CA1271320A - Drilling fluid - Google Patents
Drilling fluidInfo
- Publication number
- CA1271320A CA1271320A CA000552823A CA552823A CA1271320A CA 1271320 A CA1271320 A CA 1271320A CA 000552823 A CA000552823 A CA 000552823A CA 552823 A CA552823 A CA 552823A CA 1271320 A CA1271320 A CA 1271320A
- Authority
- CA
- Canada
- Prior art keywords
- drilling fluid
- oil
- drilling
- fluid
- ethoxylated
- 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.)
- Expired - Fee Related
Links
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
- C09K8/04—Aqueous well-drilling compositions
- C09K8/26—Oil-in-water emulsions
Abstract
A B S T R A C T
DRILLING FLUID
A drilling fluid comprising a stable oil in water emulsion consisting of a) 50-96 %v aqueous phase b) 3-40 %v oil phase c) 1-10 %v of at least one surfactant belonging to the class of a) ethoxylated amines;
b) ethoxylated diamines; and c) quaternary ethoxylated ammonium salts.
DRILLING FLUID
A drilling fluid comprising a stable oil in water emulsion consisting of a) 50-96 %v aqueous phase b) 3-40 %v oil phase c) 1-10 %v of at least one surfactant belonging to the class of a) ethoxylated amines;
b) ethoxylated diamines; and c) quaternary ethoxylated ammonium salts.
Description
3~
DRI~LING ~L~ID
The invention relates to a drilling fluid comprising a stable oil in water emulsion consisting of a) 50-96 %v aqueous phase b) 3-40 %v oil phase c) 1-10 %v of at least one surfactant belonging to the class (a) of ethoxylated amines having the formula:
DRI~LING ~L~ID
The invention relates to a drilling fluid comprising a stable oil in water emulsion consisting of a) 50-96 %v aqueous phase b) 3-40 %v oil phase c) 1-10 %v of at least one surfactant belonging to the class (a) of ethoxylated amines having the formula:
2~ (~H2-CH2~)X-H
\ (-CH2-CH2-0-)y~H in which R is any hydrophobic organic group and x and y are integers >1I the sum of which is in the range of fram 4~20, and/or to the class (b) of ethoxylated diamlnes having the formula:
~(--CH2--CH2-0--)z-H
R-N (-CH2-cH2--)x-H
2) n~N\
( 2 2 )y in which R is any hydrophobic organic group, x, y and z are integers ' 1, the sum of which is in the range of from 4 to 20 and n is an integer in range of from 1 to 6, and/or to the class (c) of quaternary ethoxylated ammonium salts having the formula:
~ CH2-CH2-9-) ~ A( ) LR2 (~2 CH2 Y ~
in which ~ and R2 are any hydrophobic organic groups, x and y are integers > 1 the sum of which is in the range of from 2 to 20 and A is any anion.
When drilling subterranean wells such as, for example, oil or gas wells, the rotary drilling method is com~.only employed. The rotary drilling method utilizes a bit attached to a drill stem, and ~.~'7~32(:3 a clrilling fluid or "mud" which is circulated through the drill stem to the bottom of the borehole where it is ejected through small openings in the drill bit. The fluid is -then re-turned to the surface through the c~nnular space between the clrill stem and the borehole wall, or casing if one has been installed. Upon reachiny the surface, the clrilling fluid or "mud" is ordinarily treated to remove cuttings obtained fram the borehole, and is then recirculated.
Drilling fluids serve many functions, and should therefore possess a number of desirable physical and rheological properties.
For example, the viscosity of a drilling fluid should be sufficient to permit it to effectively transport bit cuttings fram the bottc~l of the borehole to the surface for remaval. ~ drilling fluid should alco prevent excessive amounts of fluid from flawing fram the borehole into surrounding formations by depositing on the wall of the hole a thin but substantially impervious filter cake. In ad-dition, a drilling fluid should be able to hold solids in sus-pension, preventing their return to the bottom of the hole when the circulation is reduced or temporarily interrupted. This proper-ty can be obtained by utilizing additives which will impart a gel structure to the drilling fluid to increase viscosities. me gel structure, however, is preferably such that cuttings can be removed from the drilling fluid by passing the fluid through filtration equipment such as a shale shaker and/or sand cyclones prior to recirculating the fluid to the drill bit. A drilling fluid must also exert pressure on the surrounding formations, thus preventing possible collapse of the borehole or influx of highly pressurized oil or gas in the formation. Finally, a drilling fluid should serve as a lubricating and cooling agent for the drill string and the bit.
Drilling of easily dispersible formations such as shalest marls and chaIks often presents a problem in mud solids control.
Drilled solids tend to disintegrate in the drilling fluid while being transported to surface and the fines thus created are very diEficult to remove. A build-up of fines is the consequence and leads to an increased viscosity of the drilling Eluid and a decreased rate of penetration of the drilling operation. Ultimately n~1d dilution is required to recondition the mud or drilling fluid.
A method to combat drilled solids disintegration is the application of the drilling fluid according to the invention. This "mud" prevents disintegration of cuttings and so delays the build-up of fines.
In addition the present invention relates to a concept in mud engineering which involves the drilling of a well by the use of an oil in water emulsion which deposits its oil phase onto mineral surfaces. In this manner the interaction of the water phase of the mud and troublesome shale zones is greatly lowered or prevented completely and this facilitates the easy drilling of the well.
A preferred composition of the mud system according to the invention is as follows:
a) 87-93 ~v aqueous phase b) 4-8 %v oil phase c) 3-5 %v surfactant.
The heart of the system is the nature of the surfactant interfacial phase, i.e. at least one ethoxylated amine, ethoxylated diamine and/or quaternary ethoxylated ammonium salt which acts both to disperse the oil phase throughout the aqueous phase and also to coat it out onto mineral surfaces, including troublescme shale zones. What distinguishes the present system from those previously existing is the effectiveness of the coating in preventing the undesirable water-shale interactions and the ease with which it is incorporated into typical drilling fluid systems. The ethoxylate amines and diamines and the quaternary ethoxylated ammonium salts are essential for the present drilling fluid and none of the surfactants used in the drilling muds according to the existing patent specifications or present in the cc~,mercially available systems give as good results as the ethoxylate amines and diamines and the quaternary ethoxylated ammonium salts.
The ethoxylated amines and diamines are ccmmercially available surfactants with the following chemical formulas, respectively:
2 ~12~)x ~1 R-N
( 2 2 )y and / (~12~l2~? Z
R-N \ /( 2 2 )x H
(~CH2)n~N
( 2 2 ~y The "R" group may be any hydrophobic organic group, aliphatic or aromatic, saturated or unsaturated, straight chained or branched and a preferred set of groups are those derived fram tallcw, olive oil or coconut oil. The number of ethylene oxide units is chosen to balance the particular hydrophobic group in any particular case and hence provide the desireable emulsification and wetting properties.
When the "R" group is derived from tallow, the preferred number of ethylene oxide groups is approximately 15, but this can vary considerably depending upon the expected conditions of use. For low or moderate temperatures, approximately 5 units will suffice and in conditions of very high temperatures or very high salinity, more than 15 may be necessary. me integer n is preferably 3.
The quaternary ethoxylated ammonium salts are also produced on a commercial scale. They are surfactants with the chemical formula:
~ 2-CH2-O-)xHl 1_2 (-CH2 C~I2-O-)yH¦
me "~ " and "R2" groups may be any hydropho~ic organic groups, aliphatic or aromatic, saturated or unsaturated, straight chained or branched. A preferred set of groups are those derived from tallow, coconut oil or oli~e oil. The "R2" group is more preferably a methyl group. The number of ethylene oxide units is in the range of from 2 to 20. When the "~ " group is derived from tallcw and the "~ " group is a methyl group the preferred number of ethylene oxide groups about 15, but this can vary depending upon the conditions of use. The A( ) symbolizes any ~lorganic or organic anion, but in actual practice A( ) m~stly represents the chloride anion.
~1~2~7~
These surfactants form stable oil in water emulsions over a wide composition range, for example:
75% water phase/20% oil phase/5% surfactant 50~ water phase/40~ oil phase/10% surfactant These compositions are intended to be illustrative and not exhaustive and the exact one chosen for any particular application will depend upon the exact nature of the problem. Obviously, for both environ-mental and cost considerations the minimum oil/surfactant phase necessary to effectively coat the wellbore and cuttings surfaces is desirable but balanced by the need to maintain the fluid properties without constant new chemicals addition as the well is deepened.
This amount must be selected for any given case with a knowledge of the sensitivity of the particular shale being penetrated and of the operating conditions (drilling rate etc.) being used. In th~
laboratory a 90% water phase/6% oil phase/4% surfactant composition has been found to provide good shale inhibition and fluid maintenance properties for two particular shale types tested ~Pierre and Hutton shale) but this is in no way the only composition which could be used or even the most desirable in any given field application.
The oil phase is taken to mean any aqueous immiscible fluid which can be successfully emulsified by the surfactant phase and coated out onto m1neral surfaces to reduce their interaction with the aqueous phase. Examples of these include mineral oils such as diesel or napthenic oils such as Shellsol r~ ~ and also vegetable or other natural oils.
The aqueous phase is taken to mean water or any solution in which water is the solvent such as sea water or where electrolytes or other chemicals are deliberately added to achieve or enhance useful fluid properties. To enhance the inhibiting effects of the emulsions in cases of highly swelling shales it is advantageous to add 1-15 per cent of a potassium salt such as potassium chloride to the water base.
To be useful as a well drilling fluid it is suitable to build certain other properties into such emulsions including desirable ~'7~
rheoloyies, densities and fluicl loss ch~aracteristics and these are achieved using the standard technology of mud enyLneeriny summarized below.
Desirable rheoloyies are normally obtained using either clay suspensions or dissolved polymers. me list of possibilities is enormous but generally the common mud viscosifiers such as pre-hydrated bentonite or Xanthan gum have been found to be preferred.
These are intended to be advantageous and illustrative examples and not exhaustive and any viscosifier which imparts a useful drilling fluid rheology and is compatible with the other system CGmpOnents may be considered.
me variation of fluid density is achieved using the standard technology of mud enyineering and usually by the suspension of high density solids such as barium sulphate in the viscosified fluid.
me adjusbment of the filtration properties of the emulsions is again carried out using the standard technology of mud engineering by the addition of suspended clays or dissolved polymers such as bentonite, carboxymethyl cellulose or starches etc.
The invention does not only relate to the formulation of oil in water emulsions which coat out onto shale or other mineral surfaces but also to the incorporation of such an emulsion into a fluid useful for well drilling completing and working over, using the standard available mud technology.
Example The cuttings dispersion test, used to evaluate the interaction between shale cuttings and particular drilling fluids is carried out as follcws:
Shale (in this case Hutton shale from the U.K. North Sea) is ground and sieved and the fraction between sieves 1.7-2.7 mm is collected and equilibrated with water. Twenty grams of e~uilibrated shale cuttings is immersed in 350 mls of the drilling fluid and rolled at 50 rpm and 60 degrees centrigrade for 24 hours. After this time the cuttings are collected over a 1.4 mm sieve, washed, dried, re-equilibrated with water and the percentage weight 105s of the cuttings calculated. If there was a very large interaction ~ti;~
between the fluid and ~he shale cuttings the shale will have dispersed into very small particles and hence little will be collected over the 1.8 mm sieve; conversely, if there was little interaction between the shale cuttings and the drllliTIg fluid the cuttings will have largely remained the same dimensions and up to 100~ will be collected.
Thus rolling the cu~tings in pure diesel oil results in 100%
recovery while rolling in pure water results in 0% recovery and it is therefore concluded that there is little interaction between the diesel oil and the cuttings but a large interaction between the water and the cuttings. All the "real" drilling fluids were evaluated on this scale.
me cuttings dispersion test gives a reasonable idea of the extent of the interaction, chemical and mechanical, bet~een the drilling fluid and the shale cuttings and has been found in the laboratory to be accurate and reproducible to within 2 per cent.
The results of some cuttings dispersion tests are given belcw, the higher the percentage recovery the less is the interaction between the shale and the fluid and hence the better the per-forrnance of the fluid.
The shale inhibiting drilling fluids were of three types,depending on the surfactant contained therein They consisted of 90 %v aqueous phase/6 %v oil phase/4 %v surfactant. All three muds used in this example were formulated to have a yield point (= yield value as defined in the book "Ccmposition and properties of oil well drilling fluids" by W.F. Rogers, Gulf Publishing Co. ~1953) p. 232) of 15 and were unweighed.
Since sea water is often used as the base aqueous fluid in offshore locations the emulsion muds were compared with each other, seawater being the aqueous phase.
713~
SURFACTANT TYPE S~L~LE TYPE % RECOVERY
1) Ethoxylated amlne Hutton 98 (x+y--15, R derived from tallow) 2) Ethoxylated diamine Hutton 98 (x+y~zal5, n = 3, R derived frc~m tallc~w)
\ (-CH2-CH2-0-)y~H in which R is any hydrophobic organic group and x and y are integers >1I the sum of which is in the range of fram 4~20, and/or to the class (b) of ethoxylated diamlnes having the formula:
~(--CH2--CH2-0--)z-H
R-N (-CH2-cH2--)x-H
2) n~N\
( 2 2 )y in which R is any hydrophobic organic group, x, y and z are integers ' 1, the sum of which is in the range of from 4 to 20 and n is an integer in range of from 1 to 6, and/or to the class (c) of quaternary ethoxylated ammonium salts having the formula:
~ CH2-CH2-9-) ~ A( ) LR2 (~2 CH2 Y ~
in which ~ and R2 are any hydrophobic organic groups, x and y are integers > 1 the sum of which is in the range of from 2 to 20 and A is any anion.
When drilling subterranean wells such as, for example, oil or gas wells, the rotary drilling method is com~.only employed. The rotary drilling method utilizes a bit attached to a drill stem, and ~.~'7~32(:3 a clrilling fluid or "mud" which is circulated through the drill stem to the bottom of the borehole where it is ejected through small openings in the drill bit. The fluid is -then re-turned to the surface through the c~nnular space between the clrill stem and the borehole wall, or casing if one has been installed. Upon reachiny the surface, the clrilling fluid or "mud" is ordinarily treated to remove cuttings obtained fram the borehole, and is then recirculated.
Drilling fluids serve many functions, and should therefore possess a number of desirable physical and rheological properties.
For example, the viscosity of a drilling fluid should be sufficient to permit it to effectively transport bit cuttings fram the bottc~l of the borehole to the surface for remaval. ~ drilling fluid should alco prevent excessive amounts of fluid from flawing fram the borehole into surrounding formations by depositing on the wall of the hole a thin but substantially impervious filter cake. In ad-dition, a drilling fluid should be able to hold solids in sus-pension, preventing their return to the bottom of the hole when the circulation is reduced or temporarily interrupted. This proper-ty can be obtained by utilizing additives which will impart a gel structure to the drilling fluid to increase viscosities. me gel structure, however, is preferably such that cuttings can be removed from the drilling fluid by passing the fluid through filtration equipment such as a shale shaker and/or sand cyclones prior to recirculating the fluid to the drill bit. A drilling fluid must also exert pressure on the surrounding formations, thus preventing possible collapse of the borehole or influx of highly pressurized oil or gas in the formation. Finally, a drilling fluid should serve as a lubricating and cooling agent for the drill string and the bit.
Drilling of easily dispersible formations such as shalest marls and chaIks often presents a problem in mud solids control.
Drilled solids tend to disintegrate in the drilling fluid while being transported to surface and the fines thus created are very diEficult to remove. A build-up of fines is the consequence and leads to an increased viscosity of the drilling Eluid and a decreased rate of penetration of the drilling operation. Ultimately n~1d dilution is required to recondition the mud or drilling fluid.
A method to combat drilled solids disintegration is the application of the drilling fluid according to the invention. This "mud" prevents disintegration of cuttings and so delays the build-up of fines.
In addition the present invention relates to a concept in mud engineering which involves the drilling of a well by the use of an oil in water emulsion which deposits its oil phase onto mineral surfaces. In this manner the interaction of the water phase of the mud and troublesome shale zones is greatly lowered or prevented completely and this facilitates the easy drilling of the well.
A preferred composition of the mud system according to the invention is as follows:
a) 87-93 ~v aqueous phase b) 4-8 %v oil phase c) 3-5 %v surfactant.
The heart of the system is the nature of the surfactant interfacial phase, i.e. at least one ethoxylated amine, ethoxylated diamine and/or quaternary ethoxylated ammonium salt which acts both to disperse the oil phase throughout the aqueous phase and also to coat it out onto mineral surfaces, including troublescme shale zones. What distinguishes the present system from those previously existing is the effectiveness of the coating in preventing the undesirable water-shale interactions and the ease with which it is incorporated into typical drilling fluid systems. The ethoxylate amines and diamines and the quaternary ethoxylated ammonium salts are essential for the present drilling fluid and none of the surfactants used in the drilling muds according to the existing patent specifications or present in the cc~,mercially available systems give as good results as the ethoxylate amines and diamines and the quaternary ethoxylated ammonium salts.
The ethoxylated amines and diamines are ccmmercially available surfactants with the following chemical formulas, respectively:
2 ~12~)x ~1 R-N
( 2 2 )y and / (~12~l2~? Z
R-N \ /( 2 2 )x H
(~CH2)n~N
( 2 2 ~y The "R" group may be any hydrophobic organic group, aliphatic or aromatic, saturated or unsaturated, straight chained or branched and a preferred set of groups are those derived fram tallcw, olive oil or coconut oil. The number of ethylene oxide units is chosen to balance the particular hydrophobic group in any particular case and hence provide the desireable emulsification and wetting properties.
When the "R" group is derived from tallow, the preferred number of ethylene oxide groups is approximately 15, but this can vary considerably depending upon the expected conditions of use. For low or moderate temperatures, approximately 5 units will suffice and in conditions of very high temperatures or very high salinity, more than 15 may be necessary. me integer n is preferably 3.
The quaternary ethoxylated ammonium salts are also produced on a commercial scale. They are surfactants with the chemical formula:
~ 2-CH2-O-)xHl 1_2 (-CH2 C~I2-O-)yH¦
me "~ " and "R2" groups may be any hydropho~ic organic groups, aliphatic or aromatic, saturated or unsaturated, straight chained or branched. A preferred set of groups are those derived from tallow, coconut oil or oli~e oil. The "R2" group is more preferably a methyl group. The number of ethylene oxide units is in the range of from 2 to 20. When the "~ " group is derived from tallcw and the "~ " group is a methyl group the preferred number of ethylene oxide groups about 15, but this can vary depending upon the conditions of use. The A( ) symbolizes any ~lorganic or organic anion, but in actual practice A( ) m~stly represents the chloride anion.
~1~2~7~
These surfactants form stable oil in water emulsions over a wide composition range, for example:
75% water phase/20% oil phase/5% surfactant 50~ water phase/40~ oil phase/10% surfactant These compositions are intended to be illustrative and not exhaustive and the exact one chosen for any particular application will depend upon the exact nature of the problem. Obviously, for both environ-mental and cost considerations the minimum oil/surfactant phase necessary to effectively coat the wellbore and cuttings surfaces is desirable but balanced by the need to maintain the fluid properties without constant new chemicals addition as the well is deepened.
This amount must be selected for any given case with a knowledge of the sensitivity of the particular shale being penetrated and of the operating conditions (drilling rate etc.) being used. In th~
laboratory a 90% water phase/6% oil phase/4% surfactant composition has been found to provide good shale inhibition and fluid maintenance properties for two particular shale types tested ~Pierre and Hutton shale) but this is in no way the only composition which could be used or even the most desirable in any given field application.
The oil phase is taken to mean any aqueous immiscible fluid which can be successfully emulsified by the surfactant phase and coated out onto m1neral surfaces to reduce their interaction with the aqueous phase. Examples of these include mineral oils such as diesel or napthenic oils such as Shellsol r~ ~ and also vegetable or other natural oils.
The aqueous phase is taken to mean water or any solution in which water is the solvent such as sea water or where electrolytes or other chemicals are deliberately added to achieve or enhance useful fluid properties. To enhance the inhibiting effects of the emulsions in cases of highly swelling shales it is advantageous to add 1-15 per cent of a potassium salt such as potassium chloride to the water base.
To be useful as a well drilling fluid it is suitable to build certain other properties into such emulsions including desirable ~'7~
rheoloyies, densities and fluicl loss ch~aracteristics and these are achieved using the standard technology of mud enyLneeriny summarized below.
Desirable rheoloyies are normally obtained using either clay suspensions or dissolved polymers. me list of possibilities is enormous but generally the common mud viscosifiers such as pre-hydrated bentonite or Xanthan gum have been found to be preferred.
These are intended to be advantageous and illustrative examples and not exhaustive and any viscosifier which imparts a useful drilling fluid rheology and is compatible with the other system CGmpOnents may be considered.
me variation of fluid density is achieved using the standard technology of mud enyineering and usually by the suspension of high density solids such as barium sulphate in the viscosified fluid.
me adjusbment of the filtration properties of the emulsions is again carried out using the standard technology of mud engineering by the addition of suspended clays or dissolved polymers such as bentonite, carboxymethyl cellulose or starches etc.
The invention does not only relate to the formulation of oil in water emulsions which coat out onto shale or other mineral surfaces but also to the incorporation of such an emulsion into a fluid useful for well drilling completing and working over, using the standard available mud technology.
Example The cuttings dispersion test, used to evaluate the interaction between shale cuttings and particular drilling fluids is carried out as follcws:
Shale (in this case Hutton shale from the U.K. North Sea) is ground and sieved and the fraction between sieves 1.7-2.7 mm is collected and equilibrated with water. Twenty grams of e~uilibrated shale cuttings is immersed in 350 mls of the drilling fluid and rolled at 50 rpm and 60 degrees centrigrade for 24 hours. After this time the cuttings are collected over a 1.4 mm sieve, washed, dried, re-equilibrated with water and the percentage weight 105s of the cuttings calculated. If there was a very large interaction ~ti;~
between the fluid and ~he shale cuttings the shale will have dispersed into very small particles and hence little will be collected over the 1.8 mm sieve; conversely, if there was little interaction between the shale cuttings and the drllliTIg fluid the cuttings will have largely remained the same dimensions and up to 100~ will be collected.
Thus rolling the cu~tings in pure diesel oil results in 100%
recovery while rolling in pure water results in 0% recovery and it is therefore concluded that there is little interaction between the diesel oil and the cuttings but a large interaction between the water and the cuttings. All the "real" drilling fluids were evaluated on this scale.
me cuttings dispersion test gives a reasonable idea of the extent of the interaction, chemical and mechanical, bet~een the drilling fluid and the shale cuttings and has been found in the laboratory to be accurate and reproducible to within 2 per cent.
The results of some cuttings dispersion tests are given belcw, the higher the percentage recovery the less is the interaction between the shale and the fluid and hence the better the per-forrnance of the fluid.
The shale inhibiting drilling fluids were of three types,depending on the surfactant contained therein They consisted of 90 %v aqueous phase/6 %v oil phase/4 %v surfactant. All three muds used in this example were formulated to have a yield point (= yield value as defined in the book "Ccmposition and properties of oil well drilling fluids" by W.F. Rogers, Gulf Publishing Co. ~1953) p. 232) of 15 and were unweighed.
Since sea water is often used as the base aqueous fluid in offshore locations the emulsion muds were compared with each other, seawater being the aqueous phase.
713~
SURFACTANT TYPE S~L~LE TYPE % RECOVERY
1) Ethoxylated amlne Hutton 98 (x+y--15, R derived from tallow) 2) Ethoxylated diamine Hutton 98 (x+y~zal5, n = 3, R derived frc~m tallc~w)
3) Quaternary ethoxylated Hutton 99 ammonium chloride (x+y=15, Rl is derived frc~n tallow, R2 is a methyl group) As a cc~parative experiment a typical gypsum/lignosulphonate mud was tested in the same manner as describecd hereinbefore using Hutton shale. me recovery was now only 11%. m e superiority of the present systems is clearly demonstrated by the results of the above experiments.
Claims (9)
1. A drilling fluid comprising a stable oil in water emulsion consisting of a) 50-96 %v aqueous phase b) 3-40 %v oil phase c) 1-10 %v of at least one surfactant belonging to the class (a) of ethoxylated amines having the formula:
in which R is any hydrophobic organic group and x and y are integers ? 1, the sum of which is in the range of from 4-20, and/or to the class (b) of ethoxylated diamines having the formula:
in which R is any hydrophobic organic group, x, y and z are integers ? 1, the sum of which is in the range of from 4 to 20 and n is an integer in range of from 1 to 6, and/or to the class (c) of quaternary ethoxylated ammonium salts having the formula:
in which R1 and R2 are any hydrophobic organic groups x and y are integers ? 1 the sum of which is in the range of from 2 to 20 and A is any anion.
in which R is any hydrophobic organic group and x and y are integers ? 1, the sum of which is in the range of from 4-20, and/or to the class (b) of ethoxylated diamines having the formula:
in which R is any hydrophobic organic group, x, y and z are integers ? 1, the sum of which is in the range of from 4 to 20 and n is an integer in range of from 1 to 6, and/or to the class (c) of quaternary ethoxylated ammonium salts having the formula:
in which R1 and R2 are any hydrophobic organic groups x and y are integers ? 1 the sum of which is in the range of from 2 to 20 and A is any anion.
2. A drilling fluid as claimed in claim 1 in which at least one of the hydrophobic groups R, R1 and R2 is derived from tallow, coconut oil or olive oil.
3. A drilling fluid as claimed in claim 1, in which R2 is a methyl group.
4. A drilling fluid as claimed in claim 1, 2 or 3, in which 4-8 %v oil phase and 3-5 %v surfactant is present.
5. A drilling fluid as claimed in claim 1, 2 or 3, in which in the aqueous phase from 1 to 15 %wt of a potassium salt is present.
6. A drilling fluid as claimed in claim 1, 2 or 3, in which a clay suspension is present.
7. A drilling fluid as claimed in claim 1, 2 or 3, in which Xanthan gum is present.
8. A drilling fluid as claimed in claim 1, 2 or 3, in which n = 3.
9. A process for drilling, completing or working over a well in an underground formation in which process a drilling fluid as claimed in claim 1, 2 or 3 is circulated.
Applications Claiming Priority (2)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| GB8630295 | 1986-12-18 | ||
| GB868630295A GB8630295D0 (en) | 1986-12-18 | 1986-12-18 | Drilling fluid |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CA1271320A true CA1271320A (en) | 1990-07-10 |
Family
ID=10609237
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CA000552823A Expired - Fee Related CA1271320A (en) | 1986-12-18 | 1987-11-26 | Drilling fluid |
Country Status (10)
| Country | Link |
|---|---|
| US (1) | US4828724A (en) |
| EP (1) | EP0271943A3 (en) |
| AU (1) | AU596251B2 (en) |
| CA (1) | CA1271320A (en) |
| DK (1) | DK659587A (en) |
| GB (1) | GB8630295D0 (en) |
| MY (1) | MY103007A (en) |
| NO (1) | NO875261L (en) |
| NZ (1) | NZ222943A (en) |
| OA (1) | OA08786A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7951755B2 (en) | 2002-12-02 | 2011-05-31 | An-Ming Wu | Emulsified polymer drilling fluid and methods of preparation |
Families Citing this family (44)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| GB8902762D0 (en) * | 1989-02-08 | 1989-03-30 | Shell Int Research | Surfactant composition |
| DE3915876A1 (en) * | 1989-05-16 | 1990-11-22 | Henkel Kgaa | USE OF SELECTED ESTEROILS IN WATER-BASED DRILLING RINSES OF THE O / W EMULSION TYPE AND CORRESPONDING DRILLING LIQUIDS WITH IMPROVED ECOLOGICAL TOLERABILITY |
| DE3915875A1 (en) * | 1989-05-16 | 1990-11-22 | Henkel Kgaa | USE OF SELECTED OLEOPHILIC ALCOHOLS IN WATER-BASED DRILLING PIPES OF THE O / W EMULSION TYPE AND CORRESPONDING DRILLING FLUIDS WITH IMPROVED ECOLOGICAL RELIABILITY |
| DE3916550A1 (en) * | 1989-05-20 | 1990-11-22 | Henkel Kgaa | USE OF SELECTED OLEOPHILER ETHERS IN WATER-BASED DRILLING RINSES OF THE O / W EMULSION TYPE AND CORRESPONDING DRILLING LIQUIDS WITH IMPROVED ECOLOGICAL COMPATIBILITY |
| US5061386A (en) * | 1990-07-16 | 1991-10-29 | Shell Oil Company | Surfactant composition |
| US5908814A (en) * | 1991-10-28 | 1999-06-01 | M-I L.L.C. | Drilling fluid additive and method for inhibiting hydration |
| US5350740A (en) * | 1991-10-28 | 1994-09-27 | M-1 Drilling Fluids Company | Drilling fluid additive and method for inhibiting hydration |
| US5424284A (en) * | 1991-10-28 | 1995-06-13 | M-I Drilling Fluids Company | Drilling fluid additive and method for inhibiting hydration |
| US5678631A (en) * | 1994-07-01 | 1997-10-21 | Well-Flow Technologies, Inc. | Process for removing solids from a well drilling system |
| US5773390A (en) * | 1994-07-01 | 1998-06-30 | Well-Flow Technologies, Inc. | Chemical additive for removing solids from a well drilling system |
| US5635458A (en) * | 1995-03-01 | 1997-06-03 | M-I Drilling Fluids, L.L.C. | Water-based drilling fluids for reduction of water adsorption and hydration of argillaceous rocks |
| US6589917B2 (en) | 1996-08-02 | 2003-07-08 | M-I Llc | Invert emulsion drilling fluids and muds having negative alkalinity and elastomer compatibility |
| US6806233B2 (en) * | 1996-08-02 | 2004-10-19 | M-I Llc | Methods of using reversible phase oil based drilling fluid |
| US5905061A (en) * | 1996-08-02 | 1999-05-18 | Patel; Avind D. | Invert emulsion fluids suitable for drilling |
| US6218342B1 (en) | 1996-08-02 | 2001-04-17 | M-I Llc | Oil-based drilling fluid |
| US5888944A (en) * | 1996-08-02 | 1999-03-30 | Mi L.L.C. | Oil-based drilling fluid |
| US5909779A (en) * | 1997-08-19 | 1999-06-08 | M-I L.L.C. | Oil-based drilling fluids suitable for drilling in the presence of acidic gases |
| US6793025B2 (en) * | 1998-01-08 | 2004-09-21 | M-I L. L. C. | Double emulsion based drilling fluids |
| US6405809B2 (en) | 1998-01-08 | 2002-06-18 | M-I Llc | Conductive medium for openhold logging and logging while drilling |
| US6247543B1 (en) | 2000-02-11 | 2001-06-19 | M-I Llc | Shale hydration inhibition agent and method of use |
| US6857485B2 (en) | 2000-02-11 | 2005-02-22 | M-I Llc | Shale hydration inhibition agent and method of use |
| US6484821B1 (en) | 2000-11-10 | 2002-11-26 | M-I L.L.C. | Shale hydration inhibition agent and method of use |
| US6609578B2 (en) | 2000-02-11 | 2003-08-26 | Mo M-I Llc | Shale hydration inhibition agent and method of use |
| US6881349B2 (en) | 2002-11-15 | 2005-04-19 | M-I Llc | Method for recycling of oil based drilling fluid contaminated with water and water contaminated with oil based drilling fluid |
| WO2002086280A1 (en) | 2001-04-24 | 2002-10-31 | M-I L.L.C. | Method of recycling water contaminated oil based drilling fluid |
| US7638150B2 (en) * | 2002-08-02 | 2009-12-29 | Simply Thick Llp | Process for preparing concentrate thickener compositions |
| GB2378716B (en) * | 2001-08-08 | 2004-01-14 | Mi Llc | Process fluid |
| US6828279B2 (en) | 2001-08-10 | 2004-12-07 | M-I Llc | Biodegradable surfactant for invert emulsion drilling fluid |
| US7148183B2 (en) * | 2001-12-14 | 2006-12-12 | Baker Hughes Incorporated | Surfactant-polymer composition for substantially solid-free water based drilling, drill-in, and completion fluids |
| US6831043B2 (en) * | 2002-01-31 | 2004-12-14 | M-I Llc | High performance water based drilling mud and method of use |
| ES2319990T3 (en) * | 2003-01-31 | 2009-05-18 | Simply Thick Llc | DRINKS DRESSED IMPROVED FOR DYSPHAGIA. |
| US7084092B2 (en) * | 2003-08-25 | 2006-08-01 | M-I L.L.C. | Shale hydration inhibition agent and method of use |
| US7178610B2 (en) * | 2004-08-11 | 2007-02-20 | Halliburton Energy Services, Inc. | Subterranean treatment fluids comprising polyoxazoline compositions and methods of use in subterranean formations |
| GB2427630B (en) | 2005-06-30 | 2007-11-07 | Schlumberger Holdings | Methods and materials for zonal isolation |
| WO2007107502A1 (en) * | 2006-03-21 | 2007-09-27 | Akzo Nobel N.V. | Additive for preserving the fluidity of fluids containing gas hydrates |
| GB2446400B (en) | 2007-02-08 | 2009-05-06 | Mi Llc | Water-based drilling fluid |
| WO2008137181A1 (en) * | 2007-05-07 | 2008-11-13 | Clearly Superior, Inc | Food thickening agent, method for producing food thickening agent |
| EA018710B1 (en) * | 2007-11-30 | 2013-10-30 | Эм-Ай ЭлЭлСи | Emulsifier blend and method of performing a downhole operation |
| US8026198B2 (en) * | 2008-03-26 | 2011-09-27 | Shrieve Chemical Products, Inc. | Shale hydration inhibition agent(s) and method of use |
| US8936111B2 (en) | 2010-03-06 | 2015-01-20 | Halliburton Energy Services, Inc. | Invert drilling fluids having enhanced rheology and methods of drilling boreholes |
| DE102012003224A1 (en) * | 2012-02-20 | 2013-08-22 | Sasol Germany Gmbh | Drilling fluid, use and method using the drilling fluid |
| US9101156B2 (en) | 2013-03-15 | 2015-08-11 | Kent Precision Foods Group, Inc. | Thickener composition, thickened nutritive products, methods for preparing thickened nutritive products, and methods for providing nutrition |
| US10899955B2 (en) | 2014-12-31 | 2021-01-26 | Kemira Oyj | Emulsions, treatment fluids and methods for treating subterranean formations |
| US11751594B2 (en) | 2020-10-22 | 2023-09-12 | Grain Processing Corporation | Food thickener composition and method |
Family Cites Families (15)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US2423144A (en) * | 1944-10-07 | 1947-07-01 | Shell Dev | Emulsifiable hydrocarbon oils and emulsions thereof |
| US2555794A (en) * | 1948-10-18 | 1951-06-05 | Shell Dev | Well-drilling fluid |
| US2805991A (en) * | 1954-10-28 | 1957-09-10 | Gulf Oil Corp | Drilling muds |
| US2898294A (en) * | 1956-12-24 | 1959-08-04 | Jersey Prod Res Co | Well completion fluids |
| US3034984A (en) * | 1958-10-08 | 1962-05-15 | Texaco Inc | Drilling fluid |
| US3017351A (en) * | 1958-11-06 | 1962-01-16 | Pan American Petroleum Corp | Shale hydration inhibitors for clear water drilling fluids |
| US3198268A (en) * | 1963-07-02 | 1965-08-03 | Exxon Production Research Co | Method of reducing fluid loss in well treatment |
| US3310125A (en) * | 1963-08-29 | 1967-03-21 | Shell Oil Co | Method for increasing drilling rate |
| US3318396A (en) * | 1963-09-24 | 1967-05-09 | Gulf Oil Corp | Rotary drilling process |
| US3444090A (en) * | 1967-03-01 | 1969-05-13 | Grace W R & Co | Stabilizing filming amine emulsions |
| GB1256538A (en) * | 1968-02-02 | 1971-12-08 | ||
| US3601194A (en) * | 1969-07-14 | 1971-08-24 | Union Oil Co | Low fluid loss well-treating composition and method |
| US4000076A (en) * | 1974-06-14 | 1976-12-28 | Phillips Petroleum Company | Drilling mud having reduced corrosiveness |
| US4247402A (en) * | 1978-03-13 | 1981-01-27 | Brinadd Company | Clay-free, thixotropic wellbore fluid |
| US4230586A (en) * | 1978-08-07 | 1980-10-28 | The Lubrizol Corporation | Aqueous well-drilling fluids |
-
1986
- 1986-12-18 GB GB868630295A patent/GB8630295D0/en active Pending
-
1987
- 1987-11-25 EP EP87202338A patent/EP0271943A3/en not_active Withdrawn
- 1987-11-26 CA CA000552823A patent/CA1271320A/en not_active Expired - Fee Related
- 1987-12-11 US US07/132,081 patent/US4828724A/en not_active Expired - Fee Related
- 1987-12-16 AU AU82604/87A patent/AU596251B2/en not_active Ceased
- 1987-12-16 NO NO875261A patent/NO875261L/en unknown
- 1987-12-16 OA OA59245A patent/OA08786A/en unknown
- 1987-12-16 MY MYPI87003209A patent/MY103007A/en unknown
- 1987-12-16 NZ NZ222943A patent/NZ222943A/en unknown
- 1987-12-16 DK DK659587A patent/DK659587A/en not_active Application Discontinuation
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US7951755B2 (en) | 2002-12-02 | 2011-05-31 | An-Ming Wu | Emulsified polymer drilling fluid and methods of preparation |
| US8293686B2 (en) | 2002-12-02 | 2012-10-23 | Marquis Alliance Energy Group Inc. | Emulsified polymer drilling fluid and methods of preparation |
Also Published As
| Publication number | Publication date |
|---|---|
| EP0271943A2 (en) | 1988-06-22 |
| MY103007A (en) | 1993-03-31 |
| US4828724A (en) | 1989-05-09 |
| AU596251B2 (en) | 1990-04-26 |
| AU8260487A (en) | 1988-06-23 |
| OA08786A (en) | 1989-03-31 |
| EP0271943A3 (en) | 1989-10-11 |
| DK659587A (en) | 1988-06-19 |
| GB8630295D0 (en) | 1987-01-28 |
| NO875261D0 (en) | 1987-12-16 |
| NO875261L (en) | 1988-06-20 |
| DK659587D0 (en) | 1987-12-16 |
| NZ222943A (en) | 1990-08-28 |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CA1271320A (en) | Drilling fluid | |
| EP0973843B1 (en) | Well servicing fluid for trenchless directional drilling | |
| US6390208B1 (en) | Aphron-containing well drilling and servicing fluids | |
| Bloys et al. | Designing and managing drilling fluid | |
| US2890169A (en) | Drilling fluid for wells | |
| US9085725B2 (en) | Invert emulsion based completion and displacement fluid and method of use | |
| US4526693A (en) | Shale and salt stabilizing drilling fluid | |
| US5851960A (en) | Method of performing well drilling operations with a foamable drilling fluid | |
| US7833946B2 (en) | Water-based drilling fluid | |
| US8322419B2 (en) | Method of gravel packing a well containing synthetic or oil-based drilling fluids | |
| EP0764710A1 (en) | Silicone oil-based drilling fluids | |
| WO1992014798A1 (en) | Drilling fluid | |
| US6686323B2 (en) | Surfactant compositions for well cleaning | |
| US3724565A (en) | Method of controlling lost circulation | |
| EP0049484B1 (en) | A process for the production of a fluid loss reducing additive for an oil-based well working fluid | |
| US3123559A (en) | Hccjhio | |
| EP0255161A2 (en) | Drilling fluid | |
| WO1996024646A1 (en) | Drilling fluid | |
| WO1996024645A1 (en) | Drilling fluid | |
| WO2019136328A1 (en) | Invert emulsion gravel packing fluid for alternate path technology | |
| WO1999009109A1 (en) | Shale-stabilizing additives | |
| US20230167349A1 (en) | Wellbore Servicing Fluid and Methods of Making and Using Same | |
| GB2245294A (en) | Drilling fluid | |
| US3535237A (en) | Drilling fluid | |
| SOUTHARD | Driers and Metallic Soaps (see Paints and Varnishes) |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| MKLA | Lapsed |