Halliburton Energy Services, Inc.

Lyondellbasell Advanced Polymers Inc.

Magnablend, Inc.

Halliburton Company

A. Schulman, Inc.

Carbo Ceramics Inc.

Texas United Chemical Company, LLC

Bradley Leon Todd

Thomas Donovan Welton

Trinidad Munoz, Jr

Rajesh Kumar Saini

Ronald J Powell

David Eugene McMechan

Stanley J Heath

Gary P Funkhouser

Robert S Taylor

Michael M Brezinski

Thomas Wayne Ray

Gregory B Chitwood

John C Gano

Ralph Harvey Echols

Marion Dewey Kilgore

Cynthia Strickland Tuckness

Richard W Pauls

Keith A Frost

Philip D Nguyen

Ronald Glen Dusterhoft

Larry Steven Eoff

Billy F Slabaugh

Baireddy R Reddy

William David Henderson

Russell M Fitzgerald

Dennis Willie Gray

Ian D Robb

Ronald J Crook

Jody Ray McGlothen

Michael N Mang

Mark R Savery

Paul I Herman

Karen Savery

Roger Lynn Schultz

B Raghava Reddy

Jimmie Dean Weaver, Jr

Craig Wayne Roddy

Ashok K Santra

Feng Liang

Michael Wayne Sanders

Jeff T Fleming

Steven B Laramay

Alex Procyk

Raynard Rene Veldman

Amy Lyn Brooks

David Joe Steele

Luke William Holderman

Donald Lee Whitfill

Loren C Swor

Phillip M Starr

James Van Fisk, Jr

David W Ritter

James D Kercheville

Diptabhas Sarkar

Ivan M Suleiman

Charles J Busceme

Kristie Ince

Trinidad Munoz

Jiten Chatterji

Jim Basuki Surjaatmadja

Bobby J King

William Walter Shumway

James William Ogle

Kenneth L Schwendemann

Jason E Bryant

J Michael Wilson

Robert E Hanes, Jr

Loyd Eddie East

David Michael Loveless

Ronney R Koch

Jimmie B Lawson

Mark A Parker

Joseph G Yaritz

Keith A Rispler

David B Allison

Eric Davidson

Audis C Byrd

Kim O Tresco

Lyle Lehman

Jorge M Fernandez

Stephen T Arrington

Donald M Justus

Don Conkle

Alan W Moorehead

William W Pattison, Jr

Eric Davudson

Connie R Todd

Ki Cherryl Whitt, Legal Representative

Corine McMechan, Legal Representative

Bessie Q Citrowske

James M Griffin

Ashley Donaldson

David E Mcmechan

James W Dobson

David Mcmechan

Completion fluid compositions designed for fluid loss control in a subterranean formation. In particular, the compositions comprise an aqueous base fluid, a suspension polymer, a fluid loss control additive, and a degradable bridging agent. The completion fluid compositions provide a way to temporarily seal a wellbore communicating with a subterranean formation and enables completion or workover operations to be performed, after which the composition can be removed by contact with a mild clean-up composition.

Bridging particle and fluid loss control agent

Drill-in fluids disclosed herein comprise an aqueous base fluid, a viscosifier, a fluid loss control additive, and a degradable bridging agent comprising a degradable high strength polymetaphosphate material capable of undergoing an irreversible degradation downhole. The present disclosure further relates to a method for controlling fluid loss through a subterranean surface by using the drill-in fluid for form a filter cake on the subterranean surface. Also provided is a method of degrading a filter cake with an aqueous fluid or aqueous acidic fluid, wherein the filter cake is produced from the drill-in fluid. Further provided is a specific order of addition of constituents of the drill-in fluid, which results in improved filter cake performance and/or filter cake removal.

Drill-in fluid compositions and methods

Novel completion fluid compositions for fluid loss control during completion and workover operations conducted on a wellbore penetrating a subterranean formation are disclosed. In particular, the composition is a weighted brine fluid having a polymetaphosphate composition, a biopolymer suspension agent, and a fluid loss control additive. These novel compositions provide a means to temporarily seal a wellbore communicating with a subterranean formation to enable completion or workover operations to be performed, after which the composition can be removed by contact with an acidic composition.

Weighted fluid loss control pill for completion and workover operations

Viscous degradable fluids for use in fluid loss control, diversion, gravel packing, fracturing, and acidizing operations, method of preparing the viscous degradable fluids, and methods of using the viscous degradable fluids in subterranean operations. At least one aliphatic polyester is dissolved in a solvent comprising triacetin to form a viscous degradable fluid. The viscous degradable fluid can be injected directly into a subterranean formation or mixed with other fluids and/or additives before being injected into the subterranean formation, where it can temporarily block or restrict flow through openings in the formation.

Degradable aliphatic polyester fluid

Treatment fluids for use in fluid loss control, diversion, and plugging operations and methods of use are disclosed. The treatment fluids contain a degradable particular langbeinite material that temporarily creates a physical barrier to fluid flow before degrading over time with little to no effect on the environment. This degradable additive can be combined with other traditional downhole additives such as surfactants, viscosifying agents, biocides and the like, allowing for a wide variety of applications in hydrocarbon reservoirs.

Low temperature diversion in well completion operations using natural mineral compound

A polymetaphosphate composition and method for temporarily sealing a perforation in a wellbore to facilitate a treatment therein and a well tool which can include a flow path, and a flow blocking device which selectively prevents flow through the flow path. The well tool can include a polymetaphosphate composition. A method of constructing a downhole well tool can include forming a structure of a solid mass comprising a polymetaphosphate composition, and incorporating the structure into the well tool.

High strength dissolvable compositions for use in subterranean wells

Provided is a method of treating a subterranean formation comprising: preparing a well servicing fluid comprised of a base fluid, a temporary compacted material wherein the temporary compacted material is a compacted organic acid; placing the well servicing fluid into a subterranean formation; and allowing the temporary compacted material to gradually dissolve.

Methods and compositions for using temporary compacted materials as well servicing fluids in a subterranean formation

The present disclosure provides methods for identifying chemical diverter material placed in a borehole region and provides chemical diverter material. In one embodiment, a method for detecting diverter material placed in a borehole region includes (a) obtaining a first data set by: emitting pulses of neutrons from the pulsed neutron source into the borehole region and detecting capture gamma rays resulting from nuclear reactions in the borehole region; (b) placing a diverter material comprising aqueous-swellable particles and a thermal neutron absorbing material into the borehole region; (c) obtaining a second data set by: emitting pulses of neutrons from the first pulsed neutron source or a second pulsed neutron source into the borehole region, and detecting capture gamma rays in the borehole; and (d) comparing the first data set and the second data set to determine the location of diverter material placed in the borehole region.

Tagged chemical diverter

Methods, fluids, and compositions are provided for treating subterranean formations. The fluids can be servicing or drilling fluids including a base fluid and a particulate agent or biocide precursor particulate agent. The particulate agent can seal flow paths in the subterranean formation and subsequently can be degraded to allow flow to resume. The particulate agent may be a reaction product of a urea containing compound and an aldehyde containing compound. An example of such a reaction product is a methylene urea.

Methods and compositions for using temporary, slow degrading, particulate agents in a subterranean formation

Diverting compositions for treating a subterranean zone substantially distanced from a wellbore, comprising: a carrier fluid; and a particulate, partially dehydrated or anhydrous borate source material that does not substantially swell when placed in contact with the carrier fluid. The carrier fluid is capable of carrying and placing the borate source material into a stimulation network substantially distanced from a wellbore, and wherein the borate source material is dissolvable through sufficient contact with an aqueous fluid. The carrier fluid is a water-miscible non-aqueous fluid selected from the group consisting of ethylene glycol, propylene glycol, N,N- dimethylformamide, tetrahydrofuran, dichloromethane, 1,4-dioxane, dimethylsulfoxide, tetramethylenesulfone, acetonitrile, hexamethylphosphoramide, 1,3-methyl-3,4,5,6-tetrahydro- 2(1H)-pyrimidinone, propylene carbonate, ethylene carbonate, and combinations thereof.

Far field diversion technique for treating subterranean formation

A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%. Similar methods using stepwise fracturing fluids and remedial fracturing treatments are provided.

Increasing fracture complexity in ultra-low permeable subterranean formation using degradable particulate

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Duncan, OK, United States of America

Bradley Leon Todd