Texas United Chemical Company, LLC

Tucc Technology, LLC

Halliburton Energy Services, Inc.

Kim O Tresco

Bradley Leon Todd

James W Dobson, Jr

Jorge M Fernandez

Shauna Leigh Hayden

Jeffrey S Lay

Pierre J Hinds

Benjamin K Geerdes

Abmel Marquez Perez

James W Dobson

Trinidad Munoz

Jr James W Dobson

James W Dobson Jr

Abmel Marquez c/o Urb Terrazas Del Avila Perez

The invention provides concentrates for reducing the fluid loss on an oil base well drilling or servicing fluid, the concentrates comprising an oleagineous liquid and (1) a polymer which is solublized in the oleagineous liquid, or (2) a polymer which is solublized in the oleaginous liquid together with an organophilic polyphenolic material which is solublized and/or dispersed in the oleagineous liquid. The method of preparing the concentrate and the method of reducing the fluid loss of an oil base well drilling or servicing fluid utilizing the concentrates is also disclosed. The preferred oil soluble polymer is a styrene-butadiene rubber crumb. The preferred oleagineous liquid is an aromatic-free hydrogenated oil essentially containing only saturated hydrocarbons. The preferred polyphenolic material is a source of humic acid, such as mined lignite.

Solubilized polymer concentrates, methods of preparation thereof, and well drilling and servicing fluids containing the same

Disclosed is an alkaline earth metal peroxide concentrate, or fluidized suspension, for addition to aqueous hydraulic fracturing fluids to efficiently decrease the viscosity of the hydrated, hydrophilic polysaccharide polymer in the system. The concentrate comprises a hydrophobic, water insoluble liquid, an organophilic clay suspension agent, a polar activator, a sparingly-soluble alkaline earth metal peroxide, and an anionic surfactant. Advantageously, these concentrations, or suspensions, exhibit high flash points, making them easier to transport using commercial transportation means.

Earth metal peroxide fluidized compositions

A treatment fluid composition for treating a subterranean formation penetrated by a well bore is formed from an aqueous fluid, a hydratable polymer and an inorganic peroxide breaking agent, which is classified as a stable, non-oxidizer according to UN standards but which retains oxidizing properties as measured by the content of available oxygen. A method of treating a subterranean formation penetrated by a well bore may also be performed by forming a treatment fluid from an aqueous hydrated polymer solution. This is combined with a stable, inorganic peroxide breaking agent. The treating fluid is then introduced into the formation. An optional crosslinking agent capable of crosslinking the polymer may also be included.

Treatment fluids with non-oxidizer class inorganic peroxide polymer breakers and methods of use thereof

A water-based drilling fluid which includes an aqueous fluid and a water-soluble dissipative surfactant composition is described, wherein the dissipative surfactant composition includes at least one fatty acid or ester derivative of a plant or vegetable oil. Also described are methods of using such aqueous-based drilling fluids including the dissipative surfactant composition as described in hydrocarbon recovery operations associated with oil/tar sand, where such fluids act to increase the dispersant qualities of hydrocarbons within the oil/tar sand, and where such fluid exhibit a reduced coefficient of friction.

Dissipative surfactant aqueous-based drilling system for use in hydrocarbon recovery operations from heavy oil and tar sands

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.

Ultra high viscosity pill and methods for use with an oil-based drilling system

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.

Compounded hydrocarbon oil and oil base drilling fluids prepared therefrom

The invention provides well drilling and servicing fluids, and methods of drilling, completing, or working over a well therewith, preferred fluids comprise an aqueous liquid, a water soluble polymer viscosifier (preferably xanthan gum), a polymeric fluid loss control additive (preferably a partially depolymerized partially crosslinked hydroxyalkyl ether derivative of starch or a hydroxyalkyl ether derivative of a partially crosslinked and partially depolymerized starch), a bridging agent comprising a particulate calcined magnesia that has an Activity Index greater than about 800 seconds, and an additive selected from the group consisting of citric acid, alkali metal salts of citric acid, ammonium citrate, and mixtures thereof in an amount sufficient to increase the low shear rate viscosity of the fluids, preferably from about 0.05&#x2013;5 ppb, most preferably from about 0.15&#x2013;3 ppb. The invention further provides a method of increasing the low shear rate viscosity of fluids which contain a water soluble polymer and a calcined magnesia bridging agent which has an Activity Index greater than about 800 seconds.

Method of increasing the low shear rate viscosity of well drilling and servicing fluids containing calcined magnesia bridging solids, the fluids and methods of use

The invention provides well drilling and servicing fluids, and methods of drilling, completing, or working over a well therewith, preferred fluids comprise an aqueous liquid, a water soluble polymer viscosifier (preferably xanthan gum), a polymeric fluid loss control additive (preferably a partially depolymerized partially crosslinked hydroxyalkyl ether derivative of starch or a hydroxyalkyl ether derivative of a partially crosslinked and partially depolymerized starch), a bridging agent comprising a particulate calcined magnesia that has an Activity Index greater than about 800 seconds, and citric acid in an amount sufficient to increase the low shear rate viscosity of the fluids. The invention further provides a method of increasing the low shear rate viscosity of fluids which contain a water soluble polymer and a calcined magnesia bridging agent which has an Activity Index greater than about 800 seconds.

Disclosed is a method of increasing the low shear rate viscosity and the shear thinning index of aqueous fluids containing a divalent cation salt, a crosslinked amylopectin starch which functions as both a viscosifier/suspending agent and as a fluid loss control additive, and a bridging agent, the fluids resulting from the method, and the use of the fluids in drilling a well, wherein the bridging agent is a sized particulate magnesium carbonate or a mixture of sized magnesium carbonate and sized calcium carbonate. The median (D ) particle size of the magnesium carbonate is from about 2 &mgr;m to about 10 &mgr;m. The weight ratio of calcium carbonate to magnesium carbonate is from about 70/30 to about 0/100.

Method of increasing the low shear rate viscosity and shear thinning index of divalent cation-containing fluids and the fluids obtained thereby

The invention provides clay-free, preferably biopolymer free, well drilling and servicing fluids comprising an aqueous divalent cation-containig water soluble salt, a bridging agent, and a pre-gelatinized crosslinked amylopectin starch suspending agent and fluid loss control additive. The concentration of the starch derivative is sufficient to provide the fluid with the following charactristics: (a) a low shear rate viscosity less than about 10,000 centipoise; (b) a high shear rate viscosity at 511 sec in the range from about 15 to about 70 centipoise measured at 120&deg; F.; (c) a fluid loss less than about 10 milliliters as measured at 185&deg; F. and 250 psi differential pressure across a 5 micron disk for 30 minutes; and (d) anti-settling characteristics as exhibited upon static aging the fluid for 16 hours at 185&deg; F. The low shear rate viscosity of the fluids can be increased without increasing the high shear rate viscosity above about 70 centipoise by incorporating magnesium oxide and/or dipotassium hydrogen phosphate in the fluids. The invention also provides a method of making the clay-free well drilling and servicing fluid and a process of drilling, completing, and working over a well with the clay-free fluid.

Divalent cation-containing well drilling and servicing fluids

The invention provides clay-free, preferably biopolymer free, well drilling and servicing fluids comprising an aqueous divalent cation-containing water soluble salt, a bridging agent, and a pre-gelatinized crosslinked amylopectin starch suspending agent and fluid loss control additive. The concentration of the starch derivative is sufficient to provide the fluid with the following charactersitics: (a) a low shear rate viscosity less than about 10,000 centipoise; (b) a high shear rate viscosity at 511 sec,in the range from about 15 to about 70 centipoise measured at 120&deg; F.; (c) a fluid loss less than about 10 milliliters as measured at 185&deg; F. and 250 psi differential pressure across a 5 micron disk for 30 minutes; and (d) anti-settling characteristics as exhibited upon static aging the fluid for 16 hours at 185&deg; F.

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Houston, TX, United States of America

Kim O Tresco