Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Milchem Incorporated

Other

Baker Hughes Oilfield Operations LLC

Baker Hughes Holdings LLC

Dennis K Clapper

William S Halliday

Ronald Gene Bland

Alphonse C Perricone

Tao Xiang

Michael A Jarrett

Darrell P Salisbury

Dorothy P Enright

David W Schwertner

James E Norfleet

Mark R Smalling

Reza Ettehadi Osgouei

Rosa Swartwout

Michael J Otto

Lirio Quintero

Calvin J Stowe

Aaron Hammer

Qusai Darugar

Jianzhong Yang

John Barton Weirich

Thomas G Dahl

Roland May

William M Dye

Billy G Chesser

Geoffrey Robinson

Nyal S Walker

Joseph J Arensdorf

Wen Shao Cao

Kalyan C Singamshetty

Grant Mackenzie

Donald C Krause

Alyssa Renee Garcia

Justin Thomas Porter

Michelle Carr

Ian L Everhard

Saddock Benaissa

Shannon Stocks-Fischer

William R Bradford, Jr

William Halliday

A stabilized water-dispersible latex additive useful in both freshwater-based and brine-based drilling fluids, may be formed by mixing an effective amount of a compound containing at least one pyrrolidone ring, such as, polyvinylpyrrolidone, a vinylpyrrolidone-vinyl acetate copolymer, poly(1-vinylpyrrolidone-co-2-dimethylaminoethyl methacrylate), a vinylpyrrolidone-acrylic acid copolymer, and combinations thereof, with the water-dispersible latex additive before or after the water-dispersible latex additive is introduced to the drilling fluid.

Stabilized water-dispersible latex additives for drilling fluids

Examples of techniques for performing a wellbore construction operation in a wellbore are disclosed. In one example implementation according to aspects of the present disclosure, a computer-implemented method includes: performing a rheology test on a test fluid, the test fluid being representative of a fluid pumped through the wellbore, to generate test fluid data; performing, by the processing device, a data analysis on the test fluid data to generate at least one parameterized correlation; measuring a first property of the fluid to generate measured data; calculating, by the processing device, a second property of the fluid in the wellbore by using the parameterized correlations and the measured data to generate calculated data; and changing a parameter of the wellbore construction operation based at least in part on the calculated data.

In-situ rheology behavior characterization using data analytics techniques

An effective amount of amphiphilic star polymers and surfactants may be applied to downhole fluids containing oil-in-water and water-in-oil emulsions, such as drilling fluids, completion fluids, drill-in fluids, workover fluids, and remediation fluids, to stabilize the emulsions and improve rheological properties of these fluids for use in oil and gas production operations. The star polymers and surfactants may be applied to the downhole fluid separately or as a blend to generate emulsions within the fluid that have substantially uniform droplet size.

Star polymers and methods of use for downhole fluids

A method of drilling and completing a wellbore in a subterranean formation comprises circulating an invert oil emulsion fluid in the subterranean formation; the invert oil emulsion fluid comprising an oil phase, an emulsifier, and an internal phase comprising an alcohol other than a polycyclicpolyetherpolyol with molecular weight in excess of 50,000 and a salt dissolved in the alcohol, wherein the alcohol and the salt are selected such that the salt has a solubility in the alcohol of greater than about 3 g/100 ml at 23&#xb0; C.

Invert emulsions having a non-aqueous based internal phase containing dissolved salts

A method for introducing an organic drilling fluid additive into an aqueous drilling fluid in a subterranean formation, where the method includes introducing loaded microparticles into an aqueous drilling fluid. The loaded microparticles are made by absorbing at least one organic drilling fluid additive onto hybrid calcium carbonate microparticles to form loaded microparticles. The method further includes delivering the drilling fluid into a subterranean formation, and optionally shearing the loaded microparticles to release the absorbed drilling fluid additive(s) into the drilling fluid, such as by shearing them at the drill bit.

Liquid loaded powders made from hybrid calcium carbonate for oil and gas drilling fluids

Capped nanoparticles may be added to an oil-based fluid to improve the electrical conductivity of the oil-based fluid. The oil-based fluid may be a drilling fluid, a completion fluid, a drill-in fluid, a stimulation fluid, a servicing fluid, and combinations thereof. In a non-limiting embodiment, the oil-based fluid composition may be circulated in a subterranean reservoir wellbore.

Electrically conductive oil-based fluids

Polymer-modified asphalt is used in drilling fluids for filtration control, lost circulation control, drill string differential sticking prevention, or wellbore stabilization. The latex modified asphalt provides a mixture of latex-asphalt complex, asphalt, and latex particles that help maintain wellbore stability while drilling into shale formations. The polymer-modified latex is effective for controlling laminated and microfractured shale. Polymers may be functionalized to react with the asphalt to create copolymer modifications of the asphalt for improved performance as drilling fluid additives. The drilling fluids may be water-based or oil-based, or based on an emulsion of oil and water.

Polymer-modified asphalt for drilling fluid applications

Adding a lubricant having a metal stearate and polytetrafluoroethylene (PTFE) to a downhole fluid may lubricate a first surface once the downhole fluid has been circulated within a subterranean reservoir wellbore. Friction, torque, and/or drag may be reduced when the lubricated first surface contacts a second surface. The first surface may be or include, but is not limited to a wellbore casing, a drill string, a pipe, a formation, a drill bit, a metal surface within a mud motor, formation evaluation tool, at least one drilling tool, and combinations thereof. One or both of the first and second surfaces may be metal. The downhole fluid may be or include, but is not limited to, a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof.

Lubricating compositions for use with downhole fluids

A method for estimating a depth from which cuttings have been recovered from a well may include varying a parameter of one or more marking agents added into a drilling fluid circulated into the well and recovering the cuttings from the well. The depth may be estimated by estimating a value associated with the marking agent that marks the cuttings. A system for estimating a depth from which cuttings have been recovered from a well includes at least one marking agent configured to mark the cuttings and a marking agent dispensing device configured to add the at least one marking agent into a drilling fluid circulated into the well. The marking agent dispensing device may be further configured to vary a parameter of the at least one marking agent.

Estimating drill cutting origination depth using marking agents

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.

Method for lubricating and/or reducing corrosion of drilling equipment

A drilling fluid has a redispersible polymer powder introduced as a water dispersion that is capable of providing a deformable latex film on at least a portion of a subterranean sand formation and which inhibits or controls fluid loss and acts as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. The redispersible polymer powder may be made by drying the emulsion in which they are formed and then grinding into a powder or by spray drying. The polymer particles of suitable size precipitate or collect or assemble onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.

Drilling fluids with redispersible polymer powders

Latex additives, methods for treating latex additives, drilling fluid systems, and lost circulation pills comprising the latex additives, the latex additive comprising latex particles having a particle size distribution before aging comprising an average particle diameter of about 1 micron or less; and a quantity of one or more water soluble oxygenated organic molecules comprising two or more oxygen atoms effective to maintain substantially the same particle size distribution before and after freezing the latex additive.

Method and drilling fluid systems and lost circulation pills adapted to maintain the particle size distribution of component latex particles before and after freezing of the latex particles in the presence of water

A method and drilling fluid system for providing filtration control during drilling operations using a drilling fluid system comprising water soluble polymer comprising acrylamide monomer, the method comprising: providing a drilling fluid system having effective rheological properties, the drilling fluid system comprising aqueous base consisting essentially of freshwater, a quantity of from about 21 to 58 kg/m(7.5 to about 20 pounds per barrel) plugging agent, and an amount of bridging agent comprising water soluble polymer comprising acrylamide monomer which exhibits a 5% by weight Brookfield viscosity in freshwater of from about 50 cP to about 100 cP, and; contacting a subterranean formation with the drilling fluid system and maintaining effective filtration control at concentrations of about 10,000 ppm or less monovalent salt, as demonstrated in the laboratory by producing a HPHT filtrate of 25 cm/min or less after 30 minutes at about 149&#xb0; C. (300&#xb0; F.) after static aging of said drilling fluid system for a period of 16 hours or more at temperatures of about 260&#xb0; C. (500&#xb0; F.).

High temperature filtration control using water based drilling fluid systems comprising water soluble polymers

A water-based drilling fluid having a polymer latex capable of providing a deformable latex film on at least a portion of a subterranean formation has been discovered to provide reduced drilling fluid pressure invasion when used to drill in shale formations for hydrocarbon recovery operations. A precipitating agent such as a silicate or an aluminum complex (e.g. sodium aluminate) is preferably used in conjunction with the polymer. Typically, the water present contains a salt to form a brine, often to saturation, although the invention may be practiced with fresh water. If a salt is employed, it is often helpful to additionally employ a surfactant, such as a betaine, for example.

Water-based drilling fluids using latex additives

An oil-based drilling fluid having a polymer latex capable of providing a deformable latex film on at least a portion of a subterranean sand formation has been discovered to inhibit or control fluid loss and act as a sealing agent when used to drill in sand formations for hydrocarbon recovery operations. Typically, the polymer latex is an aqueous suspension of particles formed by emulsion polymerization that is in turn emulsified into a hydrocarbon base fluid. The polymer particles of suitable size precipitate onto the pores of a subterranean sand formation to at least partial seal the formation with a deformable polymer film.

Fluid loss control and sealing agent for drilling depleted sand formations

Growing community of inventors

Houston, TX, United States of America

Dennis K Clapper