example 1 The following formulation constitutes one possible embodiment of the invention:
Amodrill 1500 10-20 kglm3 Bentone 150 10-20 kglm' Mixture of an alkylarylakloxylate (30-60% by weight), an acetylenic diol (30-60% by weight), and ethylene glycol (16% by weight) 2 Um3 Mixture of an ethoxylated 2,4,7,9-tetramethyl 5 decyn-4,7-diol (>65% by weight) and tetramethyl-5-decyne-4,7-diol,2,4,7,9- (>25% by weight) 2 Um3 New100 Brine 50Um~
Mixture of a granular refined petroleum distillate resin (75%) and a mineral filler (25%) 10 kg/m~
Substituted styrene acrylate copolymer (pre-crosslinked, 100% active) 10 kglm3 The above-described embodiments of the present invention are meant to be illustrative of preferred embodiments and are not intended to limit the scope of the present invention. Various modifications, which would be readily apparent to one skilled in the art, are intended to be within the scope of the present invention. The only limitations to the scope of the present invention are set forth in the following claims appended hereto.
Claims (21)
1. ~A method of forming bore holes in non-conventional hydrocarbon deposits, comprising the steps of:~
circulating a drilling fluid through said bore hole during the drilling thereof, said drilling fluid being oil based.
circulating a drilling fluid through said bore hole during the drilling thereof, said drilling fluid being oil based.
2. ~The method of claim 1 wherein said oil based drilling fluid comprises a base oil with low or no aromatics therein.
3. ~The method of claim 2 wherein said base oil is a linear alpha olefin.
4. ~The method of claim 2 wherein said base oil is a poly alpha olefin.
5. ~The method of claim 2 wherein said base oil is a paraffin based oil.
6. ~The method of any of claims 2 to 5 wherein said fluid includes at least one viscosifying agent.
7. ~The method of claim 6 wherein said at least one viscosifying agent includes Bentone 150.
8. ~The method of claim 6 wherein said viscosifier is a phosphate ester/metal complex.
9. ~The method of claim 6 wherein said phosphate ester/metal complex is Chemoil Gel or Chemoil Link.
10. ~The method of any of claims 1 to 9 wherein said non-conventional hydrocarbon deposits are oil sands.
11. A drilling fluid for use in the drilling of bore holes in conventional or non-conventional hydrocarbon deposits, the drilling fluid comprising a base oil and a viscosifying agent for said base oil.
12. The drilling fluid of claim 11 wherein said base oil has a low or no concentration of aromatics therein.
13. The drilling fluid of claim 12 wherein said base oil is a linear alpha olefin.
14. The drilling fluid of claim 12 wherein said base oil is a poly alpha olefin.
15. The drilling fluid of claim 12 wherein said base oil is a paraffin based oil.
16. The drilling fluid of any of claims 11 to 15 wherein said viscosifying agent is Bentone 150.
17. The drilling fluid of any of claims 11 to 15 wherein said viscosifying agent is a phosphate ester/metal complex.
18. The drilling fluid of claim 17 wherein said phosphate ester/metal complex is Chemoil Gel or Chemoil Link.
19. The drilling fluid of any of claims 11 to 18 wherein said non-conventional hydrocarbon deposits are oil sands.
20. A method of inhibiting the accretion of bitumen on metal surfaces during the drilling of oil sands comprising the steps of:
viscosifying an oil based drilling fluid; and circulating said oil based drilling fluid while drilling through said oil sands, said oil based drilling fluid having a sufficiently low aromatic content that bitumen in said oil sands will not accrete to metal surfaces.
viscosifying an oil based drilling fluid; and circulating said oil based drilling fluid while drilling through said oil sands, said oil based drilling fluid having a sufficiently low aromatic content that bitumen in said oil sands will not accrete to metal surfaces.
21. ~A method of reducing the incidence of oil on cuttings during the drilling of conventional or non-conventional oil or gas reservoirs comprising the steps of:
circulating an oil based drilling fluid while drilling info said reservoirs, said oil based drilling fluid having a sufficiently low aromatic content to reduce the incidence of said oil on said cuttings; and agitating said cuttings by mechanical means to separate said oil and said oil based drilling fluid from said cuttings.
circulating an oil based drilling fluid while drilling info said reservoirs, said oil based drilling fluid having a sufficiently low aromatic content to reduce the incidence of said oil on said cuttings; and agitating said cuttings by mechanical means to separate said oil and said oil based drilling fluid from said cuttings.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA002478622A CA2478622A1 (en) | 2003-11-18 | 2004-08-20 | Oil based drilling fluid |
Applications Claiming Priority (3)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CA2,449,869 | 2003-11-18 | ||
| CA 2449869 CA2449869A1 (en) | 2003-11-18 | 2003-11-18 | Oil based drilling fluid |
| CA002478622A CA2478622A1 (en) | 2003-11-18 | 2004-08-20 | Oil based drilling fluid |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA2478622A1 true CA2478622A1 (en) | 2005-05-18 |
Family
ID=34575141
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA002478622A Abandoned CA2478622A1 (en) | 2003-11-18 | 2004-08-20 | Oil based drilling fluid |
Country Status (1)
| Country | Link |
|---|---|
| CA (1) | CA2478622A1 (en) |
Cited By (4)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7612117B2 (en) * | 2005-11-17 | 2009-11-03 | General Electric Company | Emulsion breaking process |
| US7771588B2 (en) * | 2005-11-17 | 2010-08-10 | General Electric Company | Separatory and emulsion breaking processes |
| US20120132423A1 (en) * | 2007-10-16 | 2012-05-31 | Halliburton Energy Services, Inc. | Compositions and Methods for Treatment of Well Bore Tar |
| US9051508B2 (en) | 2007-10-16 | 2015-06-09 | Halliburton Energy Services, Inc. | Methods of preventing emulsification of crude oil in well bore treatment fluids |
-
2004
- 2004-08-20 CA CA002478622A patent/CA2478622A1/en not_active Abandoned
Cited By (7)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7612117B2 (en) * | 2005-11-17 | 2009-11-03 | General Electric Company | Emulsion breaking process |
| US7771588B2 (en) * | 2005-11-17 | 2010-08-10 | General Electric Company | Separatory and emulsion breaking processes |
| US20120132423A1 (en) * | 2007-10-16 | 2012-05-31 | Halliburton Energy Services, Inc. | Compositions and Methods for Treatment of Well Bore Tar |
| US8603951B2 (en) | 2007-10-16 | 2013-12-10 | Halliburton Energy Services, Inc. | Compositions and methods for treatment of well bore tar |
| US8741816B2 (en) * | 2007-10-16 | 2014-06-03 | Halliburton Energy Services, Inc. | Compositions and methods for treatment of well bore tar |
| US8877689B2 (en) | 2007-10-16 | 2014-11-04 | Haliburton Energy Services, Inc. | Compositions and methods for treatment of well bore tar |
| US9051508B2 (en) | 2007-10-16 | 2015-06-09 | Halliburton Energy Services, Inc. | Methods of preventing emulsification of crude oil in well bore treatment fluids |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| EEER | Examination request | ||
| FZDE | Discontinued |