Halliburton Energy Services, Inc.

Hallibunon Energy Services, Inc.

Philip Wayne Livanec

Jay Paul Deville

Chesnee Lae Davis

Lee Jeremy Hall

William Walter Shumway

Gregory Paul Perez

Matthew Lynn Miller

Jonathan Paul Walker

Alan William Marr

Greg Paul Perez

Scott Anthony Klasner

Zhao Deng

Hui Zhou

Greg P J Perez

It can sometimes be difficult to quantify the amount of polymer present in a subterranean treatment fluid, particularly at a job site. Methods for analyzing a treatment fluid for a polymer can comprise: receiving a sample of a treatment fluid comprising a nitrogen-containing polymer; placing the sample of the treatment fluid and an aqueous base in an oilfield retort; heating the sample of the treatment fluid and the aqueous base together in the oilfield retort at least until the nitrogen-containing polymer has been substantially hydrolyzed to one or more volatile nitrogen compounds; distilling the one or more volatile nitrogen compounds from the oilfield retort; and determining a quantity of the nitrogen-containing polymer in the sample of the treatment fluid based upon a quantity of the one or more volatile nitrogen compounds distilled from the oilfield retort. Analyses of other nitrogen-containing compounds may take place similarly.

Methods for quantifying nitrogen-containing compounds in subterranean treatment fluids

Embodiments relate to solid nano-particles applied to the surface of well equipment to treat bituminous material adhesion. An embodiment provides a method of treating the surface of well equipment. The method may comprise applying a solid nanoparticle film to the surface of the well equipment with a treatment fluid comprising solid nanoparticles. The method may further comprise allowing the solid nanoparticles to interact with the surface of the well equipment and/or bituminous materials adhered to the surface of the well equipment to remove at least a portion of the bituminous materials from the surface of the well equipment.

Methods of mitigating bituminous material adhesion using nano-particles

A method including providing a drilling fluid that comprises a base fluid, a weighting agent, and a sag stability enhancer, wherein the sag stability enhancer comprises polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol; and placing the drilling fluid in a subterranean formation via a wellbore penetrating the subterranean formation. A method including forming a fluid comprising a base fluid, a weighting agent, and from about 0.5 ppb (1.4 kg/m) to about 30 ppb (85.5 kg/m) of a sag stability enhancer, wherein the sag stability enhancer comprises a glycol; and introducing the fluid into at least a portion of a well. A drilling fluid containing a base fluid, a weighting agent, and a sag stability enhancer comprising polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol.

Additive to enhance sag stability of drilling fluid

Embodiments relate to removing residue from a well bore and well bore equipment with a treatment fluid composition, and in some embodiments, to treatment fluid compositions that comprise nanoparticles. An embodiment provides a method of removing drilling fluid residue from the surfaces of well equipment. The method comprising: applying a solid nanoparticle film to at least a portion of the surfaces of the well equipment with a treatment fluid comprising solid nanoparticles; and allowing the solid nanoparticles to interact with the surfaces of the well equipment and the drilling fluid residue adhered to the surfaces of the well equipment to remove at least a portion of the drilling fluid residue from the surfaces of the well equipment.

Use of nanoparticles in cleaning well bores

Shale inhibiting additives for subterranean drilling and/or treatment fluids that include polyvinyl alcohol (PVA) are provided. In some embodiments, the methods include: providing a treatment fluid including an aqueous base fluid and a shale inhibiting additive including polyvinyl alcohol; introducing the treatment fluid into at least a portion of a subterranean formation to contact at least a portion of the subterranean formation that comprises shale; and allowing the shale inhibiting additive to interact with the shale in the subterranean formation to at least partially inhibit the shale.

Polyvinyl alcohol-based shale inhibitor

The present invention relates to hollow hydrogel capsules. In various embodiments, the present invention provides a method of treating a subterranean formation with a hollow hydrogel capsule including a hydrogel shell including a hydrolyzed and crosslinked polymerized composition. The hollow hydrogel capsule also includes a hollow interior including at least one component of a downhole composition for subterranean petroleum or water well drilling, stimulation, clean-up, production, completion, abandonment, or a combination thereof. In various embodiments, the present invention provides compositions comprising the hollow hydrogel capsules and methods of making the hollow hydrogel capsules.

Hollow hydrogel capsules and methods of using the same

Methods including introducing a running fluid into a subterranean formation, the running fluid comprising a base fluid and a weighting agent and having a specific gravity in the range of about 1.05 to about 3.0, and a 600 rpm shear stress of less than about 26.3 Pa, wherein the 600 rpm shear stress is measured at a shear rate of 600 rpm and a temperature of about 48.9&#xb0; C.; and running a tubular into the subterranean formation comprising the running fluid.

Running fluid for use in a subterranean formation operation

Among the methods provided is a method comprising: providing an oil-based fluid formed by combining components that comprise a glycol ether additive comprising a glycol ether, wherein the glycol ether additive substantially increases the low-shear viscosity of the oil-based fluid at temperatures between approximately 120 degrees Fahrenheit (48.9 degrees Celsius) and 500 degrees Fahrenheit (260 degrees Celsius); and using the oil-based fluid to drill at least a portion of a well bore penetrating at least a portion of a subterranean formation.

Thermal thickening in invert emulsion treatment fluids

Among the methods provided is a method comprising: providing an invert emulsion fluid formed by combining components that comprise: an oil-based continuous phase; an aqueous discontinuous phase; and a glycol ether additive that comprises a glycol ether and using the invert emulsion fluid to drill at least a portion of a well bore penetrating at least a portion of a subterranean formation.

Of the many compositions and methods provided herein, one method includes using a latex emulsion to treat well bore tar comprising. The method comprises providing a latex emulsion comprising a tar stabilizing polymer and water, combining the latex emulsion with alcohol, introducing a treatment fluid comprising the latex emulsion into a well bore, and contacting tar resident in the well bore with the treatment fluid wherein the latex emulsion at least partially reduces the tendency of the tar to adhere to a surface.

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Deer Park, TX, United States of America

Philip Wayne Livanec