Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Oilfield Operations LLC

Baker Hughes Holdings LLC

Harold Gene Hudson

Harold Dean Brannon

D V Satyanarayana Gupta

Scott Gregory Nelson

Naima Bestaoui-Spurr

Mark Alan Vorderbruggen

Sandra L Berry

Ahmed M Gomaa

Qi Qu

Leiming Li

Jia Zhou

Sumit Bhaduri

Paul S Carman

Terry D Monroe

Frances H DeBenedictis

Windal Scott Bray

Dv Satyanarayana Gupta

Thomas Ray Starks, Ii

Dustin Palm

Jihye Kim

Elizabeth McCartney

Andrea Nino-Penaloza

A polymer-free fluid may be used to delay reaction of hydrofluoric acid with a subterranean formation. The fluid contains an organic compound having a bifunctional group, HF or a HF-generating compound, urea and an organophosphonate.

Method of treating a subterranean formation with delayed acid system

Sandstone formations of oil and gas and geothermal wells may be successfully stimulated with a fluid containing GLDA or salt and HF or a HF-generating component and an organophosphonate component. The organophosphonate acts as a sequestering agent and reduces the amount of metal fluoride precipitates produced.

Use of sequestering agent in GLDA-based treatments for siliceous formations

An embodiment of a method of evaluating fluid trapping in an earth formation includes injecting a water-based fluid into at least one fluid channel fabricated on a substrate, the at least one fluid channel having a pore structure configured to represent a condition of an earth formation. The method also includes injecting oil into an inlet of the at least one fluid channel until at least a selected amount of the injected oil exits the channel, imaging the fluid channel and determining an amount of remaining fluid in the fluid channel after injection of the oil, the remaining fluid being an amount of the oil and/or an amount of the water-based fluid, and estimating a proportion of the total volume of the fluid channel occupied by the remaining fluid to determine an amount of fluid trapping in the pore structure. The method further includes analyzing the amount of fluid trapping.

Fluid blocking analysis and chemical evalution

A method of improving the flow of a proppant pack or gravel pack comprises: introducing into a subterranean formation or a well a plurality of ceramic particles, the ceramic particles comprising about 0.1 wt. % to about 25 wt. % of a rare earth-containing compound, based on the total weight of the ceramic particles; and forming a proppant pack or gravel pack comprising the plurality of the ceramic particles; wherein the proppant pack or gravel pack improves fluid flow as compared with a reference proppant pack or gravel pack formed from otherwise identical ceramic particles except for being free of the rare earth-containing compound.

Rare earth materials to enhance properties of ceramic particles

A method of hydraulically fracturing a subterranean formation penetrated by a wellbore comprises: providing a diverting fluid comprising a carrier fluid, a first superabsorbent polymer and a second superabsorbent polymer, the second superabsorbent polymer having a shape, or a composition, or a combination thereof different from that of the first superabsorbent polymer; injecting the diverting fluid into the subterranean formation; and injecting a fracturing fluid into the formation after injecting the diverting fluid. A viscosity modifying agent can be present in the diverting fluid. Superabsorbent polymers can also be used to develop a temporary filter cake at the formation face to reduce or eliminate the fluid leakoff out of the wellbore.

Use of superabsorbent polymers for pressure control and diversion applications

The flow of well treatment fluids may be diverted from a high permeability zone to a low permeability zone within a fracture network within a subterranean formation by use of a divert system comprising dissolvable diverter particulates and proppant. At least a portion of the high permeability zone is propped open with the proppant of the divert system and at least a portion of the high permeability zone is blocked with the diverter particulates. A fluid is then pumped into the subterranean formation and into a lower permeability zone of the formation farther from the wellbore. The diverter particulates in the high permeability zones may then be dissolved at in-situ reservoir conditions and hydrocarbons produced from the high permeability propped zones of the fracture network. The divert system has particular applicability in the enhancement of production or hydrocarbons from high permeability zones in a fracture network located far field from the wellbore.

Method of enhancing fracture complexity using far-field divert systems

A well treatment composite is characterized by particulates wherein at least a portion of the substrate of the particulates is coated with a polycationic polymer. The presence of the polycationic polymer on the surface of the well treatment particulates reduces the generation of dust and fines during a well treatment operation. The polycationic polymer further reduces the amount of dust or fines generated during transport of the well treatment particulates to a remote location as well during the manufacture or processing of well treatment particulates.

Method of reducing dust with particulates coated with a polycationic polymer

Loss of wellbore fluids (such as drilling fluids, completion fluids and workover fluids) into the flow passages of a subterranean formation may be reduced or eliminated by introducing into the wellbore in communication with the formation a composition containing a composite of a deformable core having a hardened coating which contains a viscosifying agent and, optionally, a crosslinking agent. The viscosity of the composition increases in-situ as the viscosifying agent, and optional crosslinking agent, disassociate from the deformable core and react. A fluid-impermeable barrier is thereby formed. The composites may also be used in spacers, well cements, workover and completion fluids as their need arises.

Use of composites having deformable core and viscosifying agent coated thereon in well treatment operations

A composite is characterized by particulates of sand wherein at least a portion of the surface of the particulates is coated with a polycationic polymer. The presence of the polycationic polymer on the surface of the particulates reduces the amount of dust generated during handling and use of the sand. The polycationic polymer further reduces the amount of dust generated during transport of the sand as well during manufacture, treatment or processing of the sand.

Methods of using sand composites to control dust

A method for building a plug in a horizontal wellbore using a fluid pill containing a suspended well treatment composite. The well treatment composite contains a core comprising at least one deformable particulate and at least one dissolvable diverter. At least a portion of the surface of the core is coated with at least one viscosifying polymer and at least one crosslinking agent. The fluid pill is pumped into the wellbore at the end of a fracturing treatment and the fluid pill may be displaced by a displacement fluid. The fluid pill may be diverted to an area of lower permeability by disassociating the dissolvable diverter from the core. The disassociated diverter blocks an area of higher permeability. The sized particle distribution of the diverter is sufficient to at least partially block the penetration of fluid into the high permeability zone. In the lower permeability zone, a thickened gel is formed by the in-situ reaction of the viscosifying polymer and crosslinking. Deformable particulates in the gelled fluid form a bridge plug.

Method for improving isolation of flow to completed perforated intervals

A method for building a plug in a horizontal wellbore using a fluid pill containing a suspended well treatment agent. The well treatment agent contains an ultra lightweight (ULW) deformable core and a viscosifying polymer and crosslinking agent coated onto the core. The fluid pill is pumped into the wellbore at the end of a fracturing treatment. The fluid pill is displaced by a displacement fluid and the fluid pill transforms to a thickened gel. The thickened gel is formed by the in-situ reaction of the viscosifying polymer and crosslinking which become disassociated from the ULW deformable core. The gelled fluid containing the ULW deformable core assists in the bridging of the ULW deformable core and forming the bridge plug.

Growing community of inventors

The Woodlands, TX, United States of America

Harold Gene Hudson