Halliburton Energy Services, Inc.

Dipti Singh

Jeremy A Holtsclaw

Philip D Nguyen

Prashant Dinkar Chopade

Loan K Vo

Ubong Akpan Inyang

Aaron Gene Russell

Ali Alwattari

Travis Hope Larsen

Janette Cortez

Ronald Glen Dusterhoft

Jim D Weaver

Eli Allen Schnoor

B Raghava Reddy

Aaron Michael Beuterbaugh

James William Ogle

Enrique Antonio Reyes

Janette Cortez Montalvo

Michael Linley Fripp

Jimmie Dean Weaver, Jr

Thomas Donovan Welton

Anthony Herman Van Zuilekom

Srinath Madasu

Xiangnan Ye

Michael Wayne Sanders

Glenn S Penny

Michael A McCabe

Bradley James Sparks

Christopher R Parton

Matthew Lewis Lahman

Chandra Sekhar Palla-Venkata

Nathan Carl Schultheiss

Corneliu Stanciu

Lucas Kurtis Fontenelle

Samuel James Maguire-Boyle

HsinChen Chung

Syed Muhammad Farrukh Hamza

Yuntao Thomas Hu

Golchehreh Salamat

Melissa C Weston

Nathan Schultheiss

Gladys Montenegro Galindo

Evelyn F Hampton

Michael A Mccabe

Donald V Durbin

Prashant D Chopade

The present disclosure relates to subterranean formation operations and, more particularly, to embedded treatment fluid additives for use in subterranean formation operations. The embedded treatment additives may comprise an aqueous-soluble downhole reactive material embedded in a crosslinked polymeric solution to delay the reactivity of the aqueous-soluble downhole reactive material, thereby forming the embedded treatment additive, wherein the aqueous-soluble downhole reactive material is a solid.

Embedded treatment fluid additives for use in subterranean formation operations

Provided herein are methods systems and compositions of a fracturing fluid comprising an associative polymer and clay nanoparticles. A method may comprise: providing a fracturing fluid comprising: a carrier fluid; an associative polymer; and clay nanoparticles; and injecting the fracturing fluid into a subterranean formation at or above a fracture gradient.

Associative polymer fluid with clay nanoparticles for proppant suspension

A variety of systems, methods and compositions are disclosed. A method may comprise introducing a fracturing fluid into a subterranean formation, wherein the fracturing fluid comprises an aqueous based fluid, a proppant composition, an oxidizing breaker, and halloysite nanotubes, wherein the oxidizing breaker is positioned within the halloysite nanotubes; and reducing a viscosity of the fracturing fluid.

Excapsulation oxidizing breakers for downhole applications

A method comprises: deriving fluid properties that provide for suspension of particulate diverting agents using a 3-dimensional flow model and based on a downhole temperature and at least one size characteristic of the particulate diverting agents; identifying a treatment fluid composition that comprises a nanoparticulate suspending agent and achieves the fluid properties using a relationship between the treatment fluid composition and the fluid properties; and preparing a treatment fluid or a treatment fluid additive based on the treatment fluid composition.

Methodology for developing treatment fluid compositions to enhance near- and far-field diversion downhole

A method of propping created fractures and microfractures in tight formation. The method includes injecting into a wellbore a first pad fluid stage; injecting into the wellbore a second pad fluid stage; injecting into the wellbore a diverting agent; and injecting into the wellbore a main proppant slurry stage; wherein the first pad fluid stage includes an aqueous-based fluid at a rate above the fracturing gradient to create a fracture, wherein the second pad fluid stage includes an aqueous-based fluid and a low concentration of a proppant mixture including a slurry of small proppant materials and/or a slurry of conventional proppant materials to extend the fracture and open up secondary induced fractures, and wherein the main proppant slurry stage includes an aqueous-based fluid and a proppant with a larger size than the small proppant particles in the second pad fluid stage.

Methods of propping created fractures and microfractures in tight formation

System and methods for customizing fracturing fluids downhole for real-time optimization of micro-fracturing operations are provided. Downhole operating conditions are monitored during a micro-fracturing operation along a portion of a wellbore within a subterranean formation, based on downhole measurements collected by sensors of a downhole formation tester. Injection parameters for a fracturing fluid to be injected from a bulk storage chamber of the downhole formation tester into the subterranean formation are determined based on the downhole operating conditions. Signals for customizing the fracturing fluid using one or more fluid additives stored within corresponding fluid storage chambers of the downhole formation tester are transmitted to a controller of the downhole formation tester, based on the injection parameters. Injection of the customized fracturing fluid from the downhole formation tester into an area of the subterranean formation surrounding the portion of the wellbore is controlled during the micro-fracturing operation.

Downhole customization of fracturing fluids for micro-fracturing operations

Coil tubing cleanout fluids comprising a clay are provided. A method may comprise introducing a cleanout fluid into a wellbore wherein the cleanout fluid comprises a carrier fluid and a clay; and entraining solid particles in the cleanout fluid wherein the solid particles are disposed in the wellbore.

Coil tubing cleanout fluid

Provided are example methods and systems for treating a subterranean formation. An example method comprises alternately pumping a volume of proppant-laden fluid and a volume of spacer fluid into a wellbore penetrating a subterranean formation. The proppant-laden fluid comprises an aqueous fluid and proppant. The spacer fluid comprises an aqueous fluid. At least one of the proppant-laden fluid or the spacer fluid comprises a synthetic clay. The volume of proppant-laden fluid and the volume of spacer fluid may be pumped in any order. The method further comprises repeating the alternately pumping a volume of proppant-laden fluid and a volume of spacer fluid at least once.

Methods for improving channel formation

Methods and systems employing a flocculation polymer and microparticulates. The flocculation polymer flocculates the microparticulates to form micro-aggregates for use in forming complex fracture networks. Additionally, the flocculation causes the flocculation polymer to be removed from a treatment fluid due to its interaction with the microparticulates, thereby effectively cleaning the flocculation polymer from a subterranean formation. Individual microparticulates are synergistically used alone or in the presence of a de-aggregating agent to enhance complex fracture networks.

Micro-aggregates and microparticulates for use in subterranean formation operations

The composition provided herein includes an aqueous base fluid, a water-based polymer and glass microspheres comprising a metal cross-linking agent and where the water-based polymer cross-links in the presence of the glass microspheres.

Rheology modifier

A proppant suspension composition including a proppant, gelling agent, nanoparticles, at least one breaker, and a tackifying resin. The gelling agent may include cross-linkable polymers. The nanoparticles may be natural or synthetic clays. The at least one breaker may include oxidizers, monovalent salts and/or bis-quaternary ammonium compounds. The composition can be provided downhole during fracturing operations.

Nanoparticulate containing proppant suspension composition with breaker and aggregator

Methods and systems for treating a subterranean formation. The method comprises adding proppant particulates to a fluidized bed granulator; spraying a binding agent on the proppant particulates to at least partially coat the proppant particulates with the binding agent, wherein the coated proppant particulates form proto-aggregates; adding the proto-aggregates to a treatment fluid; and introducing the treatment fluid into a fracture within the subterranean formation.

Methods for controlling conductive aggregates

Compositions including modified release material for treatment of subterranean formations are provided. Also provided is a method of treating a subterranean formation including placing in the subterranean formation a composition including a modified release material. The modified release material can include an additive and a solid substituted or unsubstituted fatty acid having a melting point of about 30&#xb0; C. to about 250&#xb0; C., wherein the additive is partially or wholly enveloped by the fatty acid.

Compositions including modified release material for treatment of subterranean formations

Growing community of inventors

Kingwood, TX, United States of America

Dipti Singh