METHODS OF PRODUCING PARTICLES HAVING TWO DIFFERENT PROPERTIES

A method of producing particles comprising: (A) providing a plurality of particle cores, wherein the cores have at least a first property; (B) partially or fully coating the outer surface of the cores with a substance, wherein the substance has a second property, and wherein the second property is different from the first property; and (C) reducing the particle size of the coated particles, wherein the core is exposed after the step of reducing. A method of using particles comprising: introducing a treatment fluid into an area to be treated, wherein the treatment fluid comprises: (i) a base fluid; and (ii) the particles. 1. A method of using particles comprising:introducing a treatment fluid into an area to be treated, wherein the treatment fluid comprises:(i) a base fluid; and (a) particle cores, wherein the cores have at least a first property;', '(b) a coating around the outer surface of the cores or a modified surface of the cores, wherein the coating or surface has a second property, and wherein the second property is different from the first property, wherein the cores are exposed via grinding of the particles after coating or modification., '(ii) a first type of particles, wherein the first type of particles comprise2. The method according to claim 1 , wherein the treatment fluid is a slurry claim 1 , an emulsion claim 1 , or an invert emulsion.3. The method according to claim 1 , wherein the base fluid is an aqueous liquid claim 1 , an aqueous miscible liquid claim 1 , or a hydrocarbon liquid.4. The method according to claim 3 , wherein the aqueous liquid is selected from the group consisting of fresh water; saltwater;brine; seawater; and any combination thereof.5. The method according to claim 3 , wherein the aqueous-miscible liquid is selected from the group consisting of alcohols; glycerins; glycols; polyglycol amines; polyols; any derivative thereof; any in combination with salts; any in combination with an aqueous-based fluid; and any combination ...

LUBRICANT FOR HIGH pH WATER BASED MUD SYSTEM

A method of drilling a wellbore in a subterranean formation employing a high pH aqueous mud or drilling fluid with a high pH lubricant. In one embodiment, the lubricant, which significantly improves the lubricity of the fluid in a high pH environment, comprises about 80 volume percent 2-octyldodecanol and about 20 volume percent alkylglucoside. In one embodiment, the alkylglucoside is comprised of 2-ethylhexylglucoside or a mixture of alkylglucosides having more than about 10 carbon atoms in the alkyl chain. The lubricant is effective at pH ranges from 7 to 14, preventing the lubricity of the aqueous drilling fluid from declining in relation to increasing pH. 1. (canceled)2. A method for drilling a wellbore in a subterranean formation wherein the method comprises providing or using an aqueous drilling fluid and a high pH lubricant to drill at least a portion of the wellbore , wherein said high pH lubricant comprises low solubility alcohol and alkyglucoside and wherein said alkyglucoside is 2-ethylhexylglucoside or a mixture of butyl and hexyl glucosides.3. The method of wherein said low solubility alcohol is selected from the group consisting of 2-octyldodecanol; polyetherglycols; oleyl alcohols; and stearyl alcohols claim 2 , and further comprises alkylglucoside selected from the group consisting of 2-ethylhexylglucoside claim 2 , butyl glucosides claim 2 , hexyl glucosides claim 2 , alkylglucosides having more than ten carbon atoms in the alkyl chain claim 2 , and mixtures thereof.4. The method of wherein said alcohol comprises about 40 to about 90 volume percent of said lubricant.5. The method of wherein said alkylglucoside comprises about 10 to about 60 volume percent of said lubricant.6. (canceled)7. (canceled)8. (canceled)9. The method of wherein said high pH lubricant comprises about 80 volume percent 2-octyldodecanol and about 20 volume percent 2-ethylhexylglucoside.10. The method of wherein said high pH lubricant comprises about 80 volume percent 2- ...

INVERT EMULSION DRILLING FLUID CONTAINING AN INTERNAL PHASE OF A POLYOL AND SALT-WATER SOLUTION

An invert emulsion drilling fluid comprising: an external phase, wherein the external phase comprises a hydrocarbon liquid; an internal phase, wherein the internal phase comprises: (i) a polyol; and (ii) a solution comprising a water-soluble salt and water. A method of using the invert emulsion drilling fluid comprises: introducing the drilling fluid into at least a portion of a subterranean formation. 1. A method of using an invert emulsion drilling fluid comprising:introducing the drilling fluid into at least a portion of a subterranean formation, wherein the drilling fluid comprises:(A) an external phase, wherein the external phase comprises a hydrocarbon liquid; (i) a polyol; and', '(ii) a solution comprising a water-soluble salt and water., '(B) an internal phase, wherein the internal phase comprises2. The method according to claim 1 , wherein the hydrocarbon liquid is selected from the group consisting of: a fractional distillate of crude oil; a fatty derivative of an acid claim 1 , an ester claim 1 , an ether claim 1 , an alcohol claim 1 , an amine claim 1 , an amide claim 1 , or an imide; a saturated hydrocarbon; an unsaturated hydrocarbon; a branched hydrocarbon; a cyclic hydrocarbon; and any combination thereof.3. The method according to claim 1 , wherein the polyol comprises a glycerol.4. The method according to claim 3 , wherein the glycerol is polyglycerol.5. The method according to claim 1 , wherein the polyol is in a concentration of about 50% to about 70% by volume of the internal phase.6. The method according to claim 1 , wherein the solution comprises more than one salt.7. The method according to claim 1 , wherein the salt comprises ions selected from the group consisting of Li claim 1 , Na claim 1 , K claim 1 , Rb claim 1 , Cs claim 1 , Mg claim 1 , Ca claim 1 , Fe claim 1 , Fe claim 1 , F claim 1 , Cl claim 1 ,CHCOO claim 1 , CHOO claim 1 , SO claim 1 , HCO claim 1 , POand combinations thereof.8. The method according to claim 7 , wherein the salt ...

Defoaming Agent Compositions and Methods of Making and Using Same

A method of servicing a wellbore in a subterranean formation comprising placing a foamed wellbore servicing fluid into a wellbore; flowing the foamed wellbore servicing fluid back to the wellbore surface; and contacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer. A system comprising a foamed wellbore servicing fluid in contact with a de-foaming structure, wherein the de-foaming structure comprises a defoamer covalently bonded to an inert substrate. 1. A method of servicing a wellbore in a subterranean formation comprising:placing a foamed wellbore servicing fluid into a wellbore;flowing the foamed wellbore servicing fluid back to the wellbore surface; andcontacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer.2. The method of wherein the inert substrate comprises an organic polymer claim 1 , an inorganic material claim 1 , or combinations thereof.3. The method of wherein the organic polymer comprises vinyl polymers claim 2 , olefin polymers claim 2 , fluoropolymers claim 2 , polyesters claim 2 , copolymers thereof claim 2 , or combinations thereof.4. The method of wherein the vinyl polymer comprises polystyrene claim 3 , polyvinylchloride claim 3 , cross-linked polyvinylacetate claim 3 , cross-linked polyacrylamide claim 3 , poly methacrylamide claim 3 , copolymers claim 3 , blends claim 3 , or combinations thereof.5. The method of wherein the olefin polymer comprises polyethylene claim 3 , polypropylene claim 3 , polybutylene claim 3 , polybutadiene claim 3 , polyisoprene claim 3 , copolymers claim 3 , blends claim 3 , or combinations thereof.6. The method of wherein the fluoropolymer comprises polyvinyl fluoride claim 3 , polytetrafluoroethylene claim 3 , fluorinated ethylene propylene copolymers claim 3 , perfluoroalkoxy polymer claim 3 , perfluoromethylalkoxy polymer claim 3 , ...

Defoaming Agent Compositions and Methods of Making and Using Same

A method of servicing a wellbore in a subterranean formation comprising placing a foamed wellbore servicing fluid into a wellbore; flowing the foamed wellbore servicing fluid back to the wellbore surface; and contacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer. A system comprising a foamed wellbore servicing fluid in contact with a de-foaming structure, wherein the de-foaming structure comprises a defoamer covalently bonded to an inert substrate. 1. A system comprising a first volume of a foamed wellbore servicing fluid in contact with a de-foaming structure , wherein the defoaming structure comprises a defoamer and an inert substrate.2. The system of claim 1 , wherein the immobilized defoaming structure comprises a porous structure claim 1 , a screen claim 1 , a flexible sponge claim 1 , or combinations thereof.3. The system of claim 1 , wherein the defoaming structure comprises a screen.4. The system of claim 1 , further comprising a fluid container claim 1 , wherein at least a portion of the fluid container comprises the defoaming structure.5. The system of claim 4 , wherein the fluid container comprises a median or baffle claim 4 , wherein at least a portion of the median or baffle comprises the defoaming structure.6. The system of claim 1 , further comprising a fluid conduit claim 1 , wherein at least a portion of the fluid conduit comprises the defoaming structure.7. The system of claim 6 , wherein the fluid conduit is a pipe.8. The system of claim 6 , wherein the fluid conduit is disposed within a wellbore.9. The system of claim 1 , further comprising a wellbore servicing equipment component.10. The system of claim 8 , wherein at least a portion of the wellbore servicing equipment component comprises the defoaming structure.11. The system of claim 1 , further comprising a second volume of the foamed wellbore servicing fluid disposed within a wellbore.12. The system of claim ...

WELLBORE SERVICING COMPOSITIONS AND METHODS OF MAKING AND USING SAME

A method of servicing a wellbore in a subterranean formation comprising preparing a wellbore servicing fluid comprising an alkoxylated humus material and an aqueous base fluid, wherein the alkoxylated humus material comprises an ethoxylated humus material and/or a C3+ alkoxylated humus material, and placing the wellbore servicing fluid in the wellbore and/or subterranean formation to modify the permeability of at least a portion of the wellbore and/or subterranean formation. A method of drilling a wellbore in a subterranean formation comprising preparing a drilling fluid comprising an alkoxylated humus material and an aqueous base fluid, wherein the alkoxylated humus material comprises an ethoxylated humus material and/or a C3+ alkoxylated humus material, and placing the drilling fluid in the wellbore and/or subterranean formation. 1. A method of servicing a wellbore in a subterranean formation comprising:preparing a wellbore servicing fluid comprising an alkoxylated humus material and an aqueous base fluid, wherein the alkoxylated humus material comprises an ethoxylated humus material and/or a C3+ alkoxylated humus material; andplacing the wellbore servicing fluid in the wellbore and/or subterranean formation to modify the permeability of at least a portion of the wellbore and/or subterranean formation.2. (canceled)3. The method of wherein the alkoxylated humus material is obtained by heating a humus material with an alkoxylating agent claim 1 , in the presence of a catalyst and an inert reaction solvent claim 1 , wherein the alkoxylating agent comprises ethylene oxide claim 1 , a C3+ cyclic ether claim 1 , or combinations thereof.7. The method of wherein the alkoxylating agent is present in a weight ratio of alkoxylating agent to humus material of from about 10:1 to about 40:1.8. The method of wherein the alkoxylating agent comprises ethylene oxide and C3+ cyclic ether in a weight ratio of ethylene oxide to C3+ cyclic ether in the range of from about 10:1 to about ...

BITUMEN IN WATER EMULSIONS AND METHODS OF MAKING SAME

A method of stabilizing a bitumen-in-water emulsion comprising contacting (i) bitumen, (ii) water, and (iii) an alkoxylated humus material to obtain a stabilized bitumen-in-water emulsion, wherein the alkoxylated humus material comprises an ethoxylated humus material, a C3+ alkoxylated humus material, or combinations thereof. A method of stabilizing a bitumen-in-water emulsion comprising contacting (i) bitumen, (ii) water, and (iii) an alkoxylated humus material to obtain a stabilized bitumen-in-water emulsion, wherein the alkoxylated humus material comprises an ethoxylated lignite, and the bitumen is extracted from the Orinoco Oil Belt in Venezuela. A stabilized bitumen-in-water emulsion comprising bitumen, water, and an alkoxylated humus material wherein the alkoxylated humus material comprises an ethoxylated humus material, a C3+ alkoxylated humus material, or combinations thereof. 1. A method of stabilizing a bitumen-in-water emulsion comprising:contacting (i) bitumen, (ii) water, and (iii) an alkoxylated humus material to obtain a stabilized bitumen-in-water emulsion, wherein the alkoxylated humus material comprises an ethoxylated humus material, a C3+ alkoxylated humus material, or combinations thereof.2. (canceled)3. (canceled)4. The method of wherein the bitumen comprises natural bitumen claim 1 , extra-heavy oils claim 1 , or combinations thereof.5. (canceled)6. The method of wherein the bitumen is present in the stabilized bitumen-in-water emulsion in an amount of from about 40 vol. % to about 85 vol. % based on the total volume of the stabilized bitumen-in-water emulsion.7. The method of wherein the water comprises fresh water.8. The method of wherein the water is present in the stabilized bitumen-in-water emulsion in an amount of from about 15 vol. % to about 60 vol. % based on the total volume of the stabilized bitumen-in-water emulsion.9. The method of wherein the alkoxylated humus material is obtained by heating a humus material with an alkoxylating ...

ALKOXYLATED HUMUS MATERIAL COMPOSITIONS AND METHODS OF MAKING SAME

A method of alkoxylating a humus material comprising heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent, and recovering a C3+ alkoxylated humus material from the reaction mixture. A method of alkoxylating a humus material comprising heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent to a temperature of from about 130° C. to about 170° C., wherein the humus material comprises leonardite, the C3+ cyclic ether comprises propylene oxide, and the inert reaction solvent comprises xylene, and recovering a C3+ alkoxylated humus material from the reaction mixture. A C3+ alkoxylated humus material. 1. A method of alkoxylating a humus material comprising:heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent; andrecovering a C3+ alkoxylated humus material from the reaction mixture.24-. (canceled)68-. (canceled)1112-. (canceled)13. The method of wherein the strong base catalyst comprises sodium methoxide claim 23 , potassium methoxide claim 23 , sodium ethoxide claim 23 , potassium ethoxide claim 23 , or combinations thereof.1415-. (canceled)16. The method of wherein the strong acid catalyst comprises (a) a mixture of HF and at least one of a metal alkoxide and a mixed metal alkoxide; or (b) a mixture of esters of at least one of titanic and zirconic acid with monoalkanols and at least one of sulfuric acid claim 23 , alkanesulfonic acids and aryloxysulfonic acids.18. The method of wherein the inert reaction solvent comprises C-Cliquid aromatic hydrocarbons.19. The method of wherein the C-Cliquid aromatic hydrocarbon is selected from the group consisting of toluene claim 18 , ethylbenzene claim 18 , xylenes claim 18 , o-xylene claim 18 , m-xylene claim 18 , p-xylene claim 18 , trimethylbenzenes claim 18 , cumene claim 18 , mesitylene claim 18 , 1 claim 18 ,2 claim 18 ,4-trimethylbenzene ...

Methods of producing particles having two different properties

A method of producing particles comprising: (A) providing a plurality of particle cores, wherein the cores have at least a first property; (B) partially or fully coating the outer surface of the cores with a substance, wherein the substance has a second property, and wherein the second property is different from the first property; and (C) reducing the particle size of the coated particles, wherein the core is exposed after the step of reducing. A method of using particles comprising: introducing a treatment fluid into an area to be treated, wherein the treatment fluid comprises: (i) a base fluid; and (ii) the particles.

Methods of producing particles having two different properties

A method of producing particles comprising: (A) providing a plurality of particle cores, wherein the cores have at least a first property; (B) partially or fully coating the outer surface of the cores with a substance, wherein the substance has a second property, and wherein the second property is different from the first property; and (C) reducing the particle size of the coated particles, wherein the core is exposed after the step of reducing. A method of using particles comprising: introducing a treatment fluid into an area to be treated, wherein the treatment fluid comprises: (i) a base fluid; and (ii) the particles.

Methods of producing particles having two different properties

A method of producing particles comprising: (A) providing a plurality of particle cores, wherein the cores have at least a first property; (B) partially or fully coating the outer surface of the cores with a substance, wherein the substance has a second property, and wherein the second property is different from the first property; and (C) reducing the particle size of the coated particles, wherein the core is exposed after the step of reducing. A method of using particles comprising: introducing a treatment fluid into an area to be treated, wherein the treatment fluid comprises: (i) a base fluid; and (ii) the particles.

Methods of producing particles having two different properties

An invert emulsion drilling fluid containing an internal phase of a polyol and salt-water solution

An invert emulsion drilling fluid comprising: an external phase, wherein the external phase comprises a hydrocarbon liquid; an internal phase, wherein the internal phase comprises: (i) a polyol; and (ii) a solution comprising a water-soluble salt and water. A method of using the invert emulsion drilling fluid comprises: introducing the drilling fluid into at least a portion of a subterranean formation.

Defoaming agent compositions and methods of making and using same

A method of servicing a wellbore in a subterranean formation comprising placing a foamed wellbore servicing fluid into a wellbore; flowing the foamed wellbore servicing fluid back to the wellbore surface; and contacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer. A system comprising a foamed wellbore servicing fluid in contact with a de-foaming structure, wherein the de-foaming structure comprises a defoamer covalently bonded to an inert substrate.

An invert emulsion drilling fluid containing an internal phase of a polyol and salt-water solution

An invert emulsion drilling fluid comprising: an external phase, wherein the external phase comprises a hydrocarbon liquid; an internal phase, wherein the internal phase comprises: (i) a polyol; and (ii) a solution comprising a water-soluble salt and water. A method of using the invert emulsion drilling fluid comprises: introducing the drilling fluid into at least a portion of a subterranean formation.

Inhibition of reservoir scale

INHIBITION OF RESERVOIR SCALE Abstract Scaling of a production well in a non-carbonate subterranean reservoir is inhibited by injecting into the reservoir a mixture of a phosphonate inhibitor and a metal chelate where the metal chelate has a lower stability constant (Ke) than the phosphonate inhibitor.

Methods of producing particles having two different properties

A method of producing particles comprising: (A) providing a plurality of particle cores, wherein the cores have at least a first property; (B) partially or fully coating the outer surface of the cores with a substance, wherein the substance has a second property, and wherein the second property is different from the first property; and (C) reducing the particle size of the coated particles, wherein the core is exposed after the step of reducing. A method of using particles comprising: introducing a treatment fluid into an area to be treated, wherein the treatment fluid comprises: (i) a base fluid; and (ii) the particles.

Alkoxylated humus material compositions and methods of making same

A method of alkoxylating a humus material comprising heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent, and recovering a C3+ alkoxylated humus material from the reaction mixture. A method of alkoxylating a humus material comprising heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent to a temperature of from about 130 °C to about 170 °C, wherein the humus material comprises leonardite, the C3+ cyclic ether comprises propylene oxide, and the inert reaction solvent comprises xylene, and recovering a C3+ alkoxylated humus material from the reaction mixture. A C3+ alkoxylated humus material.

Defoaming agent compositions and methods of making and using same

A method of servicing a wellbore in a subterranean formation comprising placing a foamed wellbore servicing fluid into a wellbore; flowing the foamed wellbore servicing fluid back to the wellbore surface; and contacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer. A system comprising a foamed wellbore servicing fluid in contact with a de-foaming structure, wherein the de-foaming structure comprises a defoamer covalently bonded to an inert substrate.

Bitumen in water emulsions and methods of making same

A method of stabilizing a bitumen-in-water emulsion comprising contacting (i) bitumen, (ii) water, and (iii) an alkoxylated humus material to obtain a stabilized bitumen-in-water emulsion, wherein the alkoxylated humus material comprises an ethoxylated humus material, a C3+ alkoxylated humus material, or combinations thereof. A method of stabilizing a bitumen-in-water emulsion comprising contacting (i) bitumen, (ii) water, and (iii) an alkoxylated humus material to obtain a stabilized bitumen-in-water emulsion, wherein the alkoxylated humus material comprises an ethoxylated lignite, and the bitumen is extracted from the Orinoco Oil Belt in Venezuela. A stabilized bitumen-in-water emulsion comprising bitumen, water, and an alkoxylated humus material wherein the alkoxylated humus material comprises an ethoxylated humus material, a C3+ alkoxylated humus material, or combinations thereof.

Novel compounds and method for generating a highly efficient membrane in water-based drilling fluids

A method is disclosed that affords improved stability to wellbores during drilling in argillaceous formations with water-based drilling fluids. The method comprises adding to the drilling fluid a compound of the invention having the capacity in water to generate a highly efficient membrane on argillaceous materials. The compound is soluble in the drilling fluid at least at the pH at which the compound is added to the drilling fluid or exists in the drilling fluid, but is insoluble in the water in the pores of the argillaceous formations, or at least at the pH of the water in such pores.

Lubricant for high PH water based mud system

A method of drilling a wellbore in a subterranean formation employing a high pH aqueous mud or drilling fluid with a high pH lubricant. In one embodiment, the lubricant, which significantly improves the lubricity of the fluid in a high pH environment, comprises about 80 volume percent 2-octyldodecanol and about 20 volume percent alkylglucoside. In one embodiment, the alkylglucoside is comprised of 2-ethylhexylglucoside or a mixture of alkylglucosides having more than about 10 carbon atoms in the alkyl chain. The lubricant is effective at pH ranges from 7 to 14, preventing the lubricity of the aqueous drilling fluid from declining in relation to increasing pH.

Method of sealing attenuated sand formations during well drilling

Alkoxylated humus material compositions and methods of making same

A method of alkoxylating a humus material comprising heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent, and recovering a C3+ alkoxylated humus material from the reaction mixture. A method of alkoxylating a humus material comprising heating a reaction mixture comprising a humus material, a C3+ cyclic ether, a catalyst and an inert reaction solvent to a temperature of from about 130 °C to about 170 °C, wherein the humus material comprises leonardite, the C3+ cyclic ether comprises propylene oxide, and the inert reaction solvent comprises xylene, and recovering a C3+ alkoxylated humus material from the reaction mixture. A C3+ alkoxylated humus material.

Immobilized defoaming system and method of servicing a subterranean formation with same

A method of servicing a wellbore in a subterranean formation comprising placing a foamed wellbore servicing fluid into a wellbore; flowing the foamed wellbore servicing fluid back to the wellbore surface; and contacting the foamed wellbore servicing fluid with an immobilized defoaming agent structure comprising an inert substrate and a defoamer. A system comprising a foamed wellbore servicing fluid in contact with a de-foaming structure, wherein the de-foaming structure comprises a defoamer covalently bonded to an inert substrate.

Spotting-flüssigkeit für differential-sticking

Procedure for sealing attenuated sand formations during well drilling

Anti-suds and methods for loosening a jammed rudder during a drilling operation

Surfactant-free emulsions and methods of use thereof

In one embodiment, the present invention provides a drilling fluid composition that comprises a surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and emulsion facilitating particles. In another embodiment, the present invention provides a method of treating a subterranean formation comprising providing a treatment fluid that comprises a surfactant-free emulsion, the surfactant-free emulsion comprising an oleaginous fluid, a fluid that is at least partially immiscible with the oleaginous fluid, and emulsion facilitating particles; and treating the subterranean formation.

Lubricants for drilling mud containing silicic acid

Lubricants for drilling mud containing silicic acid

Process for the preparation of polyolefin/acrylonitrile copolymers and polyolefin/acrylic acid or substituted acrylic acid/acrylonitrile terpolymers

Terpolymers of polyolefin/acrylic acid or substituted acrylic acid/acrylonitrile are prepared by combining a polyolefin/acrylic acid or substituted acrylic acid copolymer with at least one dinitrile to form a mixture and reacting the mixture at a temperature of at least 200 DEG C. for a time sufficient to form the terpolymer. Copolymers of polyolefin/acrylonitrile are obtained when the reaction is carried to completion. The total reaction masses obtained comprising terpolymer or copolymer, cyclic imide, solvent, when used, and any unreacted dinitrile find use as pour point depressants in heavy hydrocarbon oils.