Halliburton Energy Services, Inc.

Halliburton Company

Ricky Layne Covington

Craig Wayne Roddy

Jiten Chatterji

D Chad Brenneis

Krishna M Ravi

Lonnie Carl Helms

Michael Linley Fripp

Calvin Lynn Stegemoeller

Rahul Chandrakant Patil

Sandip Prabhakar Patil

Frank Vinicio Acosta

James R Longbottom

Nicholas Frederick Budler

Timothy Rather Tips

Darrell Chad Brenneis

Stephen F Crain

Wayne A Handke

David W Ritter

John Key

Paul O Padgett

Kevin D Edgley

Jerry L Logan

Bobby J King

Carl Joseph Thaemlitz

Sairam K S Pindiprolu

Shobeir P Gar

Sairam Ks Pindiprolu

Gavin Graff

A wiper dart having a bi-diameter wiper cup can be used to help track the location of the dart in a pipe string. As the wiper dart is pumped through the pipe string, a first mean pump pressure will exist as the wiper cup travels through drill pipe sections having a larger inner diameter than a tool joint and a second mean pump pressure will exist as the wiper cup travels through the tool joints. The wiper cup can have a geometric shape selected such that a detectable pressure spike can be observed when the wiper cup reaches a transition section located between one end of a pipe section and the tool joint. By counting the number of pressure spikes, an operator can accurately track the location of the wiper dart as it is being pumped through the pipe string.

Tracking a wiper dart having a bi-diameter wiper cup in a wellbore using pressure spikes

A method for measuring parameters related to wellsite operations comprises mixing Micro-Electro-Mechanical System (MEMS) sensors with a wellbore servicing composition in surface wellbore operating equipment. The MEMS sensors are assigned a unique identified that may be used to track individual MEMS sensor as the MEMS sensors travel through the wellbore and may be used to correlate sensor measurements taken by the MEMS sensors with particular locations in the wellbore. The MEMS sensors may be active and transmit their respective identifiers and sensor data to the surface. Transmitting identifier and sensor data from a MEMS sensor to the surface wellbore operating equipment may be via one or more other MEMS sensors, downhole devices, and surface devices.

Monitoring downhole parameters using MEMS

The present invention includes well treatment fluids and methods utilizing nano-particles and, in certain embodiments, to sealant compositions and methods utilizing nano-particles. The nano-particles may be incorporated into the sealant composition in different forms, including as discrete nano-particles, encapsulated nano-particles, agglomerated nano-particles, or in a liquid suspension.

Sealant compositions and methods utilizing nano-particles

A method comprising placing a composition comprising a wellbore servicing fluid and a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, whereby the MEMS sensor is coated with an elastomer. The elastomer-coated MEMS sensor is used to detect one or more parameters, including a compression or swelling of the elastomer, an expansion of the elastomer, or a change in density of the composition.

Use of sensors coated with elastomer for subterranean operations

Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids.

Well treatment compositions and methods utilizing nano-particles

A method comprising mixing a wellbore servicing composition comprising Micro-Electro-Mechanical System (MEMS) sensors in surface wellbore operating equipment at the surface of a wellsite. An interrogator retrieves data regarding a parameter sensed by the MEMS sensor.

Surface wellbore operating equipment utilizing MEMS sensors

An embodiment includes a method of servicing a well bore. The method may comprise introducing a lost circulation composition into a lost circulation zone, the lost circulation composition comprising hydraulic cement, nano-particles, amorphous silica, clay, and water. The method further may comprise allowing the lost circulation composition to set in the lost circulation zone. Another embodiment includes a lost circulation composition. The lost circulation may comprise hydraulic cement, nano-particles, amorphous silica, clay, and water.

Lost circulation compositions and associated methods

An apparatus includes an impervious body, a sealing element; an energy source, and a trigger. The impervious body is configured to prevent passage of fluid therethrough. The sealing element is disposed about the impervious body. The energy source is operationally connected to the sealing element. The trigger is configured to transfer energy from the energy source to the sealing element. The trigger is activated, at least in part, by receiving a signal from a pump tool passing through an interior of the impervious body.

Remotely activated downhole apparatus and methods

An apparatus includes an impervious body, a sealing element, an energy source, and a trigger. The impervious body is configured to prevent passage of fluid therethrough. The sealing element is disposed about the impervious body. The energy source is operationally connected to the sealing element. The trigger is configured to transfer energy from the energy source to the sealing element. The trigger is activated, at least in part, by receiving a signal transmitted through the impervious body.

The present invention includes well treatment fluids and methods utilizing nano-particles. An embodiment of a method of the present invention may comprise introducing a treatment fluid comprising nano-clay into a subterranean formation. The treatment fluid may be selected from the group consisting of a cement composition, a drilling fluid, a spacer fluid, and a lost circulation control composition. Another embodiment of the present invention may comprise a method of cementing. The method of cementing may comprise introducing a cement composition comprising a hydraulic cement, nano-clay, and water into a subterranean formation. The method further may comprise allowing the cement composition to set in the subterranean formation. Yet another embodiment of the present invention may comprise a treatment fluid, the treatment fluid comprising nano-clay. The treatment fluid may be selected from the group consisting of a cement composition, a drilling fluid, a spacer fluid, and a lost circulation control composition.

Cement compositions and methods utilizing nano-clay

A method comprising placing a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, placing a wellbore composition in the subterranean formation, and using the MEMS sensor to detect a location of the wellbore composition. A method comprising placing a Micro-Electro-Mechanical System (MEMS) sensor in a subterranean formation, placing a wellbore composition in the subterranean formation, and using the MEMS sensor to monitor a condition of the wellbore composition. A method comprising placing one or more Micro-Electro-Mechanical System (MEMS) sensors in a subterranean formation, placing a wellbore composition in the subterranean formation, using the one or more MEMS sensors to detect a location of at least a portion of the wellbore composition, and using the one or more MEMS sensors to monitor at least a portion of the wellbore composition. A method comprising placing one or more Micro-Electro-Mechanical System (MEMS) sensors in a subterranean formation using a wellbore composition, and monitoring a condition using the one or more MEMS sensors.

Use of micro-electro-mechanical systems MEMS in well treatments

Methods and compositions including, in one embodiment, a method of cementing in a subterranean formation comprising introducing a cement composition into the subterranean formation, wherein the cement composition comprises cement; a strength-enhancing additive consisting essentially of aluminum chloride and a metal halide; and water; and allowing the cement composition to set. Another method of cementing in a subterranean formation comprises preparing a cement composition that comprises cement, a strength-enhancing additive consisting essentially of aluminum chloride and a metal halide, and water, wherein the aluminum chloride and metal halide are not combined prior to preparing the cement composition; introducing the cement composition into the subterranean formation; and allowing the cement composition to set.

Growing community of inventors

Frisco, TX, United States of America

Ricky Layne Covington