WO2001088059A1 - Drilling fluids and method of drilling - Google Patents
Drilling fluids and method of drilling Download PDFInfo
- Publication number
- WO2001088059A1 WO2001088059A1 PCT/GB2001/002057 GB0102057W WO0188059A1 WO 2001088059 A1 WO2001088059 A1 WO 2001088059A1 GB 0102057 W GB0102057 W GB 0102057W WO 0188059 A1 WO0188059 A1 WO 0188059A1
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- WO
- WIPO (PCT)
- Prior art keywords
- fluid
- drilling
- oil
- well
- formula
- Prior art date
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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
- C09K8/02—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
Definitions
- This invention relates to drilling, completion and workover operations on wells, particularly oil and gas wells, which use fluids based on hydrocarbyl, especially alkyl or alkenyl, esters of certain aromatic carboxylic acids, and to invert fluids, particularly drilling muds, completion fluids and workover fluids including such esters.
- Oil based fluids are known for use for drilling bores in rock, and are now often used in offshore drilling or in the penetration of water sensitive layers. Generally, they are used in the form of so-called invert emulsion muds which are based on an emulsion of an aqueous phase in a continuous oil phase. Commonly such emulsion drilling fluids also include solid(s) as weighting material.
- emulsion drilling fluids also include solid(s) as weighting material.
- further additives including emulsifier systems, fluid loss additives, alkali reserves, viscosity regulators and similar materials for stabilising the fluid and to give it desired performance properties, may also be included.
- the first generation of oil based drilling fluids were based on hydrocarbon, often diesel, oil fractions often containing relatively high concentrations of aromatic constituents. Subsequently, to reduce toxicological and ecological problems from the aromatic hydrocarbons, 'aromatic free' hydrocarbon fractions were suggested. However, these did not reduce the problems as far as is desirable, particularly in marine, especially offshore, oil and gas drilling. Subsequently, naturally occurring triglyceride ester oils e.g. vegetable oils, and more recently or semisynthetic aliphatic esters have been proposed.
- This invention is directed to the use of certain aromatic carboxylic acid esters, particularly hydrocarbyl, desirably alkyl or alkenyl, esters, having valuable properties, in drilling, completion and/or workover operations, particularly in oil and/or gas wells, or as components in drilling, completion and/or workover fluids.
- these esters have a range of viscosities, especially extending to low viscosities, and toxicological and environmental profiles that can make them potentially very attractive as components of oil phase fluids for use in the drilling, completion and/or workover of wells, particularly oil and/or gas wells.
- the present invention accordingly provides a method of drilling, completing or workover of a well, particularly a hydrocarbon, especially an oil or gas, well, in which a fluid is introduced into a well during the drilling, completing or workover operation on the well, in which the fluid includes a continuous phase, particularly as the continuous phase of a water in oil emulsion, including at least one compound of the formula (I):
- R 1 is a C-
- AO is an alkyleneoxy group, particularly an ethyleneoxy or a propyleneoxy group, and may vary along the (poly)alkyleneoxy chain
- m is 0, 1 or 2, desirably 0
- Ph is a phenyl group, which may be substituted with groups (R 2 ) p ; where each R 2 is independently a C- ) to C4 alkyl or alkoxy group; and p is 0, 1 or 2, desirably 0.
- the method of this invention is, in principle, applicable to drilling, completion and workover of wells in general, but will most usually be used when wells are drilled for access to fluid resources, in particular, water, but more usually hydrocarbons such as gas and, especially, oil.
- the invention accordingly specifically includes a method of the invention for the drilling, completion and workover of oil and/or gas wells.
- the invention further includes a drilling, completion and/or workover fluid which is an emulsion of an aqueous phase, optionally including dissolved salts, in a continuous phase of an ester containing liquid including at least one compound of the formula (I) as defined above, optionally including a dispersion of weighting solids.
- a drilling, completion and/or workover fluid which is an emulsion of an aqueous phase, optionally including dissolved salts, in a continuous phase of an ester containing liquid including at least one compound of the formula (I) as defined above, optionally including a dispersion of weighting solids.
- the invention also includes a method of drilling completion and/or workover of the invention using such a drilling fluid.
- R ⁇ is desirably an alicyclic group, and particularly can be an alkyl or alkenyl group.
- Alkyl groups have the advantage that they are more stable, particularly to oxidation, than alkenyl groups, but alkenyl esters generally remain fluid at lower temperatures than alkyl esters, especially for longer chain materials.
- an alkenyl group includes only a single double bond as multiple unsaturation generally gives poor stability.
- R 1 can be a relatively short chain e.g. a C3 to CQ, alkyl group, and is desirably branched e.g.
- esters with secondary alcohols are particularly useful and R 1 is thus especially a C3 to C5 secondary alkyl group and very desirably an /so-propyl group.
- a benefit of such short chain esters is that they have low viscosity. However, the short chain esters have high solvent capacity and may interact with elastomeric well seals causing swelling which is undesirable.
- R1 can be a CQ to C20. particularly a C3 to C-13 alkyl or alkenyl group which may be straight chain or branched e.g. as in 2-ethylhexyi or /so-nonyl or branched chain C-13 alkyl as in so-called iso- " stearyl (actually a mixture of mainly branched C- j 4 to C22 alkyl with an average chain length close to C13).
- a particular unsaturated longer chain group is oleyl.
- the carboxylic acid used in the ester can be a dihydrocinnamic acid or a phenylacetic acid, it is very desirably a benzoic acid i.e. desirably m is 0. Similarly, although the phenyl ring of the acid may be substituted, it is desirable that it is unsubstituted i.e. desirably p is 0.
- the esters used in the invention may include a (poly)alkyleneoxy chain, (AO) n in formula (I), between the carboxyl group and the group R 1 .
- the (poly)alk leneoxy chain is desirably a (poly)ethyleneoxy, a (poly)propyleneoxy chain or a chain including both ethyleneoxy and propyleneoxy residues.
- n is 0.
- esters useful in this invention is /so-propyl benzoate which has a combination of properties that contribute to its usefulness: it has a wide liquid range (BP ca 219°C and pour point ⁇ -60°C); it is classified as non-flammable (flash point ca 99°C) and under normal use conditions it has a low vapour pressure; it has a density similar to that of water (1.008 kg.l"1 at 25°C); and a low viscosity (2.32 cSt at 25°C; measured by the U tube method, equivalent to 2.34 mPa.s).
- mixed esters having a variety of groups R ⁇ , or blends of compounds of the formula (I), may be advantageous.
- Such mixed esters of blends can have the additional benefit that they are more liquid than pure, especially linear saturated compounds of similar overall R ⁇ carbon number.
- the extent of adverse effects such as elastomer seal swelling for using the esters with good solvent properties can be substantially reduced, while retaining the benefits of low viscosity.
- the continuous phase of the fluid used in this invention can be wholly of one or more compounds of the formula (I), or it may contain other components used in admixture.
- aromatic hydrocarbons can be included it is unlikely that they will be used as a major component of any such mixed carrier fluid, because of the adverse environmental impact.
- non-aromatic hydrocarbon liquids e.g. paraffinic fluids may be used, but these are relatively non-biodegradable so will generally not be preferred.
- Mixtures of compounds of the formula (I) with fluid esters such as fatty acid esters e.g. of C-
- the fatty acid esters have moderately high viscosities e.g. /so-propyl oleate has a viscosity of ca 5.3 cSt at 40°C
- to CQ, more particularly a C3 to C5 branched chain alkyl group and especially where the ester is or includes /so-propyl benzoate can give mixtures with low viscosity.
- compounds of the formula (I) When mixtures are used, compounds of the formula (I) will typically be present in at least 10%, usually at least 25%, more usually at least 40%, desirably at least 50%, by weight of the total fluid used. When present, other solvent components will desirably be used at level typically of from 1 to 90, usually 1 to 75%, more desirably 2 to 60, and particularly 5 to 50% by weight of the total carrier fluid used. Relatively low proportions of esters of the formula (I) can be usefully used to reduce the viscosity of conventional non-aqueous, especially organic ester, fluids.
- the weight ratio of ester of the formula (I) to fatty acid esters will usually be from 9:1 to1 :9, more usually from 8:2 to 2:8.
- to CQ especially C3 to C5 secondary alkyl groups, such as /so-propyl, groups, or mixtures including relatively high proportions of such esters e.g. to have a fluid with a particularly low viscosity
- the potential for difficulties arising from interaction with conventional elastomeric seals may be overcome by using solvent resistant elastomeric well seals or by using metal well seals.
- the compounds of the formula (I) are particularly useful as or as components of drilling fluids.
- Drilling fluids are used in wells being drilled, to transport drill cuttings to the surface, to suspend cuttings in the absence of circulation, to maintain bore hole stability, to cool and lubricate the drill bit and drill string and to control sub-surface pressure and prevent corrosion. Desirably also they do not damage rock formations, particularly by exposing the rock to aqueous media, that are or have been drilled through and have minimum environmental impact.
- Drilling and similar fluids incorporating esters of the formula (I) can meet these requirements and are thus particularly useful as drilling, completion and workover fluids.
- the invention includes a method of drilling a well, particularly an oil well, in which the drilling fluid is or contains at least one compound of the formula (I) as defined above.
- Drilling fluids are usually formulated to have a liquid and a solid phase.
- the liquid phase is or includes at least one compound of the formula (I) and may take the form of a homogeneous liquid or an emulsion, most usually an "invert" emulsion of an aqueous phase in the non-aqueous liquid phase.
- the aqueous phase may contain salts, particularly inorganic salts, such as sodium chloride or calcium chloride up to saturation to increase the density of the fluid and/or alkali salts such as sodium hydroxide or sodium carbonate or lime to modify the pH of the system.
- the solid phase typically includes weighting material such as finely ground high density water insoluble solids, particularly solids having a specific gravity at ambient temperature of greater than 2.5 particularly up to 6 and commonly from 4 to 5.
- weighting materials include barium sulphate (in this use commonly known as barite or barytes) (SG ca 4.5), iron oxide, ilmenite (iron titanium oxide), siderite (iron carbonate), galena (lead sulphide), or manganese tetraoxide, ' to increase the density of the fluid.
- Basic materials such as calcium carbonate, dolomite (mixed calcium magnesium carbonate) or zinc oxide may be used as the, or included as a, solid to enable removal of solids by subsequent reaction with acid.
- Weighting solids typically have an average particle size in the range 20 to 200 mm. The amount used can vary widely so that the fluid density can be adjusted to provide the required hydrostatic pressure at the bottom of the well, in particular to prevent pressurised fluids (gasses or liquids) in strata through which the well is being drilled from flowing up the drilled well in an uncontrolled fashion. Typically amounts of weighting material used are in the range 0.2 to 2, more usually 0.25 to 1.5, kg.l " 1.
- Solids such as clays, particularly montmoriilonite, bentonite and/or attapulgite, may be added, usually at colloidal particle size, to modify the viscosity of the drilling fluid.
- Drilling fluids formulated with both liquid and solid phases are usually described as drilling muds.
- the invention further includes a drilling fluid which is a dispersion of weighting solids in an ester containing liquid phase which includes at least one compound of the formula (I) as defined above, and particularly where the liquid phase is an emulsion of an aqueous phase, which desirably includes dissolved inorganic salts, in a continuous phase of the ester containing liquid.
- the invention accordingly includes a drilling fluid which is an emulsion of an aqueous phase including dissolved salts in a continuous phase of an ester containing liquid including at least one compound of the formula (I), the fluid further including a dispersion of weighting solids.
- the invention also includes a method of drilling of the invention using such a drilling fluid.
- Drilling fluids incorporating esters of the formula (I) are particularly useful in demanding applications such as micro-hole drilling, slim hole drilling and coil tube drilling, because the low viscosity which can be obtained coupled with the lubricating effect of the oil enables good drilling operation. Accordingly, the invention specifically includes methods of micro-hole, slim hole and coil tube drilling using fluids containing compounds of the formula (I) as defined above.
- a well casing is normally cemented in place to isolate and protect the rock formations through which the well passes.
- the well casing is perforated at a level within the productive zone. This can be done by various methods such as jet perforation, bullet guns, hydraulic perforation, mechanical cutters and permeators.
- a formulated well completion fluid is generally used to minimise the damage to a potentially producing well.
- a completion fluid The main functions of a completion fluid are to carry solids, particularly weighting materials, used as in drilling fluids to provide hydrostatic pressure compensation, and to provide compatibility with the producing rock formation (reservoir rock) as most reservoir rocks are sensitive to any fluid other than that contained within them and completion fluids are generally formulated to minimise damage to the reservoir rock. Potentially, solids within the completion fluid can penetrate the reservoir rock and block flow passages in the formation and this harm may not be reparable subsequently and a recent trend is to use solid less completion fluids, at least for fluid in contact with the production zone.
- the invention accordingly further includes a method of completing a well, particularly an oil and/or gas well which includes introducing into the well, in contact with or adjacent the production zone of the well a completion fluid which is an emulsion of an aqueous phase in an ester containing liquid phase which includes at least one compound of the formula (I) as defined above.
- a completion fluid which is an emulsion of an aqueous phase in an ester containing liquid phase which includes at least one compound of the formula (I) as defined above.
- a workover fluid is somewhat different to that of a drilling fluid (mud)
- the primary function is to provide adequate hydrostatic head, and workover fluids may thus include weighting materials similar in type an amount to those used in drilling fluids, so that the workover operations can be carried out safely and without damaging the producing formation.
- the workover fluid may be used to lift solids such as sand, silt and/or gravel from the bottom of the well to the surface.
- Oil based systems include an oil as the continuous phase and frequently include an aqueous discontinuous phase. As with completion fluids, there is potential for solids to penetrate and damage the reservoir rock and a recent trend is to use solid less workover fluids, at least for fluid in contact with the production zone.
- the invention accordingly further includes a method of well workover, particularly on an oil and/or gas well which includes introducing into the well, in contact with or adjacent the production zone of the well a workover fluid which is an emulsion of an aqueous phase in an ester containing liquid phase which includes at least one compound of the formula (I) as defined above.
- completion or workover fluids particularly in oil and/or gas wells
- an overlying layer of a weighted well fluid to maintain adequate pressure at the production zone of the well e.g. to reduce the extent to which the oil and/or gas enters the well bore during completion or workover operations.
- Such fluids are typically referred to as completion or workover fluids although by including weighting, and usually, for oil based fluids, also salts dissolved in an emulsifed aqueous discontinuous phase, they are compositionally more similar to drilling fluids.
- the invention thus includes completion and workover methods in which the overlying fluid is a fluid of the invention, particularly having a composition as described generally for a drilling fluid of the invention.
- fluid loss control chemicals are commonly used in drilling, completion and workover fluids to reduce fluid loss. Fluid loss occurs when well fluids penetrate rock formations and particularly for completion and workover fluids it is desirable to minimise fluid loss to reduce or avoid the consequential damage to the production formation. Where solidless fluids are used, potentially the whole fluid can be lost into the formation. Loss control chemicals are materials that reduce the tendency of well fluids to be lost into rock formations and are typically hydrophilic polymers that increase the viscosity of the well fluid, particularly to give the fluid a pseudoplastic (shear thinning) rheological profile, to reduce the extent of fluid loss.
- Examples include carboxymethylcellulose and polyacrylonitrile, which are not acid soluble, xanthan gum which is typically about 50% acid soluble but biodegradable and hydroxyethyl cellulose and starch derivatives which are acid soluble.
- the advantage of acid soluble fluid loss control materials is that any such material that penetrates and potentially blocks the formation, can be removed by acid as in acidisation treatments.
- the proportion of fluid loss control chemicals used is typically from 0.1 to 2.5%, more usually from 0.8 to 2%, weight/volume of the fluid.
- rheology modifiers viscosifiers
- hydroxyethyl cellulose is particularly useful in fluids containing substantial amounts of inorganic salts such as sodium chloride.
- the concentration of rheology modifiers used is typically from 0.1 to 1%, more usually from
- corrosion inhibitors - are commonly included in drilling, completion and workover fluids, because well fluids including salts e.g. brine solutions as in invert emulsion drilling muds, are corrosive to some extent towards metal components e.g. pipework, that they contact, and corrosion inhibitors act to reduce or eliminate corrosion.
- Commonly used corrosion inhibitors include film forming amines and low molecular weight inorganic compounds that contain a sulphur group.
- oil based well fluids, particularly drilling muds are usually have low corrosion rates, because the oil continuous phase coats the metal pipelines with a non- conductive fluid thereby limiting the rate of corrosion.
- the oil phase of oil based fluids are generally free of bacteria (which often act to increase the rate of corrosion).
- the concentration of corrosion inhibitors used is typically from 0.1 to 1 % by weight of the fluid.
- the concentration of acid soluble solids used is typically from 0.3 to 3% by weight of the fluid.
- EmuH Hypermer B261 water in oil emulsifier co(polyester polyether) surfactant ex Uniqema
- An invert emulsion fluid was made up by mixing 27 parts by weight OiHand 3 parts by weight EmuH in a Hamilton beach blender under high shear.
- the aqueous phase a solution of 15 parts by weight calcium chloride in 55 parts by weight water, was prepared and added dropwise to the oil/emulsifier blend under high shear mixing (using a Silverson mixer) to form a water in oil emulsion.
- the emulsion temperature was maintained below 55°C using a (cold) water bath around the mixing vessel. Mixing was continued for 15 minutes after complete addition of the aqueous phase.
- the fresh emulsion, and samples of the emulsion stored at ambient temperature and 50°C for 4 days and 12 days, remained stable and showed no signs of creaming or separation.
- Example 2 An invert emulsion completion or workover fluid was made up as described in Example 1 but changing the aqueous phase to a solution of 13.9 parts by weight calcium chloride, 51.1 parts by weight water and 5 parts by weight Th1.
- Example 4 An invert emulsion was made up as described in Example 1 using a 80/20 by weight blend of Oil1 and Eoil 1 as the continuous phase. The product emulsion was stable, fresh and after storage at ambient temperature and 50° for 12 days.
- Example 4
- Example 2 An invert emulsion completion or workover fluid was made up as described in Example 2 using the 80/20 ester blend used in Example 3 as the continuous phase and an aqueous phase of a solution of 15 parts by weight calcium chloride, 53 parts by weight water and 2 parts by weight Th1.
- the emulsion was stable fresh and after storage for 4 days at ambient temperature and 50°, but showed some signs of instability after 12 days, although this was difficult to quantify because of air trapped in the emulsion.
- An invert drilling fluid was made by mixing 200 parts by weight of the fluid of Example 1 with 50 parts by weight barium sulphate having an average particle size of ca 50 ⁇ m as a weighting material.
- the weighting material dispersed well in the fluid although the high proportion of weighting material made the fluid rather stiff.
- Example 1 was repeated in several runs but substituting Oil 2, Oil 3, Oil 4, Oil 5 and Oil 6 for the Oil 1 used in Example 1.
- the emulsions were tested for stability as described in Example 1 and the results are set out in the table below (also including Example 1 results).
- Example 2 was repeated in a modified form using Oil 2, Oil 3, Oil 4, Oil 5 and Oil 6 instead of the Oil 1 used in Example 2 and in which the aqueous phase was a solution of 14.6 parts by weight calcium chloride, 53.4 parts by weight water and 2 parts by weight Th1 (using a reduced amount of thickener to avoid forming gels).
- the emulsions were tested for stability as described in Example 1 and the results are set out in the table below.
- Example 3 was repeated but substituting Oil 2, Oil 3, Oil 4, Oil 5 and Oil 6 instead of the Oil 1 used in Example 3 in the 80/20 by weight blends with Eoil 1 as the continuous phase.
- the emulsions were tested for stability as described in Example 1 and the results are set out in the table below (also including Example 3 results).
- Example 4 was repeated but substituting Oil 2, Oil 3, Oil 4, Oil 5 and Oil 6 instead of the Oil 1 used in Example 4 in the 80/20 by weight blends with Eoil 1 as the continuous phase and 14.6 parts by weight calcium chloride, 53.4 parts by weight water and 2 parts by weight Th1 as the aqueous phase.
- the emulsions were tested for stability as described in Example 1 and the results are set out in the table below (also including Example 4 results).
- Example 5 was repeated but substituting Oil 2, Oil 3, Oil 4, Oil 5 and Oil 6 instead of the Oil 1 used in Example 5 to make the emulsions. 10 parts barium sulphate were added to 90 parts of each of the emulsions to form the weighted mud. The amount of barium sulphate used was reduced (10% instead of 20% based on the total mud) to give drilling muds of lower viscosity. These muds were tested for stability as described in Example 1 and the results are set out in the table below (also including Example 5 results).
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- Chemical & Material Sciences (AREA)
- Oil, Petroleum & Natural Gas (AREA)
- Life Sciences & Earth Sciences (AREA)
- General Life Sciences & Earth Sciences (AREA)
- Engineering & Computer Science (AREA)
- Materials Engineering (AREA)
- Organic Chemistry (AREA)
- Lubricants (AREA)
- Perforating, Stamping-Out Or Severing By Means Other Than Cutting (AREA)
- Colloid Chemistry (AREA)
Abstract
Description
Claims
Priority Applications (9)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
CA002405153A CA2405153A1 (en) | 2000-05-15 | 2001-05-10 | Drilling fluids and method of drilling |
BR0110827-1A BR0110827A (en) | 2000-05-15 | 2001-05-10 | Method of drilling, completing or reconditioning a well, and drilling fluid, completing and / or reconditioning |
EA200201206A EA200201206A1 (en) | 2000-05-15 | 2001-05-10 | DRILLING SOLUTIONS AND DRILLING METHOD |
AU2001254963A AU2001254963A1 (en) | 2000-05-15 | 2001-05-10 | Drilling fluids and method of drilling |
JP2001585269A JP2003533582A (en) | 2000-05-15 | 2001-05-10 | Drilling fluid and drilling method |
EP01928097A EP1282674A1 (en) | 2000-05-15 | 2001-05-10 | Drilling fluids and method of drilling |
MXPA02011300A MXPA02011300A (en) | 2000-05-15 | 2001-05-10 | Drilling fluids and method of drilling. |
NO20025449A NO20025449L (en) | 2000-05-15 | 2002-11-14 | Drilling fluids and drilling methods |
US10/293,614 US7122507B2 (en) | 2000-05-15 | 2002-11-14 | Drilling fluids and method of drilling |
Applications Claiming Priority (4)
Application Number | Priority Date | Filing Date | Title |
---|---|---|---|
GB0011584.0 | 2000-05-15 | ||
GB0011584A GB0011584D0 (en) | 2000-05-15 | 2000-05-15 | Drilling fluids and methods of drilling |
US20503200P | 2000-05-18 | 2000-05-18 | |
US60/205,032 | 2000-05-18 |
Related Child Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
US10/293,614 Continuation US7122507B2 (en) | 2000-05-15 | 2002-11-14 | Drilling fluids and method of drilling |
Publications (1)
Publication Number | Publication Date |
---|---|
WO2001088059A1 true WO2001088059A1 (en) | 2001-11-22 |
Family
ID=26244262
Family Applications (1)
Application Number | Title | Priority Date | Filing Date |
---|---|---|---|
PCT/GB2001/002057 WO2001088059A1 (en) | 2000-05-15 | 2001-05-10 | Drilling fluids and method of drilling |
Country Status (5)
Country | Link |
---|---|
EP (1) | EP1282674A1 (en) |
JP (1) | JP2003533582A (en) |
AU (1) | AU2001254963A1 (en) |
MX (1) | MXPA02011300A (en) |
WO (1) | WO2001088059A1 (en) |
Cited By (4)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2002064712A1 (en) * | 2001-02-15 | 2002-08-22 | Imperial Chemical Industries Plc | A metal working lubricant composition |
CN100383215C (en) * | 2005-10-18 | 2008-04-23 | 中国石油大学(华东) | New method for using diverting agent of benzoic acid |
WO2012127230A3 (en) * | 2011-03-21 | 2012-12-13 | M-I Drilling Fluids Uk Limited | Invert drilling fluids |
CN106285713A (en) * | 2016-08-31 | 2017-01-04 | 中国铁建重工集团有限公司 | Cutter head for rock tunnel development machine |
Families Citing this family (2)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
US20080224087A1 (en) * | 2007-03-14 | 2008-09-18 | Ezell Ryan G | Aqueous-Based Insulating Fluids and Related Methods |
CN114275139B (en) * | 2021-11-19 | 2023-08-08 | 中国电子科技集团公司第三十八研究所 | Mechanical speed stabilizing device for tethered balloon |
Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0374672A1 (en) * | 1988-12-19 | 1990-06-27 | Henkel Kommanditgesellschaft auf Aktien | Use of selected fatty esters in drilling fluids, especially in offshore oil or gas recovery |
WO1993023491A1 (en) * | 1992-05-18 | 1993-11-25 | Exxon Chemical Patents Inc. | Functional fluid |
US5925182A (en) * | 1996-11-20 | 1999-07-20 | Phillips Petroleum Company | Stable liquid suspension compositions |
-
2001
- 2001-05-10 EP EP01928097A patent/EP1282674A1/en not_active Withdrawn
- 2001-05-10 AU AU2001254963A patent/AU2001254963A1/en not_active Abandoned
- 2001-05-10 WO PCT/GB2001/002057 patent/WO2001088059A1/en not_active Application Discontinuation
- 2001-05-10 MX MXPA02011300A patent/MXPA02011300A/en unknown
- 2001-05-10 JP JP2001585269A patent/JP2003533582A/en active Pending
Patent Citations (3)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
EP0374672A1 (en) * | 1988-12-19 | 1990-06-27 | Henkel Kommanditgesellschaft auf Aktien | Use of selected fatty esters in drilling fluids, especially in offshore oil or gas recovery |
WO1993023491A1 (en) * | 1992-05-18 | 1993-11-25 | Exxon Chemical Patents Inc. | Functional fluid |
US5925182A (en) * | 1996-11-20 | 1999-07-20 | Phillips Petroleum Company | Stable liquid suspension compositions |
Cited By (5)
Publication number | Priority date | Publication date | Assignee | Title |
---|---|---|---|---|
WO2002064712A1 (en) * | 2001-02-15 | 2002-08-22 | Imperial Chemical Industries Plc | A metal working lubricant composition |
CN100383215C (en) * | 2005-10-18 | 2008-04-23 | 中国石油大学(华东) | New method for using diverting agent of benzoic acid |
WO2012127230A3 (en) * | 2011-03-21 | 2012-12-13 | M-I Drilling Fluids Uk Limited | Invert drilling fluids |
CN106285713A (en) * | 2016-08-31 | 2017-01-04 | 中国铁建重工集团有限公司 | Cutter head for rock tunnel development machine |
CN106285713B (en) * | 2016-08-31 | 2019-02-19 | 中国铁建重工集团有限公司 | Cutter head for rock tunnel development machine |
Also Published As
Publication number | Publication date |
---|---|
EP1282674A1 (en) | 2003-02-12 |
MXPA02011300A (en) | 2003-06-06 |
JP2003533582A (en) | 2003-11-11 |
AU2001254963A1 (en) | 2001-11-26 |
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