Halliburton Energy Services, Inc.

Halliburton Company

Max Lynn Phillippi

Stanley Vernon Stephenson

Billy F Slabaugh

Calvin Lynn Stegemoeller

Herbert John Horinek

Vincent G Reidenbach

Leslie N Berryman

David A Prucha

Philip D Nguyen

Mehdi Sebdani Mazrooee

Ronald E Dant

Michael J R Segura

Randy S Rosine

Arron L Karcher

Herb Horinek

Donna L Harris

Herbert Horinek

Jimmie Dean Weaver, Jr

Richard W Pauls

Johnny A Barton

Chad Adam Fisher

Phillip C Harris

Robert S Taylor

Stanley J Heath

Richard Dale Rickman

John M Terracina

Bhadra D Desai

Mark Farabee

Richard L Middaugh

Tommy Slabaugh, Legal Representative

Ottmar F Hoch

Stan V Stephenson

Russell D Taylor

Herbert Hornick

Stan Stephenson

Described herein are systems, apparatuses, methods and computer-readable media that monitor and evaluate the density of a slurry of materials provided to a wellbore. Such systems and methods may be used when a volume of solids used in a hydraulic fracturing process is mixed with a volume of fluid when the slurry of materials is formed according to a hydraulic fracturing rule. This slurry may then be provided to the wellbore such that a hydraulic fracturing process may be completed. Here the solids may include a specific type of sand, a proppant material, or other material. Fluids used to make the slurry may include water, chemicals, or other liquids. A density of the slurry may be identified based on measurements that identify a mass of solids and volume of fluid that are provided to form the slurry.

Detection of solid delivery for slurry mixing

A method is provided which includes injecting a fluid into a wellbore; measuring, by a surface pressure sensor, a surface pressure; and measuring, by a downhole pressure sensor, a downhole pressure. A controller determines a true friction pressure based on a pressure differential between the surface pressure and the downhole pressure. A concentration of one or more components in the fluid is adjusted based on the true friction pressure to lower a total friction pressure loss.

System and method to optimize pumping

Methods and systems wherein a first setpoint is used with a controller to translate the setpoint into a desired flow rate from a pump and used to determining an optimized command signal associated with the first setpoint with a process control system, the process control system configured to incorporate at least a first setpoint and a measurement signal to produce the optimized command signal. The optimized command signal is then stored in a memory of the computer. When the first setpoint is again desired, the optimized command signal associated with the first setpoint is read from the memory and transmitted to the pump.

Decreasing pump lag time using process control

Methods of treating a fracture in a subterranean formation including providing a proppant-free fluid comprising a first gelling agent; providing a proppant fluid comprising a second gelling agent and proppant aggregates, wherein the proppant-free fluid and the proppant fluid are substantially immiscible; continuously pumping the proppant-free fluid into the subterranean formation; continuously pumping the proppant fluid into the subterranean formation, wherein the proppant-free fluid and the proppant fluid are present simultaneously in a portion of the subterranean formation but remain immiscible; placing the proppant aggregates into a portion of the fracture in the subterranean formation so as to form a proppant pack having proppant-free channels therein.

Methods for forming proppant-free channels in proppant packs in subterranean formation fractures

A mixing system may include a closed mixer having an inlet, a discharge, and an inlet/discharge. The mixing system may also include a recirculation line in fluid communication with the inlet and the inlet/discharge.

Centrifugal mixing system

A method of servicing a wellbore, comprising establishing a pumping profile having a performance plan, determining a remaining life estimate for a first wellbore servicing device, wherein the first wellbore servicing device is suitable for impacting conformance to the performance plan, and selecting a second wellbore servicing device in response to the remaining life value for the first wellbore servicing device, wherein the second wellbore servicing device is suitable for impacting conformance to the performance plan. A wellbore servicing system, comprising a first device suitable for impacting conformance to a performance plan, a first sensor configured to monitor an operational characteristic of the first device, and a controller in communication with the first sensor, the controller being configured to calculate at least one of a remaining life estimate of the first device and a probability of survival estimate of the first device.

System and method for servicing a wellbore

A system is provided that includes: (a) a mobile platform; (b) an input pump operatively connected to be capable of pumping a treatment stream through the system; (c) a centrifugal separator operatively connected downstream of the input pump to centrifugally treat the treatment stream; (d) a borate filter operatively connected downstream of the centrifugal separator to filter the treatment stream capable of removing at least some of a borate when the treatment stream is at a pH of 8 or above; and (e) a chemical-additive subsystem operatively connected to be capable of: (i) selectively adding one or more chemical agents to the treatment stream upstream of the centrifugal separator, wherein the chemical agents can be selected to be capable of precipitating dissolved ions selected from the group consisting of: sulfate, calcium, strontium, or barium, magnesium, iron; and (ii) selectively adding a chemical agent to the treatment stream upstream of the borate filter to increase the pH of the treatment stream to 8 or above.

Mobile systems and methods of sufficiently treating water so that the treated water may be utilized in well-treatment operations

A method is provided for treating at least a portion of a well. The method includes the steps of: (a) simultaneously introducing into a mixer at least: (i) a first stream comprising water; (ii) a second stream comprising a dry, hydratable, viscosity-increasing agent for water, wherein the second stream is substantially free of water; and (iii) a third stream comprising a non-hydratable, insoluble particulate; wherein at least the first and second streams are not mixed prior to being introduced into the mixer; (b) mixing the first, second, and third streams in the mixer to form a pumpable mixture, wherein: (i) the mixer creates at least a sufficiently-high shear rate to disperse the viscosity-increasing agent and the insoluble particulate in the pumpable mixture; and (ii) the pumpable mixture has or is capable of developing a substantially-higher viscosity than the viscosity of the first stream; and (c) introducing a treatment fluid comprising the pumpable mixture into a wellbore.

Methods for treating a well by simultaneously introducing into a mixer streams of water, a viscosity-increasing agent, and a particulate and introducing the mixture into the well

A portable well treating fluid mixing system includes: a supply tank having an inlet receiving pneumatically conveyed dry treating material; a cyclone separator having an inlet coupled to the supply tank and receiving dust laden air from the supply tank, and having a first outlet venting clean air and having a second outlet venting solids; a collection container having a first inlet coupled to the cyclone separator second outlet and receiving solids from the cyclone separator and having an outlet; and, a pump having an inlet coupled to the collection container outlet and a pump outlet coupled to the supply tank. In operation, the system continuously conveys dust from the collection container back into the supply tank to maintain the separator in proper operating condition and minimizes venting of dust during the transfer of material to the supply tank.

Portable well treating fluid mixing system and method

Dust control system for transferring dry material used in subterranean wells

Methods comprising: providing at least a plurality of liquid hardenable resin coated particulates that have been at least partially coated with a liquid hardenable resin component; providing at least a plurality of liquid hardening agent coated particulates that have been at least partially coated with a liquid hardening agent component; suspending the liquid hardenable resin coated particulates and the liquid hardening agent coated particulates in a treatment fluid; and placing the treatment fluid into a subterranean formation. Methods comprising: providing at least a plurality of coated particulates that have been at least partially coated with one component of a two component resin system; coating at least a plurality of the coated particulates on a job site with a second component of a two component resin system; suspending the coated particulates in a treatment fluid; and placing the treatment fluid into a subterranean formation.

Methods of coating particulates

The present invention relates generally to well servicing operations, and, more particularly, to devices, systems and methods useful in stimulation blending for fluids, mixtures, and/or slurries used in well servicing operations. A device, system and/or method is provided comprising a suction centrifugal pump capable of receiving an inlet fluid and providing a suction pressure arranged to substantially minimize a geyser effect in a proppant inlet and a mixer capable of receiving the inlet fluid provided by the suction centrifugal pump and mixing the inlet fluid with a proppant received from the proppant inlet, the mixer arranged to be substantially optimized for mixing. The device, system and/or method also comprises a discharge centrifugal pump capable of receiving the inlet fluid mixed with the proppant from the mixer and discharging the inlet fluid mixed with the proppant from the mixer downhole, the discharge centrifugal pump arranged to be substantially optimized for pumping. The system also comprises at least one downhole pump capable of receiving the inlet fluid mixed with the proppant from the mixer discharged downhole by the discharge centrifugal pump.

Centrifugal blending system

A method of fracturing a subterranean formation comprising the steps of: providing a coarse-foamed fracturing fluid comprising a liquid fracturing fluid component, a gas, proppant particulates, and a foaming agent; and placing the coarse-foamed fracturing fluid into a portion of a subterranean formation at a pressure sufficient to create or extend at least one fracture therein.

Coarse-foamed fracturing fluids and associated methods

The present invention relates to a method and system for hydrating a gel for treating a wellbore penetrating a subterranean formation. The method includes directing a base fluid through an inlet into a mixer having an inner chamber housing a plurality of impellors extending radially from and rotating about a hub, causing a centrifugal motion of the base fluid, feeding a quantity of gel into the mixer, mixing the gel with the base fluid and discharging the now-hydrated gel from the inner chamber through an outlet of the mixer. A prewetting device may also be used. Thereafter, a variety of additives may be added to the gel fluid mix to form a fluid treatment to be introduced into a subterranean formation.

Growing community of inventors

Duncan, OK, United States of America

Max Lynn Phillippi