Halliburton Energy Services, Inc.

Chevron U.s.a. Inc.

Multi-chem Group, LLC

William Walter Shumway

Dale E Jamison

Jay Paul Deville

Preston Andrew May

Cato Russell McDaniel

Hui Zhou

Donald Curtis Van Slyke

Jeffrey James Miller

Kay Ann Galindo

Chesnee Lae Davis

Timothy Neal Harvey

Philip Wayne Livanec

Kenneth William Pober

Eric Davidson

Pubudu Gamage

Jessica Paola Ramirez Angulo

William Cecil Pearl, Jr

Daniel David Gleitman

Sandeep D Kulkarni

Charles R Landis

Weibin Zha

Catherine Martin Santos

David L Carbajal

Kingsley Ihueze Nzeadibe

Li Guo

Miren Aranzazu Castanares

Alfredo Villarreal, Jr

Alfredo M Angeles-Boza

Alan W Moorehead

Christopher Michael Jones

Bradley Leon Todd

Songhua Chen

Enrique Antonio Reyes

Anthony Herman Van Zuilekom

Rahul Chandrakant Patil

Darren George Gascooke

Matthew Lynn Miller

Michel Joseph LeBlanc

Xiangnan Ye

Ian D Robb

Denise Nicole Benoit

Lee Jeremy Hall

Vikrant Bhavanishankar Wagle

Ronald Johannes Dirksen

Shadaab Syed Maghrabi

Sunita Sameer Kadam

Jeff Kirsner

Ryan G Ezell

Brice Aaron Jackson

Ronald Oliver Bosch

Katerina V Newman

Kevin Gregory Kleinguetl

Adam Dotson

Antonio Recio

Lawrence Joseph Herskowitz

Nivika Rajendra Gupta

Alexandra Clare Morrison

Marcus Ray Hudson

Sharad Bhimrao Gotmukle

Brian Alan Evans

Magdalena Sandor

Pramod Chamarthy

Jason Glen Bell

Mahesh Vijay Biyani

Kimberly Jo Burrows

Kenneth W Oyler

Sergey Sheyko

Jody L Maresh

Stephen A Bell

Xiaobo Hu

Troy Francis Davis

Jose Luis Carvalho Mota

Frederick Thomas Brown

Emily Hart

Rocio Macarena Moyano Dip

Vladimir Gankin

Cato R Mcdaniel

Alfredo Villarreal

Cato Russell Mcdaniel

Pubudu H Gamage

Pubudu Hasanka Gamage

Jeffery J Miller

Timothy Harvey

A water-based drilling fluid can include a first and second viscosifier of a cross-linked starch and a cross-linked acrylamide-based polymer. The acrylamide-based polymer can be crosslinked and optionally include hydrophobic monomers. The viscosifiers create a synergistic effect that imparts desirable properties to the drilling fluid compared to using either of the viscosifiers alone. The viscosifiers can be used as an alternative to other types of viscosifiers such as xanthan gum.

Synergistic viscosifiers for clay-free, water-based drilling fluids

A treatment fluid can include a base fluid and a stabilizing additive. The stabilizing additive can include a plurality of environmentally acceptable nanoparticles. The particle size distribution of the plurality of nanoparticles can be selected such that the nanoparticles stabilize a wellbore wall of a subterranean formation or form a filtercake to inhibit or prevent fluid loss into permeable areas of the formation. The plurality of nanoparticles can have a particle size distribution of a d10 value in the range of 20 to 45 nanometers, a d50 value in the range of 40 to 80 nanometers, and a d90 value in the range of 80 to 140 nanometers. The plurality of nanoparticles can also be coated with a polymeric shell. The treatment fluid can be used in an oil and gas operation.

Environmentally acceptable wellbore stability additive

A method may include: introducing a treatment fluid into a production fluid disposed in a surface well system, the treatment fluid comprising: a base fluid; and a supramolecular host guest product comprising: a treatment fluid additive comprising a surfactant; and a supramolecular host molecule, wherein the supramolecular host molecule is not covalently bonded to the treatment fluid additive; introducing the production fluid containing the treatment fluid into a production facility separator; and separating, in the production facility separator, at least a portion of the production fluid to form a water stream.

Supramolecular host guest product concentrators for production fluids

An apparatus, that is part of a drill string for drilling a wellbore in a subsurface formation, comprises a drill bit that includes at least one electrode coupled to a power source, the at least one electrode to periodically emit an electrical discharge based on electrical pulses received from the power source; and a first port to output a first type of drilling fluid having a different composition than a second type of drilling fluid to flow downhole for removal of cuttings, wherein the electrical discharge is to be transmitted through the first type of drilling fluid and through a rock of the subsurface formation.

Pulsed power drilling with multiple selective drilling fluids

Methods and systems for managing dielectric properties of a pulsed power drilling fluid are provided. In one embodiment, the methods include introducing a drilling fluid into a drilling pipe that extends into a portion of a wellbore; separating the drilling fluid into a solids rich portion and a solids lean portion in the drilling pipe at a location proximate to a pulsed power drill bit; allowing the solids lean portion of the drilling fluid to flow through the pulsed power drill bit; and drilling at least a portion of a wellbore. In some embodiments, the methods and systems include passing the drilling fluid through one or more hydrocyclones. In some embodiments, the methods and systems include passing the drilling fluid through one or more centrifuges.

Managing dielectric properties of pulsed power drilling fluids

Systems and methods using: a membrane unit to treat fluids recovered from an oil and gas well are provided. The membrane unit may include a membrane having a porous substrate at. least partially coated with graphene oxide, making the membrane hydrophilic. The membrane separates water from other components within a fluid stream. The membrane unit may include an inlet to receive a fluid stream into the membrane unit. The fluid stream may be pretreated prior to reaching the membrane unit The membrane unit may also include a first outlet in fluid communication with one side of the membrane and a second outlet in fluid communication with the opposite side of the membrane.

Treating fluids recovered from well operations using a graphene oxide coated membrane

Methods and compositions for use in the inhibition of the formation of gas hydrate agglomerates are provided. In some embodiments, a method is provided that includes: providing an emulsion drilling fluid including: a continuous phase including a non-oleaginous fluid; an internal phase including an oleaginous fluid; and a thermodynamic hydrate inhibitor; and drilling at least a portion of a wellbore penetrating a subterranean formation.

Low density hydrate inhibitive fluids

Methods for manufacturing lost circulation material particulates that may be for use in treating a subterranean formation are provided. In some embodiments, the methods include providing at a well-site a feed vessel that contains a liquid material, the liquid material including a monomer and an initiator; providing an injection device disposed underneath the feed vessel for directing at least a portion of the liquid material from the feed vessel to a reaction chamber, wherein the reaction chamber includes a fluid; discharging at least a portion of the liquid material from the feed vessel to the reaction chamber through an orifice disposed on the injection device; and forming LCM particulates at least in part by allowing at least a portion of the liquid material to polymerize in the fluid in the reaction chamber.

Methods of manufacturing lost circulation material at a well site

Systems and methods for separating paramagnetic material in wellbore return fluid. A quadrupole magnet system is disposed along conduit so that a paramagnetic field is symmetrically formed about a central axis of the conduit. A wellbore return fluid containing paramagnetic material is directed through the conduit. The paramagnetic field drives the paramagnetic material outward towards the perimeter of the conduit, thereby concentrating fluid with little or no paramagnetic material along the central axis of the conduit. An outlet is disposed along the flow path of a portion of the concentrated fluid. In some embodiments, the outlet is positioned along the central axis, while in other embodiments, the outlet is positioned along the conduit wall. The paramagnetic material may be weighting material used to prepare drilling mud.

System to manage wellbore servicing fluids containing paramagnetic materials

The present disclosure relates to a pulsed-power drilling system that includes downhole mixers for restoring optimal electrical properties in drilling fluid. The downhole mixer may include a housing having an uphole and downhole end, a channel to convey the drilling fluid through the housing, and a flow restrictor including an orifice having a fixed diameter positioned in the channel between the entrance and the exit of the channel to create a pressure drop between the entrance and the exit of the channel during a drilling operation. The pressure drop increases shear stress in the drilling fluid to manage electrical properties, such as a dielectric constant, of the drilling fluid. The electrical properties of the drilling fluid facilitate the formation of an electrical arc on a drill bit of the pulsed-power drilling system.

Pulsed-power drilling fluid property management using downhole mixer

A method of drilling is disclosed that includes introducing a water-based drilling fluid into a drill string disposed within a wellbore, circulating the water-based drilling fluid through the drill string and the wellbore, and extending the wellbore using the drill string while circulating the water-based drilling fluid, wherein the water-based drilling fluid includes water and a lubricating additive including a de-oiled cake, wherein the de-oiled cake are residues obtained after extraction of oil from a plant source, wherein the de-oiled cake is in particulate form having a particle size of 100 microns or less. A composition is disclosed that includes water-based drilling fluid including water and a lubricant additive comprising a de-oiled cake, wherein the de-oiled cake are residues obtained after extraction of oil from a plant source and wherein the de-oiled cake has a particle size of 100 microns or less.

Sustainable solid lubricant for drilling fluid

The present disclosure provides methods, compositions, and systems directed to filter cake removal embodying a delayed breaker fluid for oil-based drill-in fluids. A wellbore treatment method comprising: introducing a delayed breaker fluid into a wellbore, wherein the delayed breaker fluid comprises an aqueous base fluid, an acid precursor, and a carbodiimide; and contacting a filter cake in the wellbore with the delayed breaker fluid such that the filter cake is at least partially degraded by acid released from the acid precursor.

Breaker additives for extended delay in removal of oil-based filter cakes

The disclosure provides a method for determining a composition of a fluid. The method comprises diverting a sample of a portion of the fluid to a test chamber. The method further comprises actuating a heat source disposed around the test chamber to increase the temperature within the test chamber to produce vapors from the sample of the portion of the fluid and directing the vapors from the sample of the portion of the fluid to a chemical sensor array comprising one or more chemical sensors. The method further comprises determining a composition of the vapors from the sample of portion of the fluid, wherein the composition of the vapors is associated with the composition of the fluid.

Methods to use chemo-resistive sensors for wellbore production

Provided is a method for mitigating a lost circulation zone. The method may include providing a lost circulation treatment composition that may include an acid responsive polymer that may include at least one monomer, at least one comonomer, and at least one crosslinker; a carbonate-based solvent; and a carrier fluid that may include water. The method may also include introducing the lost circulation treatment composition into a wellbore within a subterranean formation, wherein the subterranean formation may include the lost circulation zone; placing the lost circulation treatment composition into the lost circulation zone, hydrolyzing the carbonate-based solvent to generate carbon dioxide, and causing the swelling (change of shape) of acid responsive polymer to mitigate the losses.

Stimuli responsive polymers for lost circulation applications

Growing community of inventors

Spring, TX, United States of America

William Walter Shumway