Abstract: A drilling fluid is provided which results in an enhanced rate of penetration, and more particularly, a drilling mud composition is provided with a reduced ester content which maintains an enhanced rate of penetration.

Abstract: A drilling composition is provided. The composition includes: I) an organic phase comprising components: i. from about 20 wt. % to about 99.999 wt. %, based on the total weight of components i. and ii., of at least one linear or branched, cyclic or non-cyclic, saturated hydrocarbon; ii. from about 0.001 wt. % to about 25 wt. %, based on the total weight of components i. and ii., of at least one ester; II) from 0 to about 50 wt. %, based on the total weight of the composition, of water or aqueous phase; III) from 0 to about 60 wt. %, based on the total weight of the composition, of at least one additive, wherein the sum of the weight components I) to III) is 100 wt. %.

Abstract: A base fluid may contain nanoparticles where the base fluid may include a non-aqueous fluid, an aqueous fluid, and combinations thereof. The fluid may have a resistivity range of from about 0.02 ohm-m to about 1,000,000 ohm-m. The non-aqueous fluid may be a brine-in-oil emulsion, or a water-in-oil emulsion; and the aqueous fluid may be an oil-in-water emulsion, or an oil-in-brine emulsion; and combinations thereof. The addition of nanoparticles to the base fluid may improve or increase the electrical conductivity and other electrical properties of the fluid. The fluid may be a drilling fluid, a completion fluid, a production fluid, and/or a stimulation fluid.

Abstract: Method for controlling lost circulation in a subterranean well using oil-dispersible lost-circulation materials which comprise fibers that are coated (or sized) with a lipophilic coupling agent, a lipophilic film-forming polymer or both. The fibers are preferably between about 6 mm and about 25 mm long, and between about 10 ?m and about 200 ?m in diameter. The fibers may be added to carrier fluids comprising oil-base fluids, synthetic-base fluids, invert-emulsion-base fluids and combinations thereof. The preferred fiber concentration in the carrier fluid is between about 0.55 g/L and about 28.5 g/L. The carrier fluid may be a drilling fluid, a spacer fluid or a lost-circulation pill.

Abstract: A method for determining a Plug Normal Stress Difference (?N1(P)) may include providing a test base drilling fluid that is characterized by N1(TB); adding a first concentration of a test particulate to the test base drilling fluid; adjusting the concentration of the test particulate in the test base drilling fluid to achieve a minimum concentration of the test particulate in the test base drilling fluid that will substantially plug a tapered slot, wherein the test base drilling fluid with the minimum concentration of the test particulate is characterized by N1(TA); and calculating ?N1(P)=|N1(TA)|?|N1(TB)| wherein each First Normal Stress Difference is measured by the same procedure.

Abstract: Phosphate brines are disclosed having reduced corrosive ratings. The phosphate brines include an additive system that reduces the corrosiveness of the phosphate brines compared to the phosphate brines in the absence of the additive system.

Abstract: Disclosed is a hydrocarbon-based concentrate composition for crosslinking polysaccharide polymers in an aqueous-based fluid, such as a fracturing fluid, wherein the hydrocarbon-based composition has no or substantially no detectable levels of benzene, toluene, ethylbenzene, and/or m-, o-, or p-xylenes (BTEX). Preferred polysaccharide polymers are galactomannan gums or derivatives thereof. The concentrate comprises an oleaginous solution, such as a hydrocarbon distillate, a crosslinking agent for crosslinking the polysaccharide polymer, preferably a sparingly soluble alkali metal or alkali metal alkaline earth metal borate, and a stabilizing/suspension agent, preferably a clay mineral selected from the group consisting of smectite clays. The concentrate may, optionally, contain a deflocculant and/or an anti-syneresis additive.

Abstract: A subterranean treatment fluid comprising a degradable gemini surfactant composition described by the following formula: A and A? are spacers that may be a hydrophobic group or a hydrophilic group. B is an ion and may contain a quaternary nitrogen, a sulfonate, or a phosphate. A, A?, B, B?, C, C, E and E? may be an alkyl, an aryl, a sugar, an ester, an ether, and any combination thereof. D and D? may be an aryl, a sugar, an ester, an ether, and any combination thereof. In some cases, A?, D?, and E? may be optional.

Abstract: Composition of special fluid comprising at least one hydrogenated mono- and/or at least one polyterpene, in a mixture with at least one special fluid for industrial applications such as the petroleum industry, in construction as sealants and paints, adhesives, the inks industry, metal working, the treatment and protection of metals, but also for domestic uses and in the agric-food and plumbing industries.

Abstract: Non-settable spacer fluids for use in subterranean operations comprising: a base liquid; vitrified shale; a chelating agent; a clay weighting agent; and a viscosifying agent. The chelating agent includes one or more of nitrilotriacetic acid, ethylene diamine tetracetic acid (EDTA), ethylene glycol tetraacetic acid (EGTA), tartaric acid, a polycarboxylic acid, a lignosulphonate, hydroxyethylidene diphoshponic acid (HEDP), diethylene triamine penta (methylene phosphonic) acid (DETMP), amino-tri-methylene phosphonic acid (ATMP), ethylene diamine tetra (methylene phosphonic) acid (EDTMP), or salts thereof. The clay weighting agent is present in the range of about 0.01% to about 85% by weight of the spacer fluid. The viscosifying agent is present in the range of about 1% to about 10% by weight of the spacer fluid.

Abstract: Lubricants and drilling fluid systems comprising lubricants which form a coherent lubricating film on metal equipment, thereby prolonging equipment life even under a wide variety of conditions, including high temperature and/or high pressure conditions.

Abstract: Aqueous and substantially anhydrous fluids having particularly low thermal conductivities and variable densities are disclosed. The fluids include: one or more organic and/or inorganic salts and at least one aprotic polar organic solvent, a mixture of aprotic and erotic polar organic solvents, and/or a polar organic solvent having both prone and aprotic polar functional group linkages. The fluids optionally include one or more viscosifying agents and are free of cross-linking agents. Methods for formulating and using the fluids are also disclosed.

Abstract: Working fluids, such as drilling fluids, may remove heat from other fluids, tools, equipments and environments and transfer it to other locations by using reversible phase change elements. The heat removal occurs through the absorption of heat by one or more phase transitions or a sequence of phase transitions in the elements of the working fluid. For instance, heat is absorbed when the phase change portions of the reversible phase change elements change phase including, but not necessarily limited to, a change from solid to smectic liquid crystal, from solid to nematic liquid crystal, from smectic liquid crystal to isotropic liquid, from nematic liquid crystal to isotropic liquid, from solid to isotropic liquid, and sequences and combinations thereof. Heat is released when the phase change reverses. These phase changes are first-order transitions and are associated with a latent heat or enthalpy.

Abstract: A method and system remove hydrogen sulfide from a hydrocarbon containing fluid. In an embodiment, the method for removing hydrogen sulfide from a hydrocarbon containing fluid includes contacting a methylmorpholine-N-oxide solution with the hydrocarbon containing fluid. The method also includes allowing the methylmorpholine-N-oxide to react with the hydrogen sulfide to remove the hydrogen sulfide.

Abstract: Lost circulation of drilling fluid is one of the most serious and expensive problems facing the drilling industry. The present invention relates to an improved drilling fluid for reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well. The drilling fluid comprises a base fluid and wax or waxy substance as a primary seepage loss agent. In a particularly preferred embodiment, the seepage loss agent does not include particles having a blend of natural wax and synthetic wax together in a single particle. The invention also provides a method of reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well using the drilling fluid of the invention, wherein the primary seepage loss agent is added to the drilling fluid, either before or during drilling, and the drilling fluid is pumped down hole during drilling.

Abstract: Disclosed is a two-component fluid loss control system comprising a core substrate and a polymeric shell cooperating with each other to form a microcomposite, wherein the core substrate and the polymeric shell are formed from different materials. The system can demonstrate switchable behavior. The core substrate and the polymeric shell can be further modified, where modifications cooperate with each other to form the microcomposite. Also disclosed are formulations for fluid loss control and methods for controlling fluid loss in a well.

Abstract: Disclosed herein is a composition comprising from about 0.1 wt % to about 50 wt % of a plant based product comprising mucilage. Methods of making the composition, a well treatment fluid comprising the composition, and methods of using the composition are also disclosed.

Abstract: A wellbore fluid that includes an oleaginous base fluid; and a silanated weighting agent is disclosed. In particular, the silanated weighting agents may be produced by reaction between an alkyl alkoxy silane and a weighting agent Methods of formulating such fluids and methods of drilling using such fluids are also disclosed.

Abstract: Systems and methods for processing glycerol into one or more useful products are provided. The method can include decreasing a pH of a mixture comprising glycerol and fatty acids to produce an emulsion comprising a glycerol-rich portion and a fatty acids-rich portion. At least a portion of the glycerol-rich portion can be reacted with at least one of an oxidant and a catalyst at conditions sufficient to produce a reacted product comprising glyceric acid, oxalic acid, glycolic acid, formic acid, or any combination thereof.

Abstract: Drilling fluids comprising graphenes and nanoplatelet additives and methods for production thereof are disclosed. Graphene includes graphite oxide, graphene oxide, chemically-converted graphene, and functionalized chemically-converted graphene. Derivatized graphenes and methods for production thereof are disclosed. The derivatized graphenes are prepared from a chemically-converted graphene through derivatization with a plurality of functional groups. Derivatization can be accomplished, for example, by reaction of a chemically-converted graphene with a diazonium species. Methods for preparation of graphite oxide are also disclosed.

Abstract: Disclosed are ester compositions, solvents, cleaning formulations, curing agents, reactive diluent solvents, controlled acid function release agents, polyol monomers, drilling mud, methods of making each of the above, methods of using each of the above. In one embodiment, the ester composition is obtained from a process applied to a starting material, wherein the starting material is a portion of products from a cyclohexane oxidation process, wherein the starting material includes products having free acid functional groups, wherein the starting material is selected from the group consisting of a water extract (Water Wash), a concentrated water extract (COP Acid), a non-volatile residue (NVR), and a combination thereof.

Abstract: The present invention relates to a drilling composition comprising: I) an organic phase comprising components: i. from about 20 wt. % to about 99.999 wt. %, based on the total weight of components i. and ii., of at least one linear or branched, cyclic or non-cyclic, saturated hydrocarbon; ii. from about 0.001 wt. % to about 25 wt. %, based on the total weight of components i. and ii., of at least one ester; II) from 0 to about 50 wt. %, based on the total weight of the composition, of water or aqueous phase; III) from 0 to about 60 wt. %, based on the total weight of the composition, of at least one additive, wherein the sum of the weight components I) to III) is 100 wt. %, to a process for preparation of a drilling composition, to uses of a drilling composition, to a drilling system, to a process for making a borehole, to a process for conveying cuttings, to a process for treating a drill head, to a process for production of at least one of oil and gas.

Abstract: A method comprises providing a drilling fluid comprising: an aqueous fluid; and a microemulsion surfactant; and drilling a well bore in a subterranean formation comprising an oleaginous fluid using the drilling fluid, wherein the microemulsion surfactant forms a microemulsion with the oleaginous fluid within the well bore. In accordance with the method, the subterranean formation has a retained producibility greater than about 50%.

Abstract: Non-toxic, biodegradable base fluids are disclosed for use in making downhole fluids, where the base fluids include blends of paraffins, olefins, naphthenes, esters, and oxygenates, having low viscosities, having a pale-yellow color, having a flashpoint of >80° C. (175° F.) and have a pour point of about 19° F.

Abstract: A drilling fluid is provided which results in an enhanced rate of penetration, and more particularly, a drilling mud composition is provided with a reduced ester content which maintains an enhanced rate of penetration.

Abstract: The disclosure relates to a drilling fluid having a viscosity at 40° C. less than or equal to 2.5 mm2/s and having a vapor pressure at 100° C. less than or equal to 10 mBars (1 KPa) obtained from a hydrocarbon fraction having a distillation temperature of 200 to 280° C. and a naphthene hydrocarbon content of less than 40 wt % of the fraction.

Abstract: A reduced abrasion drilling fluid system and method of drilling a borehole by circulating the reduced abrasion drilling fluid through the borehole is disclosed. The reduced abrasion drilling fluid comprises a drilling fluid, a first additive and a weighting agent, wherein the weighting agent has a particle size of at least 90% by volume less than 50 ?m.

Abstract: A method comprises providing a drilling fluid comprising: an aqueous fluid; and a microemulsion surfactant; and drilling a well bore in a subterranean formation comprising an oleaginous fluid using the drilling fluid, wherein the microemulsion surfactant forms a microemulsion with the oleaginous fluid within the well bore. In accordance with the method, the subterranean formation has a retained producibility greater than about 50%.

Abstract: The present invention relates to glycerol based drilling fluids. In particular, the invention relates to drilling fluids comprising a 95-20 volume % glycerol/water solution capable of stabilizing water-sensitive formations during drilling and the use of such solutions for drilling a well having water-sensitive formations.

Abstract: Fluids and associated methods useful in subterranean applications are provided. Compositions are provided that may be useful in subterranean applications for addressing, among other things, drill string sticking problems. More particularly, spotting fluid compositions are provided having a water insoluble external phase fluid; a water soluble internal phase fluid; and an ether carboxylic acid emulsifying agent. Additional optional components may be used, such as viscosifiers, weighting agents, and wetting agents.

Abstract: Fluids and associated methods useful in subterranean applications are provided. More particularly, methods of reducing drill string sticking are provided, which include: providing a spotting fluid composition comprising a water insoluble external phase fluid, a water soluble internal phase fluid, and an ether carboxylic acid emulsifying agent; introducing the spotting fluid to the vicinity of a desired portion of a drill string; and allowing the spotting fluid to interact with a portion of material surrounding the desired portion of the drill string spotting fluid. Compositions are provided that may be useful in subterranean applications for addressing, among other things, drill string sticking problems. Additional optional components may be used, such as viscosifiers, weighting agents, and wetting agents.

Abstract: This invention relates to drilling fluids and processes for making drilling fluids, such as for use in environmentally sensitive areas. The environmentally friendly drilling fluid includes a first fluid component having between about 5 weight percent to about 95 weight percent of olefins with a chain length in a range of between about C12 and about C48. The first fluid component includes at least about 50 weight percent trisubstituted olefin functionality. The environmentally friendly drilling fluid includes a second fluid component.

Abstract: A system for reducing pressure drop associated with the turbulent flow of asphaltenic crude oil through a conduit. The crude oil has a high asphaltene content and/or a low API gravity. Such reduction in pressure drop is achieved by treating the asphaltenic crude oil with a high molecular weight drag reducing polymer that can have a solubility parameter within about 20 percent of the solubility parameter of the heavy crude oil. The drag reducing polymer can also comprise the residues of monomers having at least one heteroatom.

Abstract: A method for removing preexisting filtercake from a portion of a subterranean formation penetrated by a wellbore is carried out by providing water-degradable particles formed from a solid polymeric acid precursor material that is capable of a degrading to acid for reacting with materials of the filtercake. A slurry is formed from the particles with a carrier fluid. The slurry of particles is introduced into the formation through the wellbore and allowed to degrade to form acid, whereby the formed acid facilitates decomposition of preexisting filtercake material. In certain applications, the water-degradable particles may also be used in combination with non-water-degradable particles, which may be used for forming a gravel pack. The water-degradable particles may also be used to reduce fluid loss temporarily to areas of the formation immediately surrounding the wellbore.

Abstract: The invention relates to a concentrate for the effective, environmentally friendly treatment of oil-polluted stretches of ground and the cleaning of oil-contaminated surfaces, said concentrate containing an emulsifier, a vegetable oil and ethanol. The emulsifier is preferably a non-ionic surfactant with an HLB value between 7 and 8. The vegetable oil is preferably selected so that it is liquid at temperatures above 5 DEG C. Oils containing unsaturated fatty acids, in particular germ oils are especially suitable. For its application as a treatment for stretches of ground, the inventive concentrate is diluted with water to form a cleaning solution and is applied to the oil-contaminated surface that is to be treated. The oil is emulsified in the inventive cleaning solution and is detached from the particles of the ground. The oil degrades in a significantly easier manner in the emulsified state. To clean oil-contaminated surfaces, the cleaning solution is sprayed onto the latter.

Abstract: Compositions including relatively low reactivity acids, mixed with viscoelastic surfactants (VESs) and internal breakers may serve as drilling fluids to open underground hydrocarbon reservoirs with carbonate contents of 10 wt % or above. The drilling fluids have low viscosities in the drilling pipe. After the fluid flows out of the drill bit, the acids react with carbonates in the formation thereby increasing the pH of the drilling fluids causing the VES to gel the fluid at the bottom of the hole and the downhole annulus between the drilling pipe and the formation rock. The viscosified drilling fluid will reduce fluid loss and will carry no dissolved drilling debris to the surface. After drilling through the targeted formation, the internal breakers in the viscosified drilling fluids will break down the fluids to permit their removal, and the well is ready to produce with very little or no near well bore damage.

Abstract: Electrically conductive oil base drilling fuids with carbon nanotubes have either an organic base (oil) or a base that is an emulsion of water in oil (invert emulsion) and contains carbon nanotubes dispersed in oil. These drilling fluids may be prepared by either (1) the addition of electrically conductive dispersions of carbon nanotubes in oil to conventional oil base drilling fluids (unweighted or weighted) or (2) the sonication of the mixture of oil pre-wetted carbon nanotubes with unweighted conventional oil base drilling fluids. The electrically conductive dispersions of carbon nanotubes in oil may be prepared by sonication or by microfluidization. The oil may be a mineral oil, paraffin oil, synthetic oil, or diesel oil. The electrically conductive oil-based drilling fluids may further contain ionic, non-ionic or polymeric surfactants.

Abstract: A method for removing drilling damage from a formation in a wellbore that has not been produced includes injecting a chemical-acting cleanup fluid and contacting it with a filtercake on a face of a formation of interest for a period of time sufficient to loosen some of the solids embedded in the filtercake. The method further includes circulating a solids removal fluid at a high rate through the wellbore across the face of the formation of interest, the solids removal fluid including a viscosifier, and positioning a second treatment fluid having a fluid loss control pill in the wellbore at the formation of interest. The method further includes degrading particles of the fluid loss control pill and degrading remaining bridging agent from the drilling fluid.

Abstract: To improve drilling performance, a drilling fluid is selected based on one or more criteria and to have at least one target characteristic. Drilling equipment is used to drill a wellbore, and the selected drilling fluid is provided into the wellbore during drilling with the drilling equipment. The at least one target characteristic of the drilling fluid includes an ability of the drilling fluid to penetrate into formation cuttings during drilling to weaken the formation cuttings.

Abstract: The invention discloses a method of treating a subterranean formation of a well bore: providing a treatment fluid made of: a fluid; a particulate material, and a viscosifier material; wherein the viscosifier material is inactive in a first state and is able to increase viscosity of the treatment fluid when in a second state; introducing the treatment fluid into the wellbore; and providing a trigger able to activate the viscosifier material from first state to second state.

Abstract: A method of treating a formation that includes exposing a region of the formation occupied by a hydrolysable gel to a hydrolyzing agent; and allowing sufficient time for the hydrolyzing agent to hydrolyze the gel. Various methods may also include the use of a swelling agent to allow for expansion of the gel.

Abstract: The invention discloses a compounded hydrocarbon oil which comprises a base hydrocarbon oil, preferably a mixture of paraffinic hydrocarbons, propylene carbonate, and a liquid fatty acid containing at least 12 carbon atoms per molecule, preferably tall oil fatty acid. The volume ratio of propylene carbonate to liquid fatty acid is from about 3.5 to 1 to about 7 to 1. Preferably the concentration of propylene carbonate is from about 0.002 gal/gal oil to about 0.0057 gal/gal oil and the concentration of the liquid fatty acid is from about 0.0003 gal/gal oil to about 0.0015 gal/gal oil. The invention further comprises a method of compounding the compounded hydrocarbon oil and an oil base drilling fluid prepared from the compounded hydrocarbon oil. Preferably the compounded hydrocarbon oil is characterized by an increase in the low shear rate viscosity of the oil of at least 5,000 centipoise or mixing 7.5 lb/bbl of an organoclay therein.

Abstract: A composition and method for breaking down and denaturing friction-reducing compound introduced into the ground during the drilling of gas and oil wells and for destroying other contaminants and biohazards naturally present within and artificially introduced into hydrocarbon wells, which are formed as a result of the drilling and pumping processes. The composition includes several species of oxidizing agent compounds that are effective in breaking down hydrogen sulfide produced by bacteria as well as the friction-reducing polymer used during drilling and several other organic compounds.

Abstract: A fluid pressure transmission pill (FPTP) having an ultra-high viscosity for use in association with hydrocarbon drilling and exploration operations, particularly, managed pressure drilling (MPD) operations, is described. The ultra-high viscosity pill is a weighted pill composition that includes a hydrocarbon fluid, a thixotropic viscosifying agent, one or more activators, an emulsifier/wetting agent, a fluid loss control additive, and a weighting material. In accordance with selected aspects of the described fluid pressure transmission pill, the ratio of the amount of the thixotropic viscosifying agent to the activator is a ratio of about 7:1, and the weighting material is a barium-containing solid-phase material. Also described are methods of use of such FPTP products in subterranean operations, such as well killing operations during managed pressure drilling.

Abstract: Lost circulation of drilling fluid is one of the most serious and expensive problems facing the drilling industry. The present invention relates to an improved drilling fluid for reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well. The drilling fluid comprises a base fluid and wax or waxy substance as a primary seepage loss agent. In a particularly preferred embodiment, the seepage loss agent does not include particles having a blend of natural wax and synthetic wax together in a single particle. The invention also provides a method of reducing or preventing lost circulation to an underground formation surrounding a well bore in the process of drilling a well using the drilling fluid of the invention, wherein the primary seepage loss agent is added to the drilling fluid, either before or during drilling, and the drilling fluid is pumped down hole during drilling.

Abstract: This invention relates to drilling fluids and processes for making drilling fluids, such as for use in environmentally sensitive areas. The environmentally friendly drilling fluid includes a first fluid component having between about 5 weight percent to about 95 weight percent of olefins with a chain length in a range of between about C12 and about C48. The first fluid component includes at least about 50 weight percent trisubstituted olefin functionality. The environmentally friendly drilling fluid includes a second fluid component.

Abstract: The present invention relates to a viscoelastic drilling fluid for drilling in underground rock formations, comprising (a) an aqueous and/or organic liquid base, (b) at least one weighting agent, in particulate form, with a mass per unit volume of at least 2 g/cm3, preferably at least 4 g/cm3, in suspension in said liquid base, and (c) carbon nanotubes with a mean diameter of between 10 and 30 nm and a specific surface in excess of 200 m2/g, preferably of between 200 m2/g and 250 m2/g. It also relates to a drilling method using such a fluid.

Abstract: A method of slurrifying drill cuttings that includes admixing oil-contaminated drill cuttings, water, and at least one surface active agent; emulsifying at least a portion of the oil contaminants within the mixture; and forming a pourable slurry of drill cuttings in water is disclosed.

Abstract: Single phase microemulsions improve the removal of filter cakes formed during drilling with oil-based muds (OBMs). The single phase microemulsion removes oil and solids from the deposited filter cake. Optionally, an acid capable of solubilizing the filter cake bridging particles may also be used with the microemulsion. In one non-limiting embodiment the acid may be a polyamino carboxylic acid. Skin damage removal from internal and external filter cake deposition can be reduced. In another optional embodiment, the single phase microemulsion may contain a filtration control additive for delaying the filter cake removal, destruction or conversion.

Abstract: An annular fluid or packer fluid, and methods of making the same, that includes a water-miscible solvent, a viscosifying additive, a crosslinking agent, a crosslinking inhibitor having the facility to inhibit crosslinking between the viscosifying additive and the crosslinking agent, and an initiating agent having the facility to overcome an action of the crosslinking inhibitor and to initiate crosslinking between the viscosifying additive and the crosslinking agent, is shown and described. The fluid has a thermal conductivity of no more than about 0.25 btu/(hr·ft·° F.) and a potential to substantially increase its viscosity upon sitting for a selected period of time.