WO1997004038A1 - Non-toxic, inexpensive synthetic drilling fluid - Google Patents
Non-toxic, inexpensive synthetic drilling fluid Download PDFInfo
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- WO1997004038A1 WO1997004038A1 PCT/US1996/011520 US9611520W WO9704038A1 WO 1997004038 A1 WO1997004038 A1 WO 1997004038A1 US 9611520 W US9611520 W US 9611520W WO 9704038 A1 WO9704038 A1 WO 9704038A1
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- 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
- C09K8/64—Oil-based compositions
-
- 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
- C09K8/60—Compositions for stimulating production by acting on the underground formation
-
- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10—TECHNICAL SUBJECTS COVERED BY FORMER USPC
- Y10S—TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y10S507/00—Earth boring, well treating, and oil field chemistry
- Y10S507/905—Nontoxic composition
Definitions
- the present invention relates to wellbore fluids (especially, synthetic fluid-based drilling fluids) and systems and processes for using them in a subterranean formation in oil and gas recovery
- drilling fluids employing synthetic fluids such as polyalphaolefin- and ester-based drilling fluids
- synthetic fluids such as polyalphaolefin- and ester-based drilling fluids
- a drilling fluid which employs an inexpensive, non-toxic synthetic fluid as the base fluid.
- the present invention satisfies this need by providing a drilling fluid comprising (a) at least one drilling fluid additive (e.g., an emulsifier, a viscosifier, a weighting agent, and an oil-wetting agent) and (b) an inexpensive, non-toxic base fluid.
- the base fluid is a drilling fluid additive
- synthetic fluid having a pour point greater than about -30°C (-22oF) and comprising (i) at least about 95 weight percent hydrocarbons containing 11 or more carbon atoms, (ii) greater than 5 weight percent hydrocarbons
- isoparaffin synthetic fluid containing 18 or more carbon atoms, (iii) at least about 50 weight percent isoparaffins, (iv) at least about 90 weight percent total paraffins, (v) at least 2 hydrocarbons containing a consecutive number of carbon atoms, (vi) less than about 1 weight percent naphthenics, and (vii) less than about 0.1 volume percent aromatics.
- This synthetic fluid is referred to hereinafter as the "isoparaffin synthetic fluid."
- the synthetic fluid comprises (1) at least about 95 weight percent
- n-paraffin synthetic fluid hydrocarbons containing 10 or more carbon atoms and (2) at least about 90 weight percent n-paraffins.
- the n-paraffins usually also contain (i) less than about 10 weight percent naphthenics and (ii) less than about 0.1 volume percent aromatics.
- both the isoparaffin and n-paraffin synthetic fluids contain (i) less than about 1 weight percent sulfur, (ii) less than about 1 weight percent nitrogen, and (iii) less than about 1 weight percent oxygenated compounds.
- the cost of the synthetic fluids employed in the present invention is comparable to that of diesel because the synthetic fluids are made by reacting
- concentrations of these materials in the synthetic fluids used in the present invention is very desirable.
- the fluids employed in the present invention which are in fact made synthetically are also desirable in view of anticipated environmental regulations which may restrict the off-shore discharge of non-aqueous-base drilling fluids to those drilling fluids using a
- a drilling system and a method for drilling a borehole are also provided by the invention.
- drilling system comprises (a) at least one subterranean formation, (b) a borehole penetrating a portion of at least one of the subterranean formations, (c) a drill bit suspended in the borehole, and (d) the above drilling fluid located in the borehole and proximate the drill bit.
- the drilling method comprises the steps of (a) rotating a drill bit at the bottom of the borehole and (b) introducing the aforesaid drilling fluid into the borehole (i) to pick up drill cuttings and (ii) to carry at least a portion of the drill cuttings out of the borehole.
- At least 95 weight percent of the isoparaffin synthetic drilling fluid is commonly composed of
- the isoparaffin synthetic fluid consists of greater than 5, typically greater than 10, more typically greater than 15, even more typically greater than 20, and most typically greater than 25, weight percent compounds containing more than 17 carbon atoms. In fact, compounds containing 18 or more carbon atoms can constitute about 30, 35, 40, 45, or even 50 or more weight percent of the isoparaffin synthetic fluid.
- the isoparaffin synthetic fluid can contain isoparaffin, naphthenic, aromatic, sulfur, nitrogen, oxygenate, and total paraffin compounds in concentrations independently set forth in the following Table I.
- the pour point of the isoparaffin synthetic fluid (as determined by ASTM D 97) is commonly greater than about -30°C (-22°F), more commonly greater than about -25°C (-13°F), even more commonly greater than about -20°C (-4°F), and most commonly greater than about -15oC (5oF).
- the pour point of the isoparaffin synthetic fluid is less than about 6°C (43°F), preferably less than about 3°C (37°F), more preferably less than about 0°C (32°F), and most preferably less than about -3°C (27°F).
- the flash point of the isoparaffin synthetic fluid (as determined by the Cleveland Open Cup method) is at least about 65.6°C (150°F), typically at least about 71.1oC (160oF), more typically about 76.7°C (170oF), even more typically at least about 82.2°C (180°F), and most typically at least about 85°C (185°F).
- the flash point of the isoparaffin synthetic fluid is less than about 121.1°C (250°F), more typically about
- the flash point of the isoparaffin synthetic fluid is at least about 65.6°C (150°F), typically at least about 71.1oC (160oF), more typically about 76.7oC (170°F), even more typically at least about 82.2°C (180°F), and most typically at least about 85°C (185oF), but usually less than about 115°C (239oF), more typically about 110°C (230oF) or less, even more typically about 105oC (221°F) or less, and most about 100°C (212oF) or less.
- the isoparaffin synthetic fluid frequently has an initial boiling point (as determined by ASTM D 86) of at least about 160oC (320°F), more frequently at least about 165°C (329°F), even more frequently at least about 170oC (338°F), and most frequently at least about 175oC (347°F) or even at least about 180°C (356°F).
- an initial boiling point as determined by ASTM D 86 of at least about 160oC (320°F), more frequently at least about 165°C (329°F), even more frequently at least about 170oC (338°F), and most frequently at least about 175oC (347°F) or even at least about 180°C (356°F).
- the isoparaffin synthetic fluid commonly has a final boiling point (as determined by ASTM D 86) of at least about 340°C (644°F), more commonly at least about 345oC (653°F), even more commonly at least about 350°C (662°F), and most commonly at least about 351oC
- the final boiling point of the isoparaffin synthetic fluid is typically about 375oC (707oF) or less, more typically about 370°C (698oF) or less, even more typically about 365°C (689°F) or less, and most typically about 360°C (680°F) or less.
- the viscosity of the isoparaffin synthetic fluid at 40°C (104°F) is ordinarily between about 1 to about 10 centistokes (cst).
- the viscosity of the isoparaffin synthetic fluid at 40°C (104°F) is less than about 6, more
- the isoparaffin synthetic fluids commonly have an API gravity greater than about 40°, more commonly greater than about 42°, even more commonly greater than about 44°, and most commonly greater than about 46°.
- the cetane index (as determined by ASTM D 976) is generally greater than about 60, preferably greater than about 62, more preferably greater than about 64, even more preferably greater than about 66, and most preferably greater than about 68. In fact, the cetane index is frequently at least about 70, 71, 73, 74, 75, 76, about 77 or more.
- An isoparaffin synthetic fluid commercially available from MDS(Malaysia) typically has the properties set forth in the following Table II.
- the mono- and poly-methyl isomers of isoparaffins containing 11 or less carbon atoms can constitute 97, 98, or even 99, weight percent of the isoparaffin hydrocarbons having up to 11 carbon atoms.
- isoparaffin synthetic fluid reported in Table II, isoparaffins whose branched
- moieties contain more than one carbon atom (e.g., have an ethyl, propyl, butyl, or larger substituent group) constitute a negligible portion of the total amount of isoparaffins containing 11 or less carbon atoms.
- Another isoparaffin synthetic fluid which is commercially available from Sasol, has the properties shown in the following Table IV.
- the base oil When the isoparaffin synthetic fluids are employed as the base fluid in a drilling mud, the base oil generally contains less than 1, preferably less than about 0.9, more preferably less than 0.8, even more preferably less than about 0.7, and most preferably less than about 0.6, weight percent polar activator (e.g., polar ether alcohols).
- the concentration of polar activators in the base fluid is commonly less than about 0.5, more commonly less than about 0.4, even more commonly less than about 0.3, and most commonly less than about 0.2, weight percent.
- the base fluid can contain less than about 0.1, 0.05, 0.01, 0.005, 0.001, weight percent polar activator or even be totally devoid of any polar activator.
- the entire drilling mud usually contains less than 1, preferably less than about 0.75, more preferably less than 0.5, even more preferably less than about 0.25, and most preferably less than about 0.1, weight percent polar activator.
- the drilling mud can contain less than about 0.05, 0.01, 0.005, 0.001, weight percent polar activator or be entirely devoid of any polar activator.
- the n-paraffin synthetic fluid at least 95 weight percent of the n-paraffin synthetic drilling fluid is generally composed of compounds
- n-paraffin synthetic drilling fluid containing 10 or more carbon atoms.
- at least 95 weight percent of the n-paraffin synthetic drilling fluid is composed of compounds containing 11 or more, more typically 12 or more, even more typically 13 or more, and most typically 14 or more carbon atoms.
- the n-paraffin synthetic fluid contains less than about 5, more commonly less than 3, even more commonly less than about 2, and most commonly less than about 1, weight percent of compounds containing 18 or more carbon atoms.
- the n-paraffin synthetic fluid can contain n-paraffin, iso-paraffin, naphthenic, aromatic, sulfur, nitrogen, and oxygenate compounds in concentrations independently listed in the following Table V.
- the pour point of the n-paraffin synthetic fluid (as determined by ASTM D 97) is commonly greater than about -30°C (-22°F) and more commonly greater than about -25°C (-13 °F). Frequently, the pour point of the n-paraffin synthetic fluid is less than about 10°C
- the flash point of the n-paraffin synthetic fluid is typically at least about 65oC (149oF), more typically at least about 70°C (158oF), even more typically at least about 75oC (167oF), and most typically at least about 80oC (176°F).
- the n-paraffin synthetic fluids can have even higher flash points, such as at least about 85°C (185oF), 90°C
- the n-paraffin synthetic fluid frequently has an initial boiling point (as determined by ASTM D 86) of at least about 190°C (374°F), more frequently at least about 200°C (392°F), even more frequently at least about 210oc (410°F), and most frequently at least about 220oC (428°F). Even higher initial boiling points, such as about 230°C (446°F), 240° (464oF), or 250oC (482oF) or more, are not unusual for the n-paraffin synthetic fluids.
- the viscosity of the n-paraffin synthetic fluid at 40°C (104°F) is ordinarily between about 1 to about 10 cst.
- the viscosity of the n-paraffin synthetic fluid at 40°C (104°F) is ordinarily between about 1 to about 10 cst.
- the viscosity of the n-paraffin synthetic fluid at 40°C (104°F) is ordinarily between about 1 to about 10 cst.
- (104°F) is less than about 5, more preferably less than about 4, even more preferably less than about 3, and most preferably less than about 2, cst.
- the n-paraffin synthetic fluids commonly have an API gravity greater than about 45°, more commonly greater than about 50°, even more commonly greater than about 50.5°, and most commonly greater than about 51°.
- the synthetic fluids of the present invention are prepared by the Fischer-Tropsch process and various modifications thereof (especially the Shell Middle
- Fischer-Tropsch product are hydrogenated, (b) small amounts of oxygen-containing compounds, mainly primary alcohols, are removed, (c) the Fischer-Tropsch product is hydroisomerized, and (d) the n-paraffins are hydrocracked to isoparaffins of a desired chain length and/or boiling range. Due to the manner in which they are
- the synthetic fluids are composed of
- hydrocarbons containing a consecutive number of carbon atoms i.e., a mixture of hydrocarbons where the carbon atom content of the individual hydrocarbons is C n , C n+1 , C n+2 , C n+3 ' etc. and n is a whole number.
- the synthetic fluids are composed of at least 2, more commonly at least 3, even more commonly at least 4, and most commonly at least 5 hydrocarbons containing a consecutive number of carbon atoms.
- some synthetic fluids contain at least 6, 7, 8, 9, or 10 or more hydrocarbons having a consecutive number of carbon atoms.
- the synthetic fluids are commercially available from Sasol in South Africa and Shell Middle Distillate in Malaysia and are preferably the fraction which has a boiling range similar to gasoils and/or kerosenes
- pour point depressants are employed in the synthetic fluids of the present invention to lower their pour point.
- Typical pour point depressants include, but are not limited to, ethylene copolymers, isobutylene polymers, polyaklylnaphthalenes, wax-aromatic condensation products (e.g., wax-naphthalene condensation products, phenol-wax condensation products), polyalkylphenolesters, polyalkylmethacrylates,
- polymethacrylates polyalkylated condensed aromatics, alkylaromatic polymers, iminodiimides, and
- polyalkylmethacrylates range from about 2,000 to about 10,000. Because they are non-toxic, ethylene copolymers and isobutylene polymers are the preferred pour point depressants.
- depressant is based upon the weight of the synthetic fluid, i.e., it is the weight of the pour point
- the pour point depressant is employed in a concentration of 0.005 to about 0.5, more preferably about 0.01 to about 0.4, and most preferably about 0.02 to about 0.3, weight percent.
- the pour point depressant is preferably mixed with the synthetic fluid and the
- surfactant means a substance that, when present at low concentration in a system, has the property of adsorbing onto the surfaces or interfaces of the system and of altering to a marked degree the surface or
- interfaces As used in the foregoing definition of surfactant, the term “interface” indicates a boundary between any two immiscible phases and the term “surface” denotes an interface where one phase is a gas, usually air.) Because the drilling fluids of the present
- Exemplary emulsifiers include, but are not limited to, fatty acids, soaps of fatty acids, and fatty acid derivatives including amido-amines, polyamides, polyamines, esters (such as sorbitan monoleate
- Typical wetting agents include, but are not limited to, lecithin, fatty acids, crude tall oil, oxidized crude tall oil, organic phosphate esters, modified imidazolines, modified amidoamines, alkyl aromatic sulfates, alkyl aromatic sulfonates, and organic esters of polyhydric alcohols.
- Exemplary weighting agents include, but are not limited to barite, iron oxide, gelana, siderite, and calcium carbonate.
- Common shale inhibiting salts are alkali metal and alkaline-earth metal salts. Calcium chloride and sodium chloride are the preferred shale inhibiting salts.
- Exemplary viscosifiers include, but are not limited to, organophilic clays (e.g., hectorite,
- non-organophilic clay means a clay which has not been amine-treated to convert the clay from water-yielding to oil-yielding.
- Illustrative fluid loss control agents include, but are not limited to, asphaltics (e.g., asphaltenes and sulfonated asphaltenes), amine treated lignite, and gilsonite.
- the fluid loss control agent is preferably a polymeric fluid loss control agent.
- exemplary polymeric fluid loss control agents include, but are not limited to, polystyrene, polybutadiene, polyethylene, polypropylene, polybutylene, polyisoprene, natural rubber, butyl rubber, polymers consisting of at least two monomers selected from the group consisting of styrene, butadiene, isoprene, and vinyl carboxylic acid. Individual or mixtures of
- polymeric fluid loss control agents can be used in the drilling fluid of this invention.
- the properties (e.g., synthetic fluid to water ratio, density, etc.) of the drilling fluids of the invention can be adjusted to suit any drilling operation.
- the drilling fluid is usually formulated to have a volumetric ratio of synthetic fluid to water of about 100:0 to about 40:60 and a density of about 0.9 kg/l (7.5 pounds per gallon (ppg)) to about 2.4 kg/l (20 ppg). More commonly, the density of the drilling fluid is about 1.1 kg/l (9 ppg) to about 2.3 kg/l (19 ppg).
- the drilling fluids are preferably prepared by mixing the constituent ingredients in the following order: (a) synthetic fluid, (b) emulsifier, (c) lime, (d) fluid loss control agent, (e) an aqueous solution
- isoparaffin synthetic fluid sample as the base fluid (Example 9), and compare the toxicity of two drilling fluids which solely differ in that the base fluid of one is the isoparaffin synthetic fluid sample and the base fluid of the other is the dimer of 1-decene (a).
- drilling fluids (6 lab barrels per drilling fluid formulation, with each lab barrel containing about 350 ml) having a density of about 2.16 kg/l (about 18 ppg) and within the scope of the present invention are formulated by sequentially adding ingredients in the order set forth in Table A. After the addition of each ingredient, the resulting composition is mixed for the indicated mixing time prior to adding a subsequent ingredient to the composition.
- An invert emulsion drilling fluid is prepared by (a) initially agitating about 240 ml of a synthetic fluid for about 1 minute using a blender and (b) then sequentially adding the following ingredients (with continuous mixing for about one minute after the addition of each material) : (i) about 6 g of a primary emulsifier; (ii) about 8 g of lime (calcium hydroxide); and (iii) about 4 g of a fluid-loss preventing agent.
- each of the materials is added in sequence, with about 5 minutes of mixing after the addition of each of the materials: (i) about 2 g of a secondary emulsifier; (ii) about 210 g of powdered barite (a non-toxic weighting agent); (iii) about 24 g of calcium chloride dihydrate (to provide salinity to the water phase without water wetting the barite); and (iv) about 20 g of a powdered clay (composed of about 35 weight percent smectite and about 65 weight percent kaolinite) to simulate drilled formation particles.
- the foregoing equations are generally accurate within ⁇ 1 unit and even within ⁇ 0.5 unit.
- Isoparaffin Synthetic Fluid-Containing Drilling Fluid Each of two substantially identical samples of an oil-base drilling fluid within the scope of the present invention was formulated as follows. (The isoparaffin synthetic fluid sample analyzed in Example 8 was employed as the synthetic fluid.) Ingredients were sequentially added in the order set forth below in Table E. After the addition of each ingredient, the resulting composition was mixed for the indicated mixing time prior to adding a subsequent ingredient to the composition.
- API Recommended Practice 13B-2 (RP 13B-2), Second Edition, December 1, 1991, American Petroleum Institute, Washington, DC (hereinafter referred to as "API"), API being incorporated herein in its entirety by reference.
- the measured results are set forth in Table F.
- Example 8 Another drilling fluid was prepared in accordance with the protocol set forth in preceding Example 8 using the isoparaffin synthetic fluid analyzed in Example 8 as the synthetic fluid.
- the sole modification consisted of using about ten times the amount of each ingredient in formulating the drilling fluid.
- the drilling fluid was subjected to the 96 hour LC 50 Mysid shrimp (Mysidopsis bahia) bioassay test by an independent laboratory and achieved a score of about 396 ⁇ 10 3 .
- Example 8 Another drilling fluid was prepared in accordance with the protocol set forth above in Example 8 .
- One modification entailed using the dimer of 1-decene (the base synthetic fluid of Novadril brand non-toxic drilling fluid) as the synthetic fluid, and the other modification consisted of using about ten times the amount of each ingredient in formulating the drilling fluid.
- the drilling fluid was subjected to the 96 hour LC 50 Mysid shrimp (Mysidopsis bahia) bioassay test by the same independent laboratory employed in
- Example 10 and achieved a score of about 207.6 ⁇ 10 3 .
- synthetic fluid within the scope of the present invention is substantially less toxic than the commercially used Novadril brand synthetic fluid.
- the reason for this is that the number obtain by the exemplary synthetic fluid-containing drilling fluid is roughly about 1.9 times greater than that obtained by the Novadril-containing drilling fluid.
- the results documented in comparative Examples 10-11 are quite surprising and unexpected because conventional wisdom in the drilling fluids industry considers toxicity to increase with decreasing carbon content and the tested synthetic fluid within the scope of the present invention has a
- the synthetic fluid can also be employed as the base liquid component in other wellbore fluids.
- wellbore fluid means a fluid used while conducting pay zone drilling
- the wellbore fluids contain one or more additional ingredients such as proppants suitable for use in hydraulically fracturing subterranean formations, particulate agents suitable for use in forming a gravel pack, viscosifiers, organophilic clays, and fluid loss control agents.
- proppants suitable for use in hydraulic fracturing procedures are quartz sand grains, tempered glass beads, sintered bauxite, resin coated sand,
- the proppants are employed in the wellbore fluids intended for use as hydraulic fracturing fluids and are used in concentrations of roughly about 1 to about 10 pounds per gallon of the wellbore fluid.
- the proppant size is typically smaller than about 2 mesh on the U.S. Sieve Series scale, with the exact size selected being dependent on the particular type of formation to be fractured, the available pressure and pumping rates, as well as other factors known to those skilled in the art.
- Typical particulate agents employed in the wellbore fluids used as gravel packing fluids include, but are not limited to, quartz sand grains, glass beads, synthetic resins, resin coated sand, walnut shells, and nylon pellets.
- the gravel pack particulate agents are generally used in concentrations of about 1 to about 20 pounds per gallon of the wellbore fluid. The size of the particulate agent employed depends on the type of
- particulate agents of about 8 to about 70 mesh on the U.S. Sieve Series scale are used.
- Illustrative viscosifiers, organophilic clays, and fluid loss control agents optionally used in wellbore fluids and their concentrations are the same as discussed above in connection with drilling fluids.
- the wellbore fluids are prepared by combining the synthetic fluid with any additional additive (e.g., hydraulic fracturing proppants, gravel pack particulate agents, viscosifiers, fluid loss control agents, and organophilic clays).
- the synthetic fluid typically comprises at least about 50 weight percent of the
- wellbore fluid the weight percent being based on the weight of all ingredients present in the wellbore fluid. Accordingly, wellbore fluids containing at least about
- the synthetic fluid constitutes the entire wellbore fluid.
- the synthetic fluid generally comprises from about 50 to 100 weight percent of the liquids employed in wellbore fluids.
- the synthetic fluid can comprise at least about 60, 70, 80, or 90 weight percent of the liquid portion of the wellbore fluid.
- the wellbore fluid of the present invention When employed as a fracturing fluid, the wellbore fluid of the present invention is usually injected into the formation using procedures analogous to those disclosed in U.S. Patent 4,488,975; U.S. Patent 4,553,601; Howard et al.. Hydraulic Fracturing. Society of Petroleum Engineers of the American Institute of
- the wellbore fluid of the present invention When employed in a perforating operation, the wellbore fluid of the present invention is used according to the methodologies disclosed in volume 1, chapter 7 of Allen, referenced above. Techniques for using packer fluids and well killing fluids, such as those discussed in volume 1, chapter 8 of Allen, are also applicable to the wellbore fluid of the present invention.
- the synthetic fluids of the present invention are lubricous, they can constitute up to about 10, and preferably from about 2 to about 5, weight percent of a water-based drilling fluid. In fact, any moving parts can be lubricated with these synthetic fluids.
Abstract
Description
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Priority Applications (6)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
AU64589/96A AU705081B2 (en) | 1995-07-24 | 1996-07-10 | Non-toxic, inexpensive synthetic drilling fluid |
BR9609546A BR9609546A (en) | 1995-07-24 | 1996-07-10 | Fluid and drilling system processes for drilling a well in an underground formation and for treating a well natural resource system and process to reduce friction between two surfaces in relative motion and apparatus |
CA002227562A CA2227562C (en) | 1995-07-24 | 1996-07-10 | Non-toxic, inexpensive synthetic drilling fluid |
EP96923741A EP0840769B2 (en) | 1995-07-24 | 1996-07-10 | Non-toxic, inexpensive synthetic drilling fluid |
UZ9800050A UZ3487C (en) | 1996-07-10 | 1996-07-10 | Non-toxic, inexpensive synthetic drilling fluid |
EA199800134A EA001186B1 (en) | 1995-07-24 | 1996-07-10 | Non-toxic inexpensive drilling fluid |
Applications Claiming Priority (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
US49444195A | 1995-07-24 | 1995-07-24 | |
US494,441 | 1995-07-24 | ||
US580,112 | 1996-01-29 | ||
US08/580,112 US5958845A (en) | 1995-04-17 | 1996-01-29 | Non-toxic, inexpensive synthetic drilling fluid |
Publications (1)
Publication Number | Publication Date |
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WO1997004038A1 true WO1997004038A1 (en) | 1997-02-06 |
Family
ID=27051420
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
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PCT/US1996/011520 WO1997004038A1 (en) | 1995-07-24 | 1996-07-10 | Non-toxic, inexpensive synthetic drilling fluid |
Country Status (13)
Country | Link |
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US (6) | US5958845A (en) |
EP (1) | EP0840769B2 (en) |
CN (1) | CN1150294C (en) |
AR (1) | AR002907A1 (en) |
AU (1) | AU705081B2 (en) |
BR (1) | BR9609546A (en) |
CA (1) | CA2227562C (en) |
CO (1) | CO4560486A1 (en) |
DK (1) | DK0840769T3 (en) |
EA (1) | EA001186B1 (en) |
MX (1) | MX9800643A (en) |
MY (1) | MY137346A (en) |
WO (1) | WO1997004038A1 (en) |
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JP2001515947A (en) * | 1997-09-12 | 2001-09-25 | エクソンモービル リサーチ アンド エンジニアリング カンパニー | Fisher-Tropsch liquid water emulsion |
JP2001515950A (en) * | 1997-09-12 | 2001-09-25 | エクソンモービル リサーチ アンド エンジニアリング カンパニー | Emulsion blend |
JP2001515949A (en) * | 1997-09-12 | 2001-09-25 | エクソンモービル リサーチ アンド エンジニアリング カンパニー | Fischer-Tropsch water emulsion of hydrocarbons |
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US9850417B2 (en) | 2009-07-09 | 2017-12-26 | Tucc Technology, Llc | Ultra high viscosity pill and methods for use with an oil-based drilling system |
WO2021003145A1 (en) * | 2019-07-01 | 2021-01-07 | Highland Fluid Technology, Inc. | Managed pressure drilling with novel noncompressible light weight fluid |
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Also Published As
Publication number | Publication date |
---|---|
CA2227562A1 (en) | 1997-02-06 |
DK0840769T3 (en) | 2005-02-14 |
EP0840769B2 (en) | 2009-08-26 |
EP0840769A1 (en) | 1998-05-13 |
MX9800643A (en) | 1998-10-31 |
AR002907A1 (en) | 1998-04-29 |
CO4560486A1 (en) | 1998-02-10 |
US5958845A (en) | 1999-09-28 |
MY137346A (en) | 2009-01-30 |
US6034037A (en) | 2000-03-07 |
US6107255A (en) | 2000-08-22 |
CN1150294C (en) | 2004-05-19 |
US6110874A (en) | 2000-08-29 |
AU705081B2 (en) | 1999-05-13 |
BR9609546A (en) | 1999-03-02 |
AU6458996A (en) | 1997-02-18 |
US6159907A (en) | 2000-12-12 |
EA001186B1 (en) | 2000-12-25 |
EP0840769B1 (en) | 2004-10-20 |
US6255256B1 (en) | 2001-07-03 |
CA2227562C (en) | 2005-09-13 |
EA199800134A1 (en) | 1998-10-29 |
CN1191558A (en) | 1998-08-26 |
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