Halliburton Energy Services, Inc.

Ascend Performance Materials Operations LLC

Bradley James Sparks

Loan K Vo

Philip D Nguyen

James William Ogle

Jacob G Ray

Christopher R Parton

Scott E Powers

Corneliu Stanciu

Kimberly M White

Tariq S Oweimreen

Ryan M Hensarling

Jimmie Dean Weaver, Jr

Thomas Donovan Welton

Dipti Singh

Ubong Akpan Inyang

Ali Alwattari

David Michael Loveless

Janette Cortez

Phillip D Nguyen

Jessica Lynn Heeter

Douglas Everett Wyatt

Brian D Mock

Nanayakkara L Somasiri

Kai Becker

Avelino Lima

Ted Wieczorek

Nanayakkara Somasiri

Polyamide resin that comprise one or more polyamides and a stabilizer component containing an copper complex and a copper salt is disclosed for improving the heat age performance for an article. The combination of a copper complex and a copper salt retains the mechanical properties of the article.

Stabilizing component for polyamide resin composition

Provided herein are polyamide compositions including one or more semi-crystalline polyamides and either an amorphous polyamide or a semi-crystalline copolyamide such as PA66/6. The provided compositions are particularly useful as vibration isolators more effective at high-temperature noise and harshness damping than conventional polyamide compositions. Also provided are methods for making the provided compositions, and articles that include the provided compositions.

Polyamide formulations for improved noise vibration and harshness

An impact-modified polyamide composition comprising from 5 wt % to 85 wt % of polyamide polymer; from 10 wt % to 60 wt % glass fiber; from 3 wt % to 30 wt % of an impact modifier; and a melt stabilizer at a concentration less than 5 wt %; wherein the weight ratio of the impact modifier to the melt stabilizer ranges from 1.0:1 to 100:1; and wherein the polyamide composition demonstrates an un-notched Charpy impact energy loss at 23&#xb0; C. that is greater than 80 kJ/mand a tensile strength greater than 135 MPa.

Impact-modified injection-molded polyamide

A hydrolysis resistant polyamide composition comprising from 50 wt % to 80 wt % polyamide polymer having a theoretical amine end group content of at least 55 &#x3bc;eq/gram; and from 25 wt % to 60 wt % glass fibers. The weight ratio of polyamide polymer to glass fibers ranges from 0.5:1 to 4.0:1. The polyamide composition comprises less than 0.06 wt % copper; and/or from 1 ppb to 0.24 wt % non-copper metal halide compound. The polyamide composition, when hydrolysis aged for 500 hours at 130&#xb0; C., demonstrates an impact resilience greater than 40 kJ/m, as measured at 23&#xb0; C.

Hydrolysis resistant polyamides

The present disclosure relates to polyamide compositions and resulting injection-molded articles that can be plated, e.g., metal coated, to form aesthetic injection-molded articles. The polyamide compositions may include from 45 wt. % to 75 wt. % of an polyamide, from 2 wt. % to 40 wt. % of an etchable filler, from 10 wt. % to 40 wt. % of a semi-structural mineral, and optionally from 0.1 wt. % to 13 wt. % of additive. The polyamide composition imparts very good surface appearance to injection-molded articles that are substantially free of visual defects.

Polyamide compositions and plating applications thereof

The present disclosure relates to polyamide compositions and resulting injection-molded articles that can be plated, e.g., metal coated, to form structurally aesthetic injection-molded articles. The polyamide compositions may include from 40 wt. % to 80 wt. % of a polyamide, from 0.5 wt. % to 40 wt. % of an etchable filler, from 5 wt. % to 30 wt. % of glass fiber, optionally less than 40 wt. % of a semi-structural mineral, and optionally from 0.1 wt. % to 13 wt. % of additive. The polyamide composition imparts very good surface appearance and excellent mechanical properties to injection-molded articles that are substantially free of visual defects.

A method and apparatus that includes isolating a sample having a known volume and obtained near a reservoir that has a reserve; extracting hydrocarbons from the sample; and identifying data associated with the hydrocarbons. The data may include the volume of the extracted hydrocarbons. The method also includes using the data to estimate the reserve of the reservoir. The method can also include pulverizing the sample to release additional hydrocarbons.

Estimating a reserve of a reservoir

The present invention relates to compositions for treatment of subterranean formations including a curable resin that is amine-curable and a curing agent having a structure including at least one primary amine and at least one secondary amine, and methods of using the same. In various embodiments, the present invention provides a method of treating a subterranean formation. The method can include obtaining or providing a composition including a curable resin that is amine-curable and a curing agent having a structure including at least one primary amine and at least one secondary amine. The method can include placing the composition in a subterranean formation downhole.

Treating a subterranean formation with a composition having multiple curing stages

A treatment fluid is described suitable for use in subterranean formations comprising an aqueous phase, a carboxymethyl hydroxyethyl cellulose, and a breaker. The aqueous phase comprises water having at least 1,000 ppm total dissolved inorganic salts and at least one of: a sulfate concentration of about 4,000 ppm or greater, a phosphate concentration of about 100 ppm or greater, a carbonate concentration of about 100 ppm or greater, or a barium concentration of about 37,000 ppm or greater. The carboxymethyl hydroxyethyl cellulose has a carboxymethyl degree of substitution in the range of about 0.3 to about 0.45 per glucopyranose unit in the carboxymethyl hydroxyethyl cellulose polymer; and a hydroxyethyl molecular substitution in the range of about 2.1 to about 2.9 per glucopyranose unit in the carboxymethyl hydroxyethyl cellulose polymer; The treatment fluid is substantially free of any crosslinker.

Fracturing or gravel-packing fluid with CMHEC in brine

Treatment fluids (e.g., fracturing fluids) comprising ionic water, and associated methods of use are provided. In one embodiment, the methods comprise providing a treatment fluid comprising an aqueous base fluid comprising one or more ionic species, a polymeric viscosifying agent carrying a first ionic charge, and an ionic surfactant carrying a second ionic charge that is the opposite of the first ionic charge; and introducing the treatment fluid into a well bore penetrating at least a portion of a subterranean formation.

Enhanced subterranean treatment fluids in ionic water or seawater

A fracturing fluid and method of including a cellulose polymer derivative, a diol functional group, and a borate crosslinker. The diol functional group may be a cis-diol functional group, a 1,2-diol functional group, or a 1,3-diol functional group. The cellulose polymer derivative further may include a hydroxyethyl group or a hydroxypropyl group. The fracturing fluid may also include at least one metallic crosslinker. The method may also include the steps of adding a pH adjusting agent, at least one breaker, a surfactant, a scale inhibitor, and/or a bactericide to the fracturing fluid, or mixing the fracturing fluid using mixing equipment or wherein the fracturing fluid is introduced into a subterranean formation using one or more pumps.

Fracturing fluid

A diverter fluid having a carbon-containing particulate dispersed therein for controlling fluid flow within subterranean formations. The diverter fluid can be injected into a wellbore for formation of a filter cake by the carbon-containing particulate, and which disperses in hydrocarbons for return to the surface.

Diverter fluid diverter fluid

A method of treating particles of a particle pack located in a subterranean formation comprising: introducing an additive into the subterranean formation, wherein the additive: (i) comes in contact with the particles of the particle pack; (ii) has a chemical attraction to the particles of the particle pack; and (iii) comprises a first functional group, wherein the first functional group is a water-control agent.

Multi-functional additive for oil or gas operations

Processes for chemically removing cured resin product from surfaces and subterranean formations in case of inappropriate consolidation, plugging of screens or tubing, and equipment damage. A chemical solvent is introduced to a wellbore where a resin has cured. The resin is contacted with the chemical solvent until the resin at least partially dissolves. At least a portion of the dissolved resin is then removed from the wellbore.

Degrading and removing cured resins from substrates

Various embodiments disclosed related to compositions and methods of using the same for treating subterranean formations. In various embodiments, the present invention provides a method of treating a subterranean formation. The method includes placing in a subterranean formation a composition that includes a viscosifier and that also includes a hydrophobically-modified polymer including at least one nitrogen-containing repeating unit.

Composition including a viscosifier and a hydrophobically-modified polymer that includes a nitrogen-containing repeating unit for treatment of subterranean formations

Growing community of inventors

Richmond, TX, United States of America

Bradley James Sparks