JP2016536409A - Method of using bio-derived monoester as drilling fluid - Google Patents

Abstract

The present invention is directed to a drilling method for a drilling hole using a monoester drilling fluid composition. In some embodiments, such monoester lubricant manufacturing methods utilize biomass precursors and / or low Fischer-Tropsch (FT) olefins and / or alcohols, and high monoester drilling fluids To be obtained. In some embodiments, such monoester drilling fluids are derived from FT olefins and fatty acids. Fatty acids may be from bioresources (ie, biomass, renewable resources) or can be obtained from FT alcohol by oxidation.

Description

This application is a continuation-in-part of co-pending US patent application Ser. No. 13 / 682,542 filed Nov. 20, 2012.

  The present invention relates to monoester drilling fluid compositions, methods for their production, and methods for use in underground formations in oil and gas recovery operations, wherein they comprise at least one bio-derived precursor and / or Manufactured from Fischer-Tropsch product (s).

Drilling fluids that use synthetic fluids as base fluids (ie, monoester drilling fluids) can achieve 96 hour LC ₅₀ Mysid shrim (Mysipsis bahia) bioassay test results higher than 100,000 ppm. However, even the results of these bioassay tests are severely limited in their commercial use.

  Therefore, there is a need for a drilling fluid that uses an inexpensive, non-toxic synthetic fluid as the base fluid. The present invention comprises (a) at least one drilling fluid additive (eg, emulsifier, thickener, extender and oil wetting agent) and (b) an inexpensive, non-toxic base fluid comprising monoester (s) This requirement is met by providing a drilling fluid, including

It has already been reported that secondary esters containing C ₁ -C ₅ carboxylic acids and one or more C ₃ -C ₂₂ olefins can be used with invert drilling muds (US Pat. No. 6,100, 223 and 6,191,076). Further, related US patent application Ser. No. 13 / 682,542 (“Monoester-Based Lubricant and its Manufacturing Method (Monoester-Based)”, filed Nov. 20, 2012, which is incorporated herein in its entirety. Lubricants and Methods of Making Same) ”) provides a simpler and more effective method for producing monoesters.

  In such cases, the use of borehole drilling methods in subterranean formations using biodegradable, non-toxic monoester drilling fluids, especially when such methods are expensive from low Fischer-Tropsch (FT) olefins and alcohols. This is extremely useful and desirable when utilizing renewable raw materials in combination with the conversion of a monoester drilling fluid.

In this aspect, it was confirmed that the monoesters produced from the C ₆ -C ₄₁ carboxylic acids and C ₈ -C ₈₄ olefins of the present invention provide superior properties for use in drilling fluids. In particular, the monoesters of the present invention have lower viscosity and superior gel strength at higher temperatures and pressures than the esters currently on the market today.

In one embodiment, the present invention comprises: a) rotating a drill bit at the bottom of the drill hole; b) introducing a drill fluid into the drill hole to pick up the drill cut and from the drill hole to the drill cut. A method of drilling a subterranean borehole, wherein the drilling fluid is selected from the group consisting of: i) an emulsifier, a wetting agent, a thickener, a bulking agent, and a fluid loss control agent. At least one additive, and ii) Formula I:

(Wherein R ₁ and R ₂ are independently selected from C ₁ -C ₈ and R ₃ is C ₅ -C ₁₃ )
And a predetermined amount (a quantity of) of at least one monoester.

It is a flowchart which shows the manufacturing method of the monoester for making it contain in a monoester type drilling fluid composition. It is a figure which shows a common monoester. It is a figure which shows an octyl hexanoate monoester. It is a figure which shows a decyl hexanoate monoester.

  In certain embodiments, the present invention includes: a) rotating a drill bit at the bottom of the drilling hole; b) introducing a drilling fluid into the drilling hole to pick up the drill cut and drilling from the drill hole. A method of drilling a subterranean borehole, wherein the drilling fluid is selected from the group consisting of: i) an emulsifier, a wetting agent, a thickener, a bulking agent, and a fluid loss control agent. At least one additive, and ii) a predetermined amount of at least one monoester of formula I, wherein the steps are carried out continuously.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I is biodegradable and non-toxic.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole wherein the monoester of Formula I is derived from an isomerized olefin.

In some embodiments, the present invention is directed to a method for drilling a subterranean borehole, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₈ and R ₃ is C ₅ -C _12. To do.

In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₅ and R ₃ is C ₅ -C _8. To do.

In some embodiments, the present invention is directed to a method for excavating an underground borehole, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₃ and R ₃ is C ₅ -C _6. To do.

  In some embodiments, the invention provides a kinematic viscosity of the monoester of Formula I at a temperature of 100 ° C. between about 0.5 cSt and 2 cSt and a kinematic viscosity at a temperature of 40 ° C. of between about 2 cSt and 4 cSt. And a method for excavating a subterranean excavation hole in which a kinematic viscosity at a temperature of 0 ° C. is between about 4 cSt and 12 cSt.

  In some embodiments, the present invention is directed to a method of drilling an underground borehole, wherein the monoester of Formula I has Oxidator BN longer than 30 hours.

  In some embodiments, the present invention is directed to a method of drilling an underground borehole, wherein the monoester of Formula I has Oxidator BN longer than 50 hours.

  In some embodiments, the present invention is directed to a method of drilling an underground borehole, wherein the monoester of Formula I has Oxidator BN longer than 60 hours.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I has a pour point less than about −20 ° C.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I has a pour point less than about −60 ° C.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the drilling fluid has a pour point lower than about 10 ° C and a viscosity at 40 ° C between about 1 cSt and about 10 cSt. And

  In some embodiments, the present invention is directed to a method for drilling a subsurface borehole, wherein the drilling fluid has a 10 second gel strength between about 2 pounds / 100 square feet and about 15 pounds / 100 square feet. To do.

  In some embodiments, the present invention is directed to a method for drilling an underground drill hole, wherein the drilling fluid has a 10 second gel strength of about 2 pounds / 100 square feet at about 93.3 ° C. and about 1000 psig. .

  In some embodiments, the present invention is directed to a method for drilling an underground borehole wherein the drilling fluid has a 10 second gel strength of about 1 pound / 100 square feet at about 121.1 ° C. and about 15000 psig. .

  In some embodiments, the present invention is directed to a method for drilling an underground borehole where the drilling fluid results in a rheological profile in Fann 77 as shown in Table 2A.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole where the drilling fluid provides a rheological profile in Fann 77 as shown in Table 2B.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the drilling fluid has a 10 minute gel strength between about 1 pound / 100 square feet and about 17 pounds / 100 square feet. To do.

In some embodiments, the present invention is directed to a method for drilling a subsurface borehole, wherein R ₃ is C ₅ .

In some embodiments, the present invention is directed to a method for excavating a subterranean borehole, wherein R ₃ is C ₅ and R ₁ and R ₂ are C ₂ .

In some embodiments, the present invention is directed to a method for drilling a subterranean borehole, wherein R ₃ is C ₅ and R ₁ and R ₂ are C ₃ .

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the at least one monoester of Formula I is octylhexanoate, its isomers, and mixtures thereof.

  In some embodiments, the present invention is directed to a method of drilling an underground borehole, wherein the at least one monoester of Formula I is decylhexanoate, its isomers, and mixtures thereof.

  In some embodiments, the present invention relates to subsurface drilling, wherein the at least one monoester of Formula I is octylhexanoate, a mixture of its isomers, decylhexanoate, its isomers and mixtures thereof Targets drilling methods.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the drilling fluid of step (b) comprises between about 20 wt% and 40 wt% of a monoester of Formula I. .

In some embodiments, the present invention provides that the drilling fluid of step (b)
a. Between about 1.0% and about 3.0% by weight of emulsifiers and wetting agents;
b. Between about 0.1% and about 1.5% by weight of organophilic clay;
c. Between about 5 wt% and about 12 wt% water;
d. Between about 1.0 wt% and about 4.0 wt% salt;
e. Between about 0.1 wt% and about 1.0 wt% latex filtration control agent;
f. Between about 40% and about 60% by weight of a bulking agent; and
g. The present invention is directed to a method for drilling an underground borehole that further includes between about 3.0 wt% and about 9.0 wt% of simulated drilling solids.

  In some embodiments, the invention provides that the drilling fluid comprises hexanyl hexanoate and isomer, hexanyl octanoate and isomer, hexanyl decanoate and isomer, hexanyl laurate and isomer, Hexanyl palmitate and isomer, Hexanyl hexadecanoate and isomer, Hexanyl stearate and isomer, Octanyl hexanoate and isomer, Octanyl octanoate and isomer, Octanyl decanoate and Isomer, octanyl laurate and isomer, octanyl palmitate and isomer, octanyl hexadecanoate and isomer, octanyl stearate and isomer, decanyl hexanoate and isomer, decanyl octano Art and isomers, decanyl decanoate and isomers, decanyl lauric art Isomer, decanyl palmitate and isomer, decanyl hexadecanoate and isomer, decanyl stearate and isomer, dodecanyl hexanoate and isomer, dodecanyl octanoate and isomer, dodecanyl Decanoate and isomer, dodecanyl laurate and isomer, dodecanyl palmitate and isomer, dodecanyl hexadecanoate and isomer, dodecanyl stearate and isomer, tetradecanyl hexanoate and isomer Tetradecanyl octanoate and isomer, tetradecanyl decanoate and isomer, tetradecanyl laurate and isomer, tetradecanyl palmitate and isomer, tetradecanyl hexadecanoate and isomer, Tetradecanyl stearate and isomers, hexadecanyl hexanoate Isomers, hexadecanyl octanoate and isomers, hexadecanyl decanoate and isomers, hexadecanyl laurate and isomers, hexadecanyl palmitate and isomers, hexadecanyl hexadecanoate and isomers Isomers, hexadecanyl stearate and isomers, octadecanyl hexanoate and isomers, octadecanyl octanoate and isomers, octadecanyl decanoate and isomers, octadecanyl laurate and isomers Octadecanyl palmitate and isomer, octadecanyl hexadecanoate and isomer, octadecanyl stearate and isomer, icosanyl hexanoate and isomer, icosanyl octanoate and isomer, Icosanyl decanoate and isomer, icosanyl laurate and isomer, ico Sanyl palmitate and isomer, icosanyl hexadecanoate and isomer, icosanyl stearate and isomer, docosanyl hexanoate and isomer, docosanyl octanoate and isomer, docosanyl decanoate And isomer, docosanyl lauriate and isomer, docosanyl palmitate and isomer, docosanyl hexadecanoate and isomer, docosanyl stearate and isomer, and mixtures thereof The drilling method for underground drilling holes including esters is targeted.

  In some embodiments, the present invention provides an aqueous solution wherein the drilling fluid comprises the components: (a) lime, (b) fluid loss control agent, (c) water and shale inhibiting salt, (d) The present invention is directed to a method for drilling an underground borehole that further includes an oil wetting agent, (e) a non-sulfonated polymer, (f) a sulfonated polymer, and (g) a non-organophilic clay.

  In some embodiments, the invention provides that the at least one monoester of Formula I is at least about 144a. m. u up to about 592a. m. The drilling method of the underground drill hole having a molecular weight of u is targeted.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I is derived from an internal olefin.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I is derived from a secondary alcohol.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I is a secondary monoester.

In some embodiments, the present invention is directed to a method for drilling a subterranean borehole, wherein the —O (CO) R ₃ group of formula I is not attached to the end of R ₁ or R ₂ .

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I does not include products derived from oligomerization.

  In some embodiments, the present invention is directed to a method for drilling an underground borehole, wherein the monoester of Formula I does not include products derived from alpha olefins.

In one embodiment, the present invention provides compounds of formula I:

(Wherein R ₁ and R ₂ are independently selected from C ₁ -C ₈ and R ₃ is C ₅ -C ₁₃ )
Of a drilling fluid composition comprising a predetermined amount of at least one monoester.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I is biodegradable and non-toxic.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein the monoester of Formula I is derived from an isomerized olefin.

In some embodiments, the invention includes a predetermined amount of at least one monoester of Formula I, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₈ and R ₃ is C ₅ -C _The drilling fluid composition is ₁₂ .

In some embodiments, the present invention comprises a predetermined amount of at least one monoester of Formula I, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₅ and R ₃ is C ₅ -C ₈ for drilling fluid compositions.

In some embodiments, the invention includes a predetermined amount of at least one monoester of Formula I, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₃ , and R ₃ is C ₅ -C ₆ for drilling fluid compositions.

  In some embodiments, the invention includes a predetermined amount of at least one monoester of Formula I, wherein the kinematic viscosity of the monoester of Formula I at a temperature of 100 ° C. is between about 0.5 cSt and 2 cSt; The drilling fluid composition is directed to a kinematic viscosity at a temperature of 40 ° C. between about 2 cSt and 4 cSt and a kinematic viscosity at a temperature of 0 ° C. between about 4 cSt to 12 cSt.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein the monoester of Formula I has an Oxidator BN longer than 30 hours.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I has an Oxidator BN longer than 50 hours.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein the monoester of Formula I has an Oxidator BN longer than 60 hours.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I has a pour point lower than about −20 ° C. To do.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I has a pour point lower than about −60 ° C. To do.

  In some embodiments, the invention comprises a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid has a pour point lower than about 10 ° C. and a temperature of 40 ° C. between about 1 cSt and about 10 cSt. A drilling fluid composition having a viscosity of

  In some embodiments, the present invention includes a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid is between about 2 pounds / 100 square feet and about 15 pounds / 100 square feet of 10 second gel. It is intended for drilling fluid compositions having strength.

  In some embodiments, the present invention comprises a predetermined amount of at least one monoester of Formula I, and the drilling fluid has a 10 second gel strength of about 2 pounds / 100 square feet at about 93.3 ° C. and about 1000 psig. A drilling fluid composition having

  In some embodiments, the present invention comprises a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid is about 1 lb / 100 sq. Ft. 10 second gel strength at about 121.1 ° C. and about 15000 psig. A drilling fluid composition having

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid provides a rheological property profile in Fann 77 as shown in Table 2A. To do.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid provides a rheological property profile in Fann 77 as shown in Table 2B. To do.

  In some embodiments, the present invention comprises a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid is a 10 minute gel between about 1 pound / 100 square feet and about 17 pounds / 100 square feet. It is intended for drilling fluid compositions having strength.

In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein R ₃ is C ₅ .

In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein R ₃ is C ₅ and R ₁ and R ₂ are C _2. And

In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of Formula I, wherein R ₃ is C ₅ and R ₁ and R ₂ are C _3. And

  In some embodiments, the invention includes a predetermined amount of at least one monoester of Formula I, wherein the at least one monoester of Formula I is octylhexanoate, its isomers, and mixtures thereof. Intended for drilling fluid compositions.

  In some embodiments, the invention comprises a predetermined amount of at least one monoester of formula I, wherein the at least one monoester of formula I is decylhexanoate, its isomers, and mixtures thereof. Intended for drilling fluid compositions.

  In some embodiments, the invention includes a predetermined amount of at least one monoester of Formula I, wherein the at least one monoester of Formula I is octylhexanoate, a mixture of its isomers, decylhexanoate. , Its isomers, and mixtures thereof.

  In some embodiments, the present invention comprises a predetermined amount of at least one monoester of formula I, wherein the drilling fluid of step (b) is between about 20 wt% and 40 wt% of the monoester of formula I A drilling fluid composition comprising

In some embodiments, the present invention comprises a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid is
a. Between about 1.0% and about 3.0% by weight of emulsifiers and wetting agents;
b. Between about 0.1% and about 1.5% by weight of organophilic clay;
c. Between about 5 wt% and about 12 wt% water;
d. Between about 1.0 wt% and about 4.0 wt% salt;
e. Between about 0.1 wt% and about 1.0 wt% latex filtration control agent;
f. Between about 40% and about 60% by weight of a bulking agent; and
g. Simulated drill solids between about 3.0 wt% and about 9.0 wt%
The drilling fluid composition further comprising:

  In some embodiments, the invention includes a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid is hexanyl hexanoate and isomer, hexanyl octanoate and isomer, hexanyldeca Noate and isomer, hexanyl laurate and isomer, hexanyl palmitate and isomer, hexanyl hexadecanoate and isomer, hexanyl stearate and isomer, octanyl hexanoate and isomer, octane Nyloctanoate and isomers, Octanyldecanoate and isomers, Octanyllaurate and isomers, Octanyl palmitate and isomers, Octanylhexadecanoate and isomers, Octanyl stearate and isomers Decanyl hexanoate and isomer, decanyl octanoate and isomer, Nildecanoate and isomer, decanyllaurate and isomer, decanylpalmitate and isomer, decanylhexadecanoate and isomer, decanyl stearate and isomer, dodecanylhexanoate and isomer, dodecanyl Octanoate and isomer, dodecanyl decanoate and isomer, dodecanyl laurate and isomer, dodecanyl palmitate and isomer, dodecanyl hexadecanoate and isomer, dodecanyl stearate and isomer, Tetradecanyl hexanoate and isomer, tetradecanyl octanoate and isomer, tetradecanyl decanoate and isomer, tetradecanyl laurate and isomer, tetradecanyl palmitate and isomer, tetradecane Nylhexadecanoate and isomers, tetradecanyls Alert and isomer, hexadecanyl hexanoate and isomer, hexadecanyl octanoate and isomer, hexadecanyl decanoate and isomer, hexadecanyl laurate and isomer, hexadecanyl palmitate and Isomers, hexadecanyl hexadecanoate and isomers, hexadecanyl stearate and isomers, octadecanyl hexanoate and isomers, octadecanyl octanoate and isomers, octadecanyl decanoate and isomers Isomers, octadecanyl laurate and isomers, octadecanyl palmitate and isomers, octadecanyl hexadecanoate and isomers, octadecanyl stearate and isomers, icosanyl hexanoate and isomers , Icosanyl octanoate and isomers, icosanyl decanoate And isomers, icosanyl laurate and isomer, icosanyl palmitate and isomer, icosanyl hexadecanoate and isomer, icosanyl stearate and isomer, docosanyl hexanoate and isomer, Docosanyl octanoate and isomer, docosanyl decanoate and isomer, docosanyl laurate and isomer, docosanyl palmitate and isomer, docosanyl hexadecanoate and isomer, docosanyl stearate and isomer The subject is a drilling fluid composition comprising a monoester selected from the group consisting of a body, and mixtures thereof.

  In some embodiments, the present invention comprises a predetermined amount of at least one monoester of Formula I, wherein the drilling fluid comprises the components: (a) lime, (b) fluid loss control agent, (c) water and shale. Drilling fluid composition further comprising an aqueous solution comprising a inhibiting salt, (d) an oil wetting agent, (e) a non-sulfonated polymer, (f) a sulfonated polymer, and (g) a non-organophilic clay. Is targeted.

  In some embodiments, the invention comprises an amount of at least one monoester of formula I wherein at least one monoester of formula I is at least about 144a. m. u up to about 592a. m. Targeted is a drilling fluid composition having a molecular weight of u.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I is derived from an internal olefin.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I is derived from a secondary alcohol. .

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I is a secondary monoester.

In some embodiments, the invention comprises a quantity of at least one monoester of formula I, wherein the —O (CO) R ₃ group of formula I is not attached to the end of R ₁ or R ₂ , Intended for drilling fluid compositions.

  In some embodiments, the present invention is directed to a drilling fluid composition comprising a predetermined amount of at least one monoester of formula I, wherein the monoester of formula I does not comprise the product resulting from oligomerization. .

  In some embodiments, the present invention is directed to a drilling fluid composition that includes a predetermined amount of at least one monoester of Formula I, wherein the monoester of Formula I does not include products derived from alpha olefins. .

I. Monoester Drilling Fluid Composition The monoester drilling fluid of the present invention has the formula I:

(Wherein R ₁ and R ₂ are independently selected from C _{1 to} C ₄₀ and R ₃ is C _{5 to} C ₄₀ )
Of a predetermined amount of at least one monoester.

  Surfactants (eg, emulsifiers, wetting agents), thickeners, extenders, fluid loss control agents, and shale suppression salts are also optionally used in the drilling fluid of the present invention. Since the drilling fluid of the present invention is intended to be non-toxic, these optional components are preferably non-toxic, as are the monoesters. Typical emulsifiers include, but are not limited to, fatty acids, fatty acid soaps, and fatty acid derivatives such as amide-amines, polyamides, polyamines, esters (eg, sorbitan monooleate polyethoxylate, sorbitan dioleate poly Ethoxylate), imidazolines, and alcohol.

  Typical wetting agents include, but are not limited to, lecithin, fatty acids, crude tall oil, oxidized crude tall oil, organophosphates, modified imidazolines, modified amidoamines, alkyl aromatic sulfates, alkyl aromatic sulfonic acids. And salts and organic esters of polyhydric alcohols.

  Typical weighting agents include, but are not limited to, barite, iron oxide, gelana, siderite, and calcium carbonate.

  Common shale deterrent salts are alkali metal salts and alkaline earth metal salts. Calcium chloride and sodium chloride are preferred shale inhibiting salts.

  Typical thickeners include, but are not limited to, organophilic clays (eg, hectorite, bentonite and attapulgite), non-organic clays (eg, montmorillonite (bentonite), hectorite, saponite, attapulgite and Illite), oil-soluble polymers, polyamide resins, and polycarboxylic acids and soaps.

  Examples of fluid loss control agents include, but are not limited to, asphalt (eg, asphaltenes and sulfonated asphaltenes), amine-treated lignite, and gilsonite. For drilling fluids for use in high temperature environments (eg, where the bottom temperature is greater than about 204.4 ° C. (400 ° F.)), the fluid loss control agent is preferably a polymeric fluid loss control agent. Typical polymer fluid loss control agents include, but are not limited to, polystyrene, polybutadiene, polyethylene, polypropylene, polybutylene, polyisoprene, natural rubber, butyl rubber and styrene, butadiene, isoprene, and vinyl carboxylic acid. Examples thereof include polymers composed of at least two monomers selected from the group. A single or mixture of polymeric fluid loss control agents may be used in the drilling fluid of the present invention.

  Optionally, one or more pour point depressants are used in the synthetic fluids of the present invention (ie, monoester drilling fluids) to lower their pour points. Typical pour point depressants include, but are not limited to, ethylene copolymers, isobutylene polymers, polyalkylnaphthalenes, wax aromatic condensation products (eg, wax-naphthalene condensation products, phenol-wax condensation products). Products), polyalkylphenol esters, polyalkyl methacrylates, polymethacrylates, polyalkylated condensed aromatics, alkyl aromatic polymers, iminodiimides, and polyalkylstyrenes (polyalkylnaphthalenes, polyalkylphenol esters and polyalkyls). The molecular weight for methacrylate ranges from about 2,000 to about 10,000). Ethylene copolymers and isobutylene polymers are preferred pour point depressants because they are non-toxic.

  No more than about 1 weight percent pour point depressant is used (as used in the specification and claims, the weight percent of pour point depressant is based on the weight of the monoester, i.e. it is The weight of the pour point depressant divided by the weight of the product, multiplied by 100% of the quotient). Preferably, the pour point depressant is used at a concentration of 0.005 to about 0.5, more preferably about 0.01 to about 0.4, and most preferably about 0.02 to about 0.3 weight percent. . If used, the pour point depressant is preferably mixed with the monoester, and the resulting composition is then combined with any additional additives described herein.

  The characteristics of the drilling fluid of the present invention (eg, the ratio of monoester to water, density, etc.) can be adjusted for any drilling operation. For example, drilling fluids typically have a monoester to water volume ratio of about 100: 0 to about 40:60 and a density of about 0.9 kg / l (7.5 pounds per gallon (ppg)) to Formulated to have about 2.4 kg / l (20 ppg). More generally, the density of the drilling fluid is from about 1.1 kg / l (9 ppg) to about 2.3 kg / l (19 ppg).

  The drilling fluid is preferably produced by mixing the components in the following order: (a) monoester, (b) emulsifier, (c) lime (if used), (d) fluid loss control agent (If used), (e) aqueous solution containing water and shale-inhibiting salt, (f) organophilic clay, (g) oil wetting agent, (h) extender, (i) non-sulfonated polymer (if used) ), (J) sulfonated polymer (if used), and (k) non-organophilic clay (if used).

II. Monoester Production Method As described above, the present invention is further directed to a method for producing the lubricant composition.

  The olefins disclosed herein may be alpha olefins produced by gas liquid fueling (GTL), refining processes, petrochemical processes, pyrolysis of plastic waste, and other processes, which are internal olefins. To the monoester. Alpha olefins are isomerized to internal olefins using double bond isomerization catalysts, including molecular sieves such as SAPO-39, and mesoporous zeolites such as SSZ-32 and ZSM-23.

Referring to the flow chart shown in FIG. 1, in some embodiments, the process for producing the above monoester species, typically having a lubricating base oil viscosity and pour point, comprises (Step 101) of C ₆ -C ₈₄ . Epoxidizing an internal olefin having a carbon number (or a predetermined amount of a plurality of olefin groups) to form an epoxide or a mixture of a plurality of epoxides; (step 102) opening the epoxide ring by a reduction method (Step 103) esterifying the secondary alcohol with a C ₆ -C ₄₁ carboxylic acid (ie, subjecting to esterification) to form an internal monoester species. including. In general, lubricant compositions comprising such monoester species have a viscosity in the range of 0.5 centistokes to 2 centistokes at a temperature of 100 ° C.

  In some embodiments, when a predetermined amount of such monoester species is formed, that amount of monoester species may be substantially homogeneous, or a mixture of two or more different such monoester species. It may be.

  In some of the above process embodiments, the olefin used is a Fischer-Tropsch reaction product. In these or other embodiments, the carboxylic acid may be derived from an alcohol produced by a Fischer-Tropsch process and / or may be a bio-derived fatty acid.

  In some embodiments, the olefin is an α-olefin (ie, an olefin having a double bond at the chain end). In these embodiments, it is usually necessary to isomerize the olefin to incorporate double bonds therein. Such isomerization is typically carried out catalyzed using, but not limited to, crystalline aluminosilicates and similar materials and catalysts such as aluminophosphates (eg, US Pat. No. 2,537,283; No. 3,211,801; No. 3,270,085; No. 3,327,014; No. 3,304,343; No. 3,448,164; 593,146; 3,723,564 and 6,281,404). Of these, the last patent claim describes a crystalline aluminophosphate-based catalyst having a one-dimensional pore size of between 3.8 and 5 inches.

  As in this example of isomerization, and as shown in Scheme 1 (FIG. 3), Fischer-Tropsch alpha olefins (α-olefins) can be isomerized to the corresponding internal olefin followed by epoxidation. it can. The epoxide can then be converted to the corresponding secondary monoalcohol by reduction of the epoxide ring, followed by esterification (ie, diesterification) with a suitable carboxylic acid or acylated derivative thereof. Since alpha olefins, especially monoesters of short chain alpha olefins, tend to be solids or waxes, conversion of alpha olefins to internal olefins is typically required. The “internalization” of the alpha olefin and subsequent conversion to the monoester functional group introduces branches along the chain in the resulting ester, resulting in lower molecular symmetry and thereby the desired product. The pour point becomes lower. In addition, the internalization of the ester can also enhance the oxidation stability and hydrolysis stability. Inner esters exhibit surprising hydrolytic and oxidative stability that is far superior to terminal esters. The steric hindrance becomes greater due to the internalization of the ester, which can contribute to oxidative stability and hydrolytic stability.

  These polar ester groups can further increase the viscosity of the final product. Branches introduced by internalizing ester groups improve low temperature properties such as pour point and cloud point. Viscosity can be increased by increasing the number of carbons in the internal olefin or the acid used in esterification.

With respect to the epoxidation step (ie, the epoxidation step), in some embodiments, the olefin (preferably an internal olefin) is reacted with a peroxide (eg, H ₂ O ₂ ) or a peroxy acid (eg, peroxyacetic acid). To produce an epoxide. (For example, D. Swern, in Organic Peroxides II, Wiley-Interscience, New York, 1971, pages 355-533; , New York 1978, pages 221-253.) Olefins are highly selective reagents such as osmium tetroxide (see M. Schroder, Chem. Rev. 80, 187, 1980) and permanganese. Potassium acid (Sheldon and Kochi, in Metal-Catalyzed Oxidation of Organic Compounds, 1 2-171 pages and pages 294~296, Academic Press, New York, by 1981 reference) can be efficiently converted to the corresponding diol.

  With respect to the step of epoxide ring opening to the corresponding secondary monoalcohol, this step is performed by reducing the epoxide ring using a metal hydride reduction procedure or a noble metal catalyzed hydrogenation process. Both procedures are very effective for the production of secondary alcohols required for internal epoxides.

Regarding the esterification step (esterification), an acid is typically used to catalyze the esterification reaction of an alcohol and a carboxylic acid. Acids suitable for esterification include, but are not limited to, sulfuric acid (see Munch-Peterson, Org. Synth., Vol. V, page 762, 1973), sulfonic acids (among others), among others. Org Synth., III, 203, 1955), hydrochloric acid (see Eliel et al., Org Synth., IV, 169, 1963), and phosphoric acid. In some embodiments, the carboxylic acid used in this step is first converted to acyl chloride (eg, using thionyl chloride or PCl ₃ ). Alternatively, acyl chloride can be used directly. When acyl chloride is used, no acid catalyst is required and typically is reacted with HCl formed by the addition of a base such as pyridine, 4-dimethylaminopyridine (DMAP) or triethylamine (TEA). . When pyridine or DMAP are used, these amines are believed to also act as catalysts by forming more reactive acylated intermediates. (See, eg, Fersh et al., J. Am. Chem. Soc., 92, 5432-5442, 1970; and Hofle et al., Angew. Chem. Int. Ed. Engl., 17, 567, 1978.) I want to)

  Regardless of the source of the olefin, in some embodiments, the carboxylic acid used in the method is derived from biomass. In some such embodiments, this includes the extraction of some oil (eg, triglyceride) components from biomass and the formation of free carboxylic acids by hydrolysis of the triglycerides that contain the oil components. .

  When using synthetic procedures according to those outlined in Scheme 1, Scheme 2 and Scheme 3, the internal octene mixture is converted to the internal monoester derivative by acylating the octyl alcohol intermediate with hexanoyl chloride and decanoyl chloride, respectively. Converted to the corresponding mixture of octylhexanoate and octyldecanoate. This method is described in more detail in the examples below. Octylhexanoate and decylhexanoate are particularly suitable for use in drilling fluid compositions.

Definitions and Terms The following terms are used throughout the specification and have the following meanings unless otherwise indicated.

  The term “Drilling Fluid” refers to a number of liquid and gaseous liquids and mixtures of liquids and solids (liquid, gas and solid solid suspensions) used in the operation of drilling a borehole in the soil. Mean as a suspension, mixture and emulsion). While it is preferred to define the term “drilling fluid” for “muds” (“muds”), some of which are more fully defined and well defined, “drilling mud” in general usage: Synonymous with drilling mud).

  The term “Rheology” means the investigation of material deformation and flow. Drilling fluid rheological measurements include plastic viscosity (PV), yield point (YP) and gel strength. Information obtained from these measurements can be used to determine hole cleaning efficiency, system pressure loss, equivalent circulation density, surge and swab pressure, and bit hydraulic pressure.

  The term “fluid loss control agent” includes, but is not limited to, asphalt (eg, asphaltenes and sulfonated asphaltenes), amine-treated lignite, and gilsonite. For drilling fluids for use in high temperature environments (eg, where the bottom temperature is greater than about 204.4 ° C. (400 ° F.)), the fluid loss control agent is preferably a polymeric fluid loss control agent. is there. Typical polymer fluid loss control agents include, but are not limited to, polystyrene, polybutadiene, polyethylene, polypropylene, polybutylene, polyisoprene, natural rubber, butyl rubber, and the group consisting of styrene, butadiene, isoprene and vinyl carboxylic acid. And a polymer comprising at least two monomers selected from: A single or mixture of polymeric fluid loss control agents can be used in the drilling fluid of the present invention.

  The term “organophilic clay” or “thickener” means CARBO-GEL® II (Baker-Hughes), organophilic bentonite, hectorite, attapulgite and sepiolite. Bentonite and hectorite are platelet clays that increase viscosity, yield point and build a thin filter cake to help reduce fluid loss. Many polymers are available for use in non-aqueous fluids. These polymers increase fluid carrying capacity and can also function as fluid loss control additives. These include: elastomer thickeners, sulfonated polystyrene polymers, styrene acrylates, fatty acids and dimer-trimer acid combinations.

  The term “emulsifier and wetting agent” means a primary emulsifier which is generally a very strong fatty acid surfactant. These are usually activated and require lime to build a stable emulsion. Secondary emulsifiers, often referred to as wetting agents, are typically based on imidazolines or amides (eg OMNI-MUL®, Baker-Hughes), but lime is not required for activation. They are made to be oil wet solids and also emulsify the oil. In order to incorporate stable water in the oil mixture, it is necessary to use a surfactant. Surfactants lower the surface tension and emulsify the internal aqueous phase and “oil wet” solids. Indeed, emulsifiers are classified as “primary” or “secondary” depending on the desired application.

The term “salt” means CaCl ₂ used to produce a drilling fluid or brine having a moderate density. CaCl ₂ can be mixed with other brines, such as NaCl, CaBR ₂ and ZnBR ₂ . The emulsification of CaCl ₂ brine as the internal phase of synthetic mud is a major application. This is because the brine provides well penetration stability while drilling the water-reactive shale region.

  The term “bulking agent” means barite (barium sulfate) (eg, MICROMAX ™) used to increase the density of drilling fluid. Other bulking agents are hematite (iron oxide), manganese tetroxide and calcium carbonate. These bulking materials increase the density of the external phase of the fluid.

  The term “latex filtration control agent” means a Pliolite® (Goodyear) polymer.

  The term “simulated drilling solid” means a powdered clay used to simulate drilling formed particles.

  The term “non-organophilic clay” means a clay that has not been amine-treated to convert from aqueous to oily.

  The term “muddy water weight” or “density” refers to the characteristics of a muddy fluid to balance and adjust the formation pressure of the ground excavation hole and promote well stability. Mud density is usually reported in pounds per gallon (pounds / calon). Since most drilling fluids contain at least a small amount of air / gas, the most accurate method for measuring density involves a pressurized mud balance.

The term “lime” means quicklime (CaO), quicklime precursor and hydrated quicklime (eg, slaked lime (Ca (OH) ₂ )).

  The term “surfactant” refers to the property of adsorbing on the surface or interface of a system and the property of significantly changing the surface free energy or interface free energy of these surfaces (or interfaces) when present at low concentrations in the system It means the substance that you have. As used in the foregoing definition of surfactant, the term “interface” refers to the boundary between any two immiscible phases and the term “surface” refers to the boundary where one phase is a gas (usually air). Represents a surface.

  The term “lubricant” means a substance (usually a liquid under operating conditions) that is introduced between two moving surfaces to reduce wear between them. Base oils used as motor oils are generally classified by the American Petroleum Institute as mineral oils (Groups I, II and III) or synthetic oils (Groups IV and V). See American Petroleum Institute (API) Publication No. 1509.

  The term “pour point” means the lowest temperature at which a fluid flows or flows (see, eg, ASTM International Standard Test Methods D 5950-96, D 6892-03, and D 97). ). Results are reported in degrees Celsius. Many commercial base oils have a pour point specification. If the base oil has a low pour point, the base oil is also considered to have other good low temperature properties, such as low cloud point, low cooling filter clogging point, and low temperature cranking viscosity.

  The term “cloud point” means the temperature at which a liquid begins to phase separate due to crystal formation. See, for example, ASTM standard test methods D 5773-95, D 2500, D 5551, and D 5771.

“Centistoke”, abbreviation “cSt”, is a unit related to the kinematic viscosity of a fluid (eg, a lubricant), where 1 centistoke is equal to 1 square millimeter per ^second (1 cSt = 1 mm ² / s). . See, for example, ASTM Standard Guide and Test Methods D 2270-04, D 445-06, D 6074, and D 2983.

With respect to the description of molecules and / or molecular fragments herein, “R _n ” ( _where “n” is a subscript) means a hydrocarbon group, where the molecule and / or molecular fragment is: It may be straight and / or branched.

The term “C _n ” ( _where “n” is an integer) refers to a hydrocarbon molecule or fragment (eg, an alkyl group), where “n” is the number of carbon atoms in the fragment or molecule. Represents a number.

  The prefix “bio” means an association with a biogenic renewable resource, eg, a resource that generally excludes fossil fuels.

  The term “internal olefin” means an olefin (ie, alkene) having a non-terminal carbon-carbon double bond (C═C). This is in contrast to “α-olefins” having terminal carbon-carbon double bonds.

  The term “Group I base oil” uses the ASTM method as defined in Table E-1 of American Petroleum Institute Publication 1509 and contains less than 90 percent saturates and / or greater than 0.03 percent sulfur, It means a base oil having a viscosity index of 80 or more and less than 120.

  The term “Group II base oil” uses the ASTM method as defined in Table E-1 of American Petroleum Institute Publication 1509, contains 90 percent or more saturates and 0.03 percent or less sulfur, 80 or more. A base oil having a viscosity index of less than 120 is meant.

  The term “Group II + base oil” means a Group II base oil having a viscosity index of 110 to less than 120.

  The term “Group III base oil” uses the ASTM method as defined in Table E-1 of American Petroleum Institute Publication 1509, contains 90 percent or more saturates and 0.03 percent or less sulfur, 120 or more. Base oil having a viscosity index of

  The term “Fischer-Tropsch derived” means a product, fraction or feed originating from a Fischer-Tropsch process or produced from a stage by a Fischer-Tropsch process.

  The term “petroleum derived” means a product, fraction or feed originating from the overhead steam stream from crude oil distillation and residual fuel which is a non-volatile residue. The origin of petroleum-derived products, fractions or feeds may be from gas field condensate.

  The term “high paraffinic wax” means a wax having a high content of n-paraffins, the n-paraffin content is generally greater than 40% by weight, but may be greater than 50% by weight, It may be greater than 75% by weight and may be less than 100% by weight or less than 99% by weight. Examples of highly paraffinic waxes include slack wax, deoiled slack wax, refined waxy oil, waxy lubricating raffinate, n-paraffin wax, NAO wax, wax produced by chemical plant process, deoiled petroleum derived wax , Microcrystalline waxes, Fischer-Tropsch waxes, and mixtures thereof.

  The phrase “derived from highly paraffinic wax” means a product, fraction or feed that originates from or is produced at a stage from a highly paraffinic wax.

  The term “aromatic” is any hydrocarbon compound containing at least one group of atoms sharing a continuous cloud of delocalized electrons, wherein the number of delocalized electrons in the group of atoms is 4n + 2 Corresponding to the solution to Hückel's law (for example, n = 1 for 6 electrons). Representative examples include, but are not limited to, benzene, biphenyl, naphthalene, and the like.

  The phrase “molecule having a cycloparaffinic functional group” is a monocyclic or fused polycyclic saturated hydrocarbon group or contains a monocyclic or fused polycyclic saturated hydrocarbon group as one or more substituents. Means any molecule. The cycloparaffin group may optionally be substituted with one or more, for example 1-3 substituents. Representative examples include, but are not limited to, cyclopropyl, cyclobutyl, cyclohexyl, cyclopentyl, cycloheptyl, decahydronaphthalene, octahydropentalene, (pentadecan-6-yl) cyclohexane, 3,7,10-tri Examples include cyclohexylpentadecane and decahydro-1- (pentadecan-6-yl) naphthalene.

  “Molecules with monocycloparaffinic functionality” are any molecule that is a monocyclic saturated hydrocarbon group of 3-7 ring carbons, or a single monocyclic saturated carbonization of 3-7 ring carbons. It means any molecule substituted with a hydrogen group. The cycloparaffin group may optionally be substituted with one or more, for example 1-3 substituents. Representative examples include, but are not limited to, cyclopropyl, cyclobutyl, cyclohexyl, cyclopentyl, cycloheptyl, (pentadecan-6-yl) cyclohexane, and the like.

  The phrase “molecule having a multicycloparaffinic functional group” is any molecule that is a polycyclic saturated hydrocarbon condensed ring group of two or more condensed rings, or a polycyclic saturated hydrocarbon of two or more condensed rings It means any molecule substituted with one or more fused ring groups, or any molecule substituted with two or more monocyclic saturated hydrocarbon groups of 3 to 7 ring carbons. The polycyclic saturated hydrocarbon fused ring group is often composed of two fused rings. The cycloparaffin group may optionally be substituted with one or more, for example 1-3 substituents. Representative examples include, but are not limited to, decahydronaphthalene, octahydropentalene, 3,7,10-tricyclohexylpentadecane, decahydro-1- (pentadecan-6-yl) naphthalene, and the like.

The term “kinematic viscosity” means a measurement of resistance to the flow of liquid under gravity. The exact operation of many base oils, lubricant compositions made from them, and equipment depends on the appropriate viscosity of the fluid being used. Kinematic viscosity is determined by ASTM D445-06. Results are reported in mm ² / s.

  The term “viscosity index” (VI) means an empirical, unitless number that indicates the effect of temperature change on the kinematic viscosity of the oil. The viscosity index is determined by ASTM D2270-04.

The term “Oxidator BN” means a measure of the base oil response in a simulated application. A high value, ie, a long time to absorb 1 liter of oxygen, indicates good stability. Oxidator BN can be measured with a Dornte oxygen absorber under pure oxygen at 1 atm at 340 ° F. (R. W. Dornte “Oxidation of White Oils” Industrial and Engineering Chemistry. 28, page 26, 1936). The time period in which 100 g of oil absorbs 1000 ml of O ₂ is reported in hours. In the Oxidator BN test, 0.8 ml of catalyst per 100 grams of oil is used. The catalyst is a soluble metal-naphthenate mixture that simulates the average metal analysis of the crankcase oil used. The additive package is 80 millimole of zinc bispolypropylenephenyl dithiophosphate per 100 grams of oil.

  Unless otherwise indicated herein, scientific and technical terms used in connection with the present invention shall have the meanings that are commonly understood by those of ordinary skill in the art. Also, unless otherwise required by context, singular terms shall include pluralities and plural terms shall include the singular. More specifically, as used herein and in the appended claims, the singular forms “a”, “an” and “the” include plural referents unless the context clearly dictates otherwise. Thus, for example, reference to “fatty acid” includes a plurality of fatty acids. Further, the ranges stated in this specification and the appended claims encompass both endpoints and all points between the endpoints. Thus, the range of 2.0 to 3.0 includes all points between 2.0, 3.0 and between 2.0 and 3.0. Further, all numbers and other numerical values used in the specification and claims representing a quantity, percentage or proportion are to be understood as being modified in all cases by the term “about”. As used herein, the term “include” and its grammatical variations are used to describe or replace an item description in a list with the listed item group. In order not to exclude the same item group, it is assumed that it is not limited. As used herein, the term “comprising” is meant to include the elements or steps specified following the term, but any such elements or steps are not exhaustive, Embodiments can include other elements or steps.

EXAMPLES The following examples are provided to illustrate specific embodiments of the invention. It should be appreciated by those skilled in the art that the methods disclosed in the following examples merely represent exemplary embodiments of the invention. However, one of ordinary skill in the art, in light of this disclosure, may make many changes in the specific embodiments described and obtain similar or similar results without departing from the spirit and scope of the invention. Please understand that you can.

(Example 1)
Epoxidation of octene to epoxyoctane A mixture of 2-octene, 3-octene and 4-octene (1: 1: 1 mixture), purchased from Aldrich Chemical, was prepared using the general procedure described below (Scheme 1). And epoxidized. To a stirred solution of 509 grams (2.95 mol) of 77% mCPBA (meta-chloroperoxybenzoic acid) in 2000 mL of n-hexane in an ice bath was added 265 grams (2.36 mol) of 2-octene, 3-octene and The 4-octene (1: 1: 1) mixture was added dropwise via an addition funnel over 60 minutes. The resulting reaction mixture was stirred for more than 2 hours at 0 ° C. The ice bath was then removed and the reaction was stirred overnight. Subsequently, the resulting milky white solution was filtered to remove metachlorobenzoic acid formed therein. The filtrate was then washed with a 10% aqueous solution of sodium bicarbonate. The organic layer was dried over anhydrous magnesium sulfate with stirring for 1 hour. The organic solvent (n-hexane) was removed by distillation at atmospheric pressure and 67-71 ° C. The presence of an epoxide mixture with little residual n-hexane was confirmed by IR and NMR analysis and GCMS spectroscopy on the remaining solution. This solution was used as such for the next step (reduction of the epoxide to the corresponding secondary alcohol) without further attempts to remove residual hexane. Because epoxides are slightly volatile, care must be taken to prevent any appreciable loss due to distillation or concentration on a rotary evaporator. Epoxidation was also carried out using a 1: 1.5 part formic acid / hydrogen epoxide solution.

(Example 2)
Reduction of 2,3-epoxyoctane to secondary octanol The epoxyoctane produced in accordance with Example 1 with little residual hexane was reduced with lithium aluminum hydride in THF (tetrahydrofuran) according to the following procedure. The product from Example 1 was divided into two equal parts, each part reduced separately with lithium aluminum hydride in anhydrous THF. Assuming that octene was completely converted to epoxide in Example 1, each portion was considered to contain 1.18 moles (151.3 grams) of epoxyoctane. Therefore, a 56 gram (1.48 mol) lithium aluminum hydride suspension in 1000 mL anhydrous THF in a 3 liter three-neck reaction flask equipped with an overhead stirrer and reflux condenser was cooled to 0 ° C. in an ice bath. Cooled down. To this suspension, one of two parts of the epoxy octane mixture (151.3 grams: estimated to be 1.18 mol) was added dropwise to this suspension via a closed addition funnel. When the addition was complete, an additional 100 ml of THF was added via the addition funnel. The reaction mixture was stirred for 2 hours at 0 ° C. The ice bath was then removed and the reaction was stirred overnight. The reaction was then heated to reflux for about 1 hour to ensure complete reduction. The progress of the reaction was monitored by NMR and IR analysis during the workup of a small aliquot. When complete, replace the heat source with an ice bath, first dilute with 500 ml of THF, then add 550 ml of 15% NaOH solution via a dropping funnel with vigorous stirring so that the temperature of the reaction does not rise above room temperature. The reaction was worked up by (added very slowly). The addition continued until all the gray solution was converted to a milky solution, and stirring was continued for an additional 30 minutes. Stirring was stopped and the solution was successfully separated into a clear liquid phase and a fine white precipitate. The mixture is filtered and the filtrate is dried over anhydrous MgSO ₄ and then concentrated on a rotary evaporator to remove the solvent THF to obtain a mixture of 2-octanol, 3-octanol and 4-octanol as a colorless viscous oil. This was changed to a very soft waxy substance while standing at room temperature for several days. In the two reactions described in Examples 1 and 2, reduction resulted in 132 grams of alcohol or 86% yield. Reduction of the second part of epoxy octane gave similar results with an overall yield of 84%. Reduction was also achieved by mild hydrogenation over a small scale Pd / C catalyst.

(Example 3)
Esterification of octanol with hexanoyl chloride: Synthesis of octylhexanoate The mixture of 2-octanol, 3-octanol and 4-octanol prepared in Synthesis Example 2 uses hexanoyl chloride as the esterifying agent as shown in Scheme 3. Was esterified by the following procedure. To a solution of 130.5 grams (1 mol) of octanol in 1000 ml of cyclohexane in a 3 liter three-necked reaction vessel equipped with an overhead stirrer and reflux condenser, 126.5 grams (1.25 mol) of triethylamine and 6.5 grams (0.05 mol) of 4-N, N-dimethylaminopyridine (DMAP) was added. The mixture was cooled with an ice bath and stirred at about 0 ° C. for 15 minutes. To the stirred cooled solution, 148 grams (1.1 mol) of hexanoyl chloride was added dropwise via a dropping funnel over 45 minutes. Once all hexanoyl chloride was added, the reaction was stirred and allowed to warm slowly to room temperature. The reaction was then refluxed and monitored by NMR and IR analysis. When the reaction was complete, the resulting milky cream solution was worked up by adding water until all solids disappeared and a clear solution (two-phase solution) was formed. The biphasic solution was separated with a separatory funnel and the organic phase was washed with water and brine and stored. The aqueous phase was extracted with ethyl acetate. The ethyl acetate extract was washed with brine and combined with the organic phase. The organic phase containing the ester was dried over anhydrous MgSO ₄ , filtered and concentrated on a rotary evaporator to give 218 grams (96% yield) of the ester mixture as a slightly orange oil. The product was passed through a 15 cm × 5 cm silica gel plug and flushed with hexane. Hexane was removed on a rotary evaporator to give the product as a colorless oil (214 grams recovered).

(Example 4)
A mixture of octanol esterified with hexanoic acid using H ₃ PO ₄ as catalyst was also esterified with hexanoic acid in toluene using phosphoric acid as catalyst according to the following procedure. The reactor consisted of a 1 L three-necked reaction flask equipped with an overhead stirrer, a reflux condenser with a Dean-Stark tube and a heating mantle. A reaction vessel was charged with 50 grams (0.38 mol) of octanol mixture, 66 grams (0.57 mol) of hexanoic acid, 5 grams of 85% phosphoric acid, and 250 ml of toluene. The mixture was heated to reflux (at about 110 ° C.) for 6 hours and stirred at reflux overnight. Another gram of 85% H ₃ PO ₄ is added and the reaction is continued under reflux until no further water formation is observed (as indicated by the level of water recovered in the Dean-Stark tube). And stirred. In all, the reaction was stirred for about 36 hours. The reaction is then cooled and the toluene removed on a rotary evaporator, followed by extraction with diethyl ether, washing well with warm water (4 × 500 ml), after which all remaining (organic and inorganic) acids are removed. Work-up by rinsing with 300 ml saturated sodium bicarbonate solution and brine (300 ml) for removal. The ether extract was dried over anhydrous MgSO ₄ , filtered and concentrated on a rotary evaporator to remove the ether. This reaction yielded 76 grams of a pale yellow oil. The oil was then passed through a 10 cm × 4 cm silica gel plug to remove any remaining acid. After the final purification step, 73 grams of the desired ester (octylhexanoate) was recovered as a colorless oil with a sweet odor. Using the same synthesis procedure, decylhexanoate was synthesized in similar yields.

(Example 5)
Lubricating properties of octylhexanoate and decylhexanoate The table below shows the lubricating properties of octylhexanoate and decylhexanoate.

(Example 6)
Oxidator BN test The oxidative stability of the octylhexanoate mixture was evaluated using the Oxidator BN test by measuring how long it takes to absorb 1 liter of oxygen for a given amount of ester. . Octylhexanoate showed excellent oxidative stability at 64 hours (see Table 1 above).

(Example 7)
Production of Drilling Fluid from Example 4 Invert emulsion drilling fluid was prepared by: (a) first stirring 166.0 grams of ester (octylhexanoate) from Example 4 using a blender for about 1 minute; b) Then in succession the following ingredients: (i) 16.0 grams of emulsifying wetting agent (OMNI-MUL®, Baker-Hughes); (ii) 3.0 grams of organophilic clay (CARBO) -GEL (R) II, Baker-Hughes) (added each material, followed by continuous mixing for about 1 minute). Subsequently, 46.0 grams of water was added to the mixture and mixed for about 10 minutes. Next, the following ingredients were added in order and mixed for about 5 minutes after each ingredient was added: (i) 300.3 grams of powder barite (non-toxic extender); (ii) 17.2 grams of Calcium chloride dihydrate (to provide salt to the aqueous phase without wetting water into barite); (iii) 4.0 grams of latex filtration control agent (Pliolite®, Goodyear); and (iv) 40.0 grams of powdered clay to simulate drilling formed particles. The final density of the drilling fluid was 14 pounds per gallon (about 1.7 kg / l).

(Example 8)
Production of Drilling Fluid from Example 4 Invert emulsion drilling fluid was: (a) First, 168.076 grams of ester (octylhexanoate) from Example 4 was stirred for about 1 minute using a blender ( b) Then in succession the following ingredients: (i) 12.0 grams of emulsifying wetting agent (OMNI-MUL®, Baker-Hughes); (ii) 2.5 grams of organophilic clay (CARBO) -GEL (R) II, Baker-Hughes) (added each material, followed by continuous mixing for about 1 minute). Subsequently, 48.3 grams of water was added to the mixture and mixed for about 10 minutes. Next, the following ingredients were added in order and mixed for about 5 minutes after each ingredient was added: (i) 300.3 grams of powder barite (non-toxic extender); (ii) 17.2 grams of Calcium chloride dihydrate (to provide salinity to the aqueous phase without wetting water into barite); (iii) 2.0 grams of latex filtration control agent (Pliolite®, Goodyear); and (iv) 40.0 grams of powdered clay to simulate drilling formed particles. The final density of the drilling fluid was 14 pounds per gallon (about 1.7 kg / l).

(Example 9)
Drilling Fluid Rheology Obtained from Example 7 The drilling fluid rheology of Example 7 can be found in the FannX77 instrument (Fann Instrument Company, Houston, TX), “Recommended Practice-Standard Procedure for Drilling Fluid Field Testing. Field Testing Drilling Fluids) ", API Recommended Practice 13B-2 (RP 13B-2), 2nd Edition, December 1, 1991, American Petroleum Institute, Washington, D.C. Evaluation was made according to the procedure described in C. The measurement results are shown in Table 2A. From these results it is clear that the ester of Example 4 can be used to produce an acceptable drilling fluid and that it has a very low gel strength at high temperatures (above 200 ° F.).

(Example 10)
Drilling Fluid Rheology Obtained from Example 8 The drilling fluid rheology of Example 8 can be found in the Fanni iX77 instrument (Fann Instrument Company, Houston, TX) as “Recommended Practice-Standard Procedure for Drilling Fluid Field Testing”. Field Testing Drilling Fluids) ", API Recommended Practice 13B-2 (RP 13B-2), 2nd Edition, December 1, 1991, American Petroleum Institute, Washington, D.C. Evaluation was made according to the procedure described in C. The measurement results are shown in Table 2B. From these results it is clear that the ester of Example 4 can be used to produce an acceptable drilling fluid and that it has a very low gel strength at high temperatures (above 200 ° F.).

  The monoester produced a unique and different rheological property profile in the Fann 77 test. The difference (and specificity) is that it has low gel strength at 200 ° F. and 250 ° F. and high pressure. This formulation showed no signs of in-device settling. Furthermore, the gel strength is very uniform and does not change. The effect itself is a reduction in pump pressure required to start circulation after long excavations have been stopped.

  All patents, patent applications, and published documents are hereby incorporated by reference to the same extent as if each individual patent, patent application, or published document was specifically and individually indicated to be incorporated by reference.

  The present invention is not to be limited in scope by the specific embodiments described herein which are intended to be merely illustrative of individual aspects of the invention, but functionally equivalent methods and components are intended to Within range. Indeed, various modifications of the invention will become apparent to those skilled in the art from the foregoing description and accompanying drawings, in addition to those shown and described herein. Such modifications are intended to fall within the scope of the appended claims.

The present invention is not to be limited in scope by the specific embodiments described herein which are intended to be merely illustrative of individual aspects of the invention, but functionally equivalent methods and components are intended to Within range. Indeed, various modifications of the invention will become apparent to those skilled in the art from the foregoing description and accompanying drawings, in addition to those shown and described herein. Such modifications are intended to fall within the scope of the appended claims.
The aspects that can be included in the present invention are summarized as follows.
[Aspect 1]
a) rotating a drill bit at the bottom of the borehole;
b) introducing a drilling fluid into the drilling hole to pick up the drill cut and carrying at least a portion of the drill cut from the drilling hole, wherein the drilling fluid comprises: ,
i) at least one additive selected from the group consisting of emulsifiers, wetting agents, thickeners, extenders and fluid loss control agents;
ii) Formula I:
[Chemical 1]

(Wherein R ₁ and R ₂ are independently selected from C ₁ -C ₈ and R ₃ is C ₅ -C ₁₃ )
And a predetermined amount of at least one monoester.
[Aspect 2]
The method of embodiment 1, wherein steps a) and b) are performed continuously.
[Aspect 3]
The method of embodiment 1, wherein the monoester of formula I is biodegradable and non-toxic.
[Aspect 4]
A process according to embodiment 1 above, wherein the monoester of formula I is derived from an isomerized olefin.
[Aspect 5]
The method of embodiment 1, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₅ and R ₃ is C ₅ -C ₈ .
[Aspect 6]
The method according to embodiment 1, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₃ and R ₃ is C ₅ -C ₆ .
[Aspect 7]
The kinematic viscosity at a temperature of 100 ° C. of the monoester of Formula I is between about 0.5 cSt and 2 cSt, the kinematic viscosity at a temperature of 40 ° C. is between about 2 cSt and 4 cSt, and the kinematic viscosity at a temperature of 0 ° C. The method of embodiment 1, wherein the method is between about 4 cSt and 12 cSt.
[Aspect 8]
The method of embodiment 1, wherein the monoester of formula I has Oxidator BN longer than 30 hours.
[Aspect 9]
The process of embodiment 1, wherein the monoester of formula I has a pour point lower than about −30 ° C. and a cloud point lower than about −30 ° C.
[Aspect 10]
The method of embodiment 1, wherein the drilling fluid has a pour point lower than about 10 ° C. and a viscosity at 40 ° C. between about 1 cSt and about 10 cSt.
[Aspect 11]
The method of embodiment 1, wherein the drilling fluid has a 10 second gel strength between about 2 pounds / 100 square feet and about 15 pounds / 100 square feet.
[Aspect 12]
The method of embodiment 1, wherein the drilling fluid has a 10 minute gel strength between about 1 pound / 100 square feet and about 17 pounds / 100 square feet.
[Aspect 13]
The method according to embodiment 4, wherein R ₃ is C ₅ .
[Aspect 14]
The method according to embodiment 4, wherein R ₃ is C ₅ and R ₁ and R ₂ are C ₂ .
[Aspect 15]
The method according to embodiment 4, wherein R ₃ is C ₅ and R ₁ and R ₂ are C ₃ .
[Aspect 16]
The method of embodiment 1, above, wherein the at least one monoester of formula I is octylhexanoate, its isomers and mixtures thereof.
[Aspect 17]
The method of embodiment 1, above, wherein the at least one monoester of formula I is decylhexanoate, its isomers and mixtures thereof.
[Aspect 18]
The method of embodiment 1, wherein the drilling fluid of step (b) comprises between about 20% and 40% by weight of the monoester of formula I.
[Aspect 19]
The drilling fluid of step (b) is
a. Between about 1.0% and about 3.0% by weight of emulsifiers and wetting agents;
b. Between about 0.1% and about 1.5% by weight of organophilic clay;
c. Between about 5 wt% and about 12 wt% water;
d. Between about 1.0 wt% and about 4.0 wt% salt;
e. Between about 0.1 wt% and about 1.0 wt% latex filtration control agent;
f. Between about 40% and about 60% by weight of a bulking agent; and
g. Simulated drilling solids between about 3.0 wt% and about 9.0 wt%
The method of embodiment 1, further comprising:

Claims (19)

a) rotating a drill bit at the bottom of the borehole;
b) introducing a drilling fluid into the drilling hole to pick up the drill cut and carrying at least a portion of the drill cut from the drilling hole, wherein the drilling fluid comprises: ,
i) at least one additive selected from the group consisting of emulsifiers, wetting agents, thickeners, extenders and fluid loss control agents;
ii) Formula I:

(Wherein R ₁ and R ₂ are independently selected from C ₁ -C ₈ and R ₃ is C ₅ -C ₁₃ )
And a predetermined amount of at least one monoester.   The method of claim 1, wherein steps a) and b) are performed continuously.   The method of claim 1 wherein the monoester of Formula I is biodegradable and non-toxic.   The process of claim 1, wherein the monoester of formula I is derived from an isomerized olefin. The method of claim _1, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₅ and R ₃ is C ₅ -C ₈ . The method of claim _1, wherein R ₁ and R ₂ are independently selected from C ₁ -C ₃ and R ₃ is C ₅ -C ₆ .   The kinematic viscosity at a temperature of 100 ° C. of the monoester of Formula I is between about 0.5 cSt and 2 cSt, the kinematic viscosity at a temperature of 40 ° C. is between about 2 cSt and 4 cSt, and the kinematic viscosity at a temperature of 0 ° C. The method of claim 1, wherein the method is between about 4 cSt and 12 cSt.   The process according to claim 1, wherein the monoester of formula I has an Oxidator BN longer than 30 hours.   The process of claim 1, wherein the monoester of Formula I has a pour point below about -30 ° C and a cloud point below about -30 ° C.   The method of claim 1, wherein the drilling fluid has a pour point lower than about 10 ° C. and a viscosity at 40 ° C. between about 1 cSt and about 10 cSt.   The method of claim 1, wherein the drilling fluid has a 10 second gel strength between about 2 pounds / 100 square feet and about 15 pounds / 100 square feet.   The method of claim 1, wherein the drilling fluid has a 10 minute gel strength between about 1 pound / 100 square feet and about 17 pounds / 100 square feet. The method of claim 4, wherein R ₃ is C ₅ . The method of claim 4, wherein R ₃ is C ₅ and R ₁ and R ₂ are C ₂ . The method of claim 4, wherein R ₃ is C ₅ and R ₁ and R ₂ are C ₃ .   The process according to claim 1, wherein the at least one monoester of formula I is octylhexanoate, its isomers and mixtures thereof.   The process according to claim 1, wherein the at least one monoester of formula I is decylhexanoate, its isomers and mixtures thereof.   The method of claim 1, wherein the drilling fluid of step (b) comprises between about 20 wt% and 40 wt% of the monoester of formula I. The drilling fluid of step (b) is
a. Between about 1.0% and about 3.0% by weight of emulsifiers and wetting agents;
b. Between about 0.1% and about 1.5% by weight of organophilic clay;
c. Between about 5 wt% and about 12 wt% water;
d. Between about 1.0 wt% and about 4.0 wt% salt;
e. Between about 0.1 wt% and about 1.0 wt% latex filtration control agent;
f. Between about 40% and about 60% by weight of a bulking agent; and
g. The method of claim 1, further comprising between about 3.0 wt% and about 9.0 wt% simulated drilled solids.