US Pat. No. 9,309,752

COMPLETING LONG, DEVIATED WELLS

Halliburton Energy Servic...

1. A method of installing a liner into a fluid containing subterranean wellbore, the method comprising:
sealing a buoyancy fluid in an interior central bore of the liner with a plug assembly in the interior central bore by sealing
the plug assembly to an interior surface of the liner while the plug assembly is at the terranean surface, the buoyancy fluid
having a lower density than the fluid contained in the wellbore;

positioning the liner to a specified final depth in the wellbore;
withdrawing the plug assembly uphole; and
after withdrawing the plug assembly uphole, flooding the liner with a fluid having a density greater than the buoyancy fluid.

US Pat. No. 9,587,469

POLY(ALKYENYLAMIDE)-POLYSACCHARIDE HYDROGELS FOR TREATMENT OF SUBTERRANEAN FORMATIONS

Halliburton Energy Servic...

1. A method of treating a subterranean formation, the method comprising:
placing in the subterranean formation a composition comprising a poly(alkenylamide)-polysaccharide hydrogel; and
plugging a flow pathway in the subterranean formation with the hydrogel;
wherein
the poly(alkenylamide) comprises the structure -(PAA)n-(CL)m-,

the poly(alkenylamide) is a block or random copolymer,
PAA has the structure

CL has the structure:

the poly(alkenylamide)-polysaccharide hydrogel comprises at least one crosslink comprising an imide between the poly(alkenylamide)
and the polysaccharide,

each of PAA and CL at each occurrence independently occur in the orientation shown or in the opposite orientation,
the polysaccharide comprises Structure I

each of R10, R11, R12, R13, and R14 are independently selected from the group consisting of —H, —R15, —OR15, and —C(O)R16,

at each occurrence R15 is independently selected from the group consisting of —H and C1-C10 hydrocarbyl,

at each occurrence R16 is independently selected from the group consisting of —O?, —OH, and —O?CI+,

at each occurrence CI+ is independently a counterion,

p is at least about 2,
each of R1, R2, R3, R4, R5, R6, R7, R8, and R9 at each occurrence is independently selected from the group consisting of —H and C1-C10 hydrocarbyl,

each of L1, L2, and L3 are independently at each occurrence selected from the group consisting of a bond and C1-C10 hydrocarbylene,

m is at least about 1,
n is at least about 2, and
m1 is about 0 to about 10,000,000.

US Pat. No. 9,493,994

COMPOSITE BOW CENTRALIZER

Halliburton Energy Servic...

1. A centralizer comprising:
a first composite collar, wherein the first composite collar comprises inner fiber windings and outer fiber windings;
a second collar;
a plurality of composite bow springs coupling the first composite collar to the second collar, wherein the ends of the plurality
of composite bow springs are disposed between the inner fiber windings and the outer fiber windings of the first composite
collar; and

a plurality of particulates disposed along the outer surface of at least one bow spring, wherein the particulates are configured
to reduce the running forces required to move the centralizer when the centralizer contacts a surface.

US Pat. No. 9,357,657

LEAD-FREE SOLDER ALLOY FOR PRINTED CIRCUIT BOARD ASSEMBLIES FOR HIGH-TEMPERATURE ENVIRONMENTS

Halliburton Energy Servic...

1. A well logging tool comprising:
an electronic system, the electronic system including one or more solder joints formed from a premelted solid lead-free wire-form
solder having a preliminary solid solder alloy composition consisting of:

Silver;
Copper;
Antimony; and
Tin;
wherein the preliminary solid solder alloy composition has a weight % of the Silver in a range of 3.5 to 7.0, a weight % of
the Copper in a range of 1.0 to 4.0, and a weight % of the Antimony in a range of 1.0 to 3.0.

US Pat. No. 9,133,685

METHOD AND APPARATUS FOR AUTONOMOUS DOWNHOLE FLUID SELECTION WITH PATHWAY DEPENDENT RESISTANCE SYSTEM

Halliburton Energy Servic...

12. A device, comprising:
a flow system that divides flow among at least three passages at a common inlet shared by the at least three passages based
on the viscosity of the fluid flow, and that recombines the flow at a common outlet shared by the at least three passages
in a direction that depends on the viscosity of the fluid flow, wherein the at least three passages having first, second and
third resistances to the fluid flow, each of the first, second and third resistances to the fluid flow distinct from the other
two of the first, second and third resistances to the fluid flow.

US Pat. No. 9,405,035

ENHANCED TRANSMITTER AND METHOD FOR A NUCLEAR MAGNETIC RESONANCE LOGGING TOOL

HALLIBURTON ENERGY SERVIC...

1. A power amplifier configured for use with a downhole nuclear magnetic resonance transmitter tool, the power amplifier comprising:
a first pair of switching amplifiers that together generate a first pair of pulse sequences having an adjustable phase difference;
a second pair of switching amplifiers that together generate a second pair of pulse sequences, each pulse sequence in the
second pair having a phase offset relative to a phase of a different one of the pulse sequences in the first pair; and

a summation stage that forms a combined signal from the pulse sequences in both said first and second pairs,
wherein said phase offset operates in order to at least partly cancel a higher harmonic of the pulse sequences from the combined
signal formed by the summation stage.

US Pat. No. 9,315,719

LOW SURFACE FRICTION PROPPANTS

Halliburton Energy Servic...

1. A proppant having low surface friction comprising an angle of repose of 30° or less; wherein said proppant comprises:
a) a Krumbein sphericity of at least 0.5;
b) a roundness of at least 0.5;
c) a particle size distribution such that the proppant has a dps from about 0.001 to about 0.3, wherein dps=(dp90?dp10)/dp50 and wherein dp10 is a particle size wherein 10% of the particles have a smaller particle size, dp50 is a median particle size wherein 50% of the particles have a smaller particle size, and dp90 is a particle size wherein 90% of the particles have a smaller particle size;

d) a porosity, excluding a central void, of from about 6% to about 40%; and
e) proppant pores, wherein at least 90% of the proppant pores have a pore size of from about 0.1 micron to about 10 microns
and at least 80% of the proppant pores are not in contact with each other.

US Pat. No. 9,360,583

APPARATUS AND METHODS OF LOCATING DOWNHOLE ANOMALIES

Halliburton Energy Servic...

1. A method comprising:
controlling transmission of signals downhole in a well by controlling sequencing of pulses from one or more transmitters;
controlling reception of return signals by controlling timing of data acquisition from one or more receivers, the return signals
generated in response to the transmission of the signals, such that the controlled transmission and return signals mimic a
moving antenna; and

determining a characteristic of a geological formation in the well using the Doppler effect, based on the mimicking.

US Pat. No. 9,371,712

CEMENT SET ACTIVATORS FOR SET-DELAYED CEMENT COMPOSITIONS AND ASSOCIATED METHODS

Halliburton Energy Servic...

1. A method of cementing comprising:
providing a set-delayed cement composition comprising water, pumice, hydrated lime, and a set retarder;
activating the set-delayed cement composition with a liquid additive to produce an activated cement composition, wherein the
liquid additive comprises a monovalent salt, a polyphosphate, a dispersant, and water; and

allowing the activated cement composition to set.

US Pat. No. 9,091,147

DOWNHOLE FLUID FLOW CONTROL SYSTEM HAVING TEMPORARY SEALING SUBSTANCE AND METHOD FOR USE THEREOF

HALLIBURTON ENERGY SERVIC...

1. A flow control screen for positioning in a subterranean well, the flow control screen comprising:
a base pipe with an internal passageway, a blank pipe section and a perforated section;
a filter medium positioned around the blank pipe section of the base pipe;
a support assembly positioned around the base pipe;
a housing positioned around the base pipe and extending between the filter medium and the support assembly to define a fluid
path between the filter medium and the internal passageway;

at least one flow control component positioned radially between the support assembly and the housing, the flow control component
having at least one first port and at least one second port with a fluid chamber comprising a vortex chamber disposed therebetween,
the flow control component disposed within the fluid path such that fluid traveling between the filter medium and the internal
passageway must pass through the fluid chamber; and

a temporary sealing substance disposed within the fluid chamber, the temporary sealing substance preventing fluid flow through
the flow control component until the temporary sealing substance degrades when exposed to a water source in the well, thereafter
permitting fluid flow through the fluid chamber of the flow control component.

US Pat. No. 9,120,962

PLUGGING COMPOSITION USING SWELLABLE GLASS ADDITIVES

Halliburton Energy Servic...

1. A method for temporary plugging in a subterranean formation comprising:
providing a composition comprising a cementitious material, water, and a swellable glass additive;
introducing the composition into a subterranean formation;
allowing the composition to set into a single solid mass; and
allowing the swellable glass additive to swell, such that the swelling of the swellable glass additive fractures the solid
mass into two or more masses.

US Pat. No. 9,411,068

3D BOREHOLE IMAGER

HALLIBURTON ENERGY SERVIC...

1. A borehole logging method that comprises:
conveying an imaging tool along a borehole and tracking a position of the tool;
transmitting an electromagnetic pulse having a width less than 2×10?9 seconds from the imaging tool in each of multiple azimuthal directions;

receiving signals at spaced receivers of the imaging tool in response to each electromagnetic pulse, said signals corresponding
to electromagnetic pulse reflections from one or more formation boundaries;

processing each received signal to determine travel times from said electromagnetic pulse reflections; and
forming a three-dimensional (3D) image of a formation region surrounding the borehole based at least in part on said travel
times as a function of position and azimuthal direction.

US Pat. No. 9,371,703

TELESCOPING JOINT WITH CONTROL LINE MANAGEMENT ASSEMBLY

Halliburton Energy Servic...

1. A telescoping joint comprising:
an outer mandrel;
an inner mandrel releasably coupled to the outer mandrel, at least part of the inner mandrel being in an area defined by the
outer mandrel and defining an inner area sealable from an environment exterior to the outer mandrel;

a control line exterior to an outer surface of the outer mandrel and coiled around the inner mandrel;
a coil housing having an opening therethrough for receiving the control line traversing from exterior to the outer surface
of the outer mandrel to being coiled around the inner mandrel;

an outer bushing; and
an inner bushing of the inner mandrel,
wherein the control line is coiled between the outer bushings and the inner bushing.

US Pat. No. 9,074,990

METHODS AND DEVICES FOR OPTICALLY DETERMINING A CHARACTERISTIC OF A SUBSTANCE

Halliburton Energy Servic...

1. A device, comprising:
an electromagnetic radiation source configured to optically interact with a sample having a characteristic of interest;
a first integrated computational element arranged within a primary channel and configured to optically interact with the electromagnetic
radiation source and produce a first modified electromagnetic radiation, wherein the first integrated computational element
is configured to be positively or negatively correlated to the characteristic of interest;

a second integrated computational element arranged within a reference channel and configured to optically interact with the
electromagnetic radiation source and produce a second modified electromagnetic radiation, wherein the second integrated computational
element is configured to be correlated to the characteristic of interest with an opposite sign relative to the first integrated
computational element; and

a first detector arranged to generate a first signal from the first modified electromagnetic radiation and a second signal
from the second modified electromagnetic radiation, and generate an output signal corresponding to the characteristic of the
sample, wherein the second signal decreases when the first signal increases according to the characteristic of the sample,
and wherein the second signal increases when the first signal decreases according to the characteristic of the sample.

US Pat. No. 9,453,380

REMOTE HYDRAULIC CONTROL OF DOWNHOLE TOOLS

Halliburton Energy Servic...

15. A method of controlling a downhole tool coupled in a drill string extending longitudinally along a borehole, comprising:
controlling response of the downhole tool in the drill string to variations in a bore-annulus pressure difference by a control
arrangement mounted in the drill string, the control arrangement defining a valve port that is connectable to a hydraulic
activation mechanism of the downhole tool, the control arrangement further comprising,

a valve piston that is longitudinally displaceable in the drill string to dispose the valve port between an open condition,
to permit fluid pressure communication between a drill string bore and the activation mechanism of the downhole tool, and
a closed condition, to substantially isolate the activation mechanism from the drill string bore; and

a latch mechanism configured to releasably latch the valve piston to the drill string restrain relative longitudinal movement
of the valve piston in a first longitudinal direction, the valve piston, when latched, being releasable by movement thereof
in an opposite, second longitudinal direction to a mode change position, wherein latching or releasing of the valve piston
changes an operational mode of the control arrangement between,

an active mode in which the valve port in its open condition upon application of bore pressures at or above tool activation
levels, permits hydraulic tool activation, and

a dormant mode in which the valve port its closed condition upon application of bore pressures at or above tool activation
levels, prevents hydraulic tool activation; and

a stay piston that is automatically displaceable under hydraulic actuation of the stay piston responsive to a pressure difference
above a trigger threshold value, to obstruct movement of the latched valve piston toward the mode change position.

US Pat. No. 9,388,635

METHOD AND APPARATUS FOR CONTROLLING AN ORIENTABLE CONNECTION IN A DRILLING ASSEMBLY

Halliburton Energy Servic...

1. In an apparatus of the type comprising a first assembly, a second assembly, an orientable rotatable connection between
the first assembly and the second assembly, and a control device associated with the orientable rotatable connection, a method
for controlling the actuation of the control device, the method comprising:
(a) providing a force tending to cause rotation of the first assembly and the second assembly relative to each other;
(b) determining an actual orientation of the second assembly with the control device actuated to prevent rotation of the second
assembly relative to the first assembly;

(c) comparing the actual orientation of the second assembly with a target orientation of the second assembly in order to determine
if the actual orientation of the second assembly is acceptable;

(d) if the actual orientation of the second assembly is not acceptable, actuating the control device to perform a control
device actuation cycle, wherein the control device actuation cycle comprises first actuating the control device to allow rotation
of the second assembly relative to the first assembly and second actuating the control device to prevent rotation of the second
assembly relative to the first assembly;

(e) determining an updated actual orientation of the second assembly;
(f) comparing the updated actual orientation of the second assembly with the target orientation of the second assembly in
order to determine if the updated actual orientation of the second assembly is acceptable;

(g) if the updated actual orientation of the second assembly is not acceptable, repeating (d) through (f), using the updated
actual orientation of the second assembly as the actual orientation of the second assembly; and

(h) if the updated actual orientation of the second assembly is acceptable, maintaining the control device actuated to prevent
rotation of the second assembly relative to the first assembly.

US Pat. No. 9,388,671

SWELLABLE SCREEN ASSEMBLY WITH INFLOW CONTROL

Halliburton Energy Servic...

13. A method of producing a fluid composition from a subterranean formation, comprising:
introducing a screen assembly into the subterranean formation, the screen assembly comprising a base pipe defining at least
one opening therein, a rigid member disposed about a first portion of the base pipe, a swellable material disposed about a
second portion of the base pipe, and a filter medium at least partially disposed about the swellable material and coupled
thereto;

expanding the swellable material toward an inner surface of a wellbore and thereby actuating a piston arranged within the
rigid member, the piston having a telescoping portion coupled to the filter material and movably arranged within a non-telescoping
portion of the piston;

filtering the fluid composition through the filter material and directing a filtered fluid to the piston;
receiving the filtered fluid with an autonomous valve vertically arranged within the piston, the autonomous valve comprising:
a top defining at least two apertures that provide fluid communication from the filter medium into corresponding inlets of
the autonomous valve;

a flow chamber in fluid communication with the corresponding inlets and through which a fluid composition is able to flow;
a bottom defining at least one outlet in fluid communication with the flow chamber; and
at least one structure spirally oriented relative to the at least one outlet; and
inducing spiral flow of the fluid composition about the at least one outlet using the at least one structure and thereby regulating
a flow of the filtered fluid through the piston.

US Pat. No. 9,328,281

FOAMING OF SET-DELAYED CEMENT COMPOSITIONS COMPRISING PUMICE AND HYDRATED LIME

Halliburton Energy Servic...

1. A method of cementing in a subterranean formation
comprising:
providing a set-delayed cement composition comprising water, pumice, hydrated lime, a dispersant, and a set retarder; wherein
the set retarder comprises a phosphonic acid derivative and the dispersant comprises a polycarboxylated ether dispersant;

foaming the set-delayed cement composition;
activating the set-delayed cement composition;
introducing the set-delayed cement composition into a subterranean formation; and
allowing the set-delayed cement composition to set in the subterranean formation.

US Pat. No. 9,086,383

SYSTEMS AND METHODS FOR MONITORING CHEMICAL PROCESSES

Halliburton Energy Servic...

1. A system, comprising:
a flow path provided within a wellbore and containing a fluid in which a chemical reaction is presently occurring, wherein
the fluid comprises at least one of a reagent and a product associated with the chemical reaction;

at least one integrated computational element arranged in an optical train to optically interact with the fluid in the flow
path and thereby generate optically interacted light, the at least one integrated computational element comprising a plurality
of thin film layers deposited on an optical substrate;

at least one detector arranged in the optical train following the at least one integrated computational element to receive
the optically interacted light and generate an output signal corresponding to a characteristic of the chemical reaction occurring
within the fluid; and

a signal processor communicably coupled to the at least one detector for receiving the output signal, the signal processor
being programmed to determine the characteristic of the chemical reaction based on the output signal.

US Pat. No. 9,091,785

FIBEROPTIC SYSTEMS AND METHODS FOR FORMATION MONITORING

Halliburton Energy Servic...

1. A formation monitoring system that comprises:
a casing that defines an annular space within a borehole;
an array of electromagnetic field sensors in the annular space;
an optical waveguide that conveys optical signals to and from the array of electromagnetic field sensors;
a power source to generate a distribution of current flow into formations penetrated by said borehole;
a surface interface coupled to the optical waveguide to receive optical signals from the array of electromagnetic field sensors,
said received optical signals representing electromagnetic field measurements collected by the array of electromagnetic field
sensors in response to the current flow; and

a computer that operates on electromagnetic field measurement data corresponding to the received optical signals to calculate
at least one parameter associated with an approaching flood front.

US Pat. No. 9,388,687

FORMATION ENVIRONMENT SAMPLING APPARATUS, SYSTEMS, AND METHODS

Halliburton Energy Servic...

1. An apparatus, comprising: a geological formation probe operable in a well bore, the geological formation probe having at
least one fluid flow inlet with an inlet area of selectable, incrementally variable size, and having a plurality of sealing
elements within the at least one fluid flow inlet, each sealing element independently movable downhole with respect to the
other sealing elements of the plurality and advanceable to engage a wall of the well bore in a sealing engagement and retractable
from the sealing engagement, wherein the inlet area comprises a guard probe inlet area, the guard probe inlet area having
an incrementally adjustable size by selective activation of selected ones of the plurality of sealing elements, and further
wherein a first sealing element of the plurality of sealing elements is at least partially spaced from the at least one fluid
flow inlet, the first sealing element being the nearest of the plurality of sealing elements to the at least one fluid flow
inlet.

US Pat. No. 9,376,908

PIPE CONVEYED EXTENDABLE WELL LOGGING TOOL

Halliburton Energy Servic...

1. A pipe conveyed well logging assembly comprising:
a downhole pipe including a garage;
a logging tool disposed in the garage and extendable therefrom;
a retraction system located downhole and configured to retract the logging tool into the garage while downhole, wherein the
retraction system includes a tractor; and

a releasable latch releasably engageable with the garage to retain the logging tool in and release the logging tool from the
garage.

US Pat. No. 9,304,227

DETECTOR, PREAMPLIFIER SELECTION APPARATUS, SYSTEMS, AND METHODS

Halliburton Energy Servic...

1. An apparatus, comprising:
an optical detector;
a detector amplifier electrically coupled to the optical detector, wherein at least one of the optical detector or the detector
amplifier is to be dynamically selected via switching circuitry from among at least two alternative elements to minimize noise
equivalent power (NEP) of a selected detector or a combination of the selected detector and a selected amplifier;

a temperature sensor to sense an operating temperature of at least one of the optical detector or the detector amplifier;
and

a feedback and control system to monitor the operating temperature such that operation of the switching circuitry is based
on the operating temperature being in one temperature range of a plurality of temperature ranges.

US Pat. No. 9,388,681

METHOD TO OPTIMIZE DRILLING EFFICIENCY WHILE REDUCING STICK SLIP

Halliburton Energy Servic...

1. A method of controlling a top drive coupled to a drill bit via a drill string during a drilling process, comprising:
generating a first control signal based at least in part upon a bit angular speed set-point, a first bit angular speed, and
an optimization problem comprising an objective function at a first state, and one or more first state constraints to which
the objective function at the first state is subject,

wherein the one or more first state constraints comprise a model of dynamics between input torque to the top drive and resulting
bit angular speed;

controlling the top drive based at least in part upon the first control signal so as to rotate the drill bit at a second bit
angular speed;

updating the model based at least in part upon operating data associated with any one or more of the top drive, drill bit,
and drill string so as to obtain an updated model;

generating a second control signal based at least in part upon the bit angular speed set-point, the second bit angular speed,
and the optimization problem comprising the objective function at a second state and one or more second state constraints
to which the objective function at the second state is subject,

wherein the one or more second state constraints comprise the updated model; and
controlling the top drive based at least in part upon the second control signal so as to rotate the drill bit at a third bit
angular speed.

US Pat. No. 9,377,557

AZIMUTHALLY-SELECTIVE DOWNHOLE NUCLEAR MAGNETIC RESONANCE (NMR) TOOL

Halliburton Energy Servic...

1. A nuclear magnetic resonance (NMR) tool for use in a wellbore in a subterranean region, the NMR tool comprising:
a magnet assembly to produce a magnetic field in a volume in a subterranean region; and
an antenna assembly to produce an excitation in the volume, and to acquire an azimuthally-selective response from the volume
based on the excitation, the antenna assembly comprising a transversal-dipole antenna and a monopole antenna,

wherein the antenna assembly is configured so that the NMR tool acquires the azimuthally-selective response from the volume
using both the transversal-dipole antenna and the monopole antenna.

US Pat. No. 9,222,320

SUBSEA PRESSURE CONTROL SYSTEM

Halliburton Energy Servic...

1. A subsea pressure control system for use with a subsea well with a well annulus and a marine riser, comprising:
at least one subsea choke configured to variably restrict flow of drilling fluid from the well annulus through a flow passage
which branches off of the well annulus below a subsea annular sealing device configured to seal off the well annulus, the
subsea choke being positionable at a subsea location;

a process control system configured to automatically operate the at least one subsea choke and a subsea pump to maintain a
given pressure in the well annulus; and

the subsea pump configured to regulate a fluid level in a line external to the marine riser to apply a given hydrostatic pressure
to the well annulus, the subsea pump at the subsea location.

US Pat. No. 9,382,776

WELLBORE ISOLATION DEVICE MADE FROM A POWDERED FUSIBLE ALLOY MATRIX

Halliburton Energy Servic...

1. A method of producing and using at least a portion of a wellbore isolation device comprising:
providing a fusible alloy matrix in a powdered form;
placing at least the particles of the fusible alloy matrix powder into a mold;
compacting the particles located inside the mold via an application of pressure;
fusing the particles together to form a solid material, wherein the solid material forms the at least a portion of the wellbore
isolation device; and

introducing the at least a portion of the wellbore isolation device into a wellbore; wherein the fusible alloy matrix undergoes
a phase transformation at or near the bottomhole temperature of the wellbore after a desired amount of time.

US Pat. No. 9,328,573

INTEGRATED GEOMECHANICS DETERMINATIONS AND WELLBORE PRESSURE CONTROL

Halliburton Energy Servic...

1. A well drilling method, comprising:
determining a property of a formation surrounding a wellbore in real time as the wellbore is being drilled, wherein the determining
is based at least in part on data received from a sensor located at a surface location; and

controlling wellbore pressure in real time as the wellbore is being drilled by controlling operation of a flow control device
independently from a mud pump, the flow control device interconnected in a mud return line returning mud from the wellbore.

US Pat. No. 9,297,232

RECLOSABLE MULTI ZONE ISOLATION TOOL AND METHOD FOR USE THEREOF

Halliburton Energy Servic...

11. A method for isolating a first zone from a second zone in a subterranean wellbore, the method comprising:
disposing a multi zone isolation tool within the wellbore in a closed position, the tool including an inner tubular defining
a central flow path and an outer tubular defining an annular flow path with the inner tubular, the annular flow path in fluid
communication with the first zone, the central flow path in fluid communication with the second zone;

maintaining the tool in the closed position while treating the second zone by equalizing pressure in the central flow path
and the annular flow path;

operably coupling a tubing string with the inner tubular;
varying the pressure in the central flow path;
biasing a mandrel slidably disposed within the inner tubular in a first direction; and
shifting a sleeve having at least one seal disposed on an inner surface thereof and coupled to the mandrel from the closed
position wherein the seal engages an outer surface of the inner tubular to an open position wherein the seal engages an outer
surface of the outer tubular.

US Pat. No. 9,482,072

SELECTIVE ELECTRICAL ACTIVATION OF DOWNHOLE TOOLS

Halliburton Energy Servic...

1. A method of activating a downhole tool in a subterranean well, the method comprising:
displacing a device in the downhole tool, the device transmitting energy to a receiver of the downhole tool, thereby activating
the downhole tool; and

wherein transmitting includes a control circuitry of the device increasing electrical current flow between an electrical power
source of the device and a transmitter of the device in response to a sensor of the device detecting a predetermined stimulus
downhole, wherein the sensor includes a magnetic field sensor and wherein the predetermined stimulus includes a magnetic field
produced by an indicator mounted in a plug that includes a pressure barrier having a lower magnetic permeability than a housing
of the downhole tool into which the plug is secured.

US Pat. No. 9,376,609

SETTABLE COMPOSITIONS COMPRISING INTERGROUND PERLITE AND HYDRAULIC CEMENT

Halliburton Energy Servic...

1. A composition consisting of:
an interground mixture consisting of unexpanded perlite and Portland cement,
wherein the interground mixture has a mean particle size between about 0.5 microns and about 10 microns,
wherein the perlite is present in an amount of about 40% to about 80% by weight of the perlite and Portland cement,
wherein the Portland cement is present in an amount of about 20% to about 60% by weight of the perlite and Portland cement;
and

a hydraulic cement blended with the interground mixture.

US Pat. No. 9,234,835

APPARATUS AND METHOD FOR ANALYSIS OF A FLUID SAMPLE

Halliburton Energy Servic...

1. An apparatus for analyzing a fluid comprising:
a single chamber to receive a fluid sample;
a positive displacement pump in hydraulic communication with the single chamber, the positive displacement pump reducing a
pressure of the fluid sample in the single chamber below a vapor pressure of a component of the fluid sample;

at least one light system to provide a light at a predetermined modulation frequency to the fluid sample, the light system
having a chopper wheel formed with a plurality of rings of slots, each ring modulating the light transmitted to the fluid
sample at a different predetermined modulation frequency;

an acoustic sensor to detect an acoustic signal caused by the interaction of the light and the fluid sample;
a controller relating the acoustic signal to at least one chemical component of the fluid sample; and
a plurality of optical filters wherein each optical filter transmits a different predetermined wavelength of light, and wherein
each optical filter acts cooperatively with a corresponding ring to transmit light of a predetermined wavelength, ?i, at a predetermined modulation frequency, fi, to the fluid sample.

US Pat. No. 9,081,114

MULTI-ARRAY LATEROLOG TOOLS AND METHODS WITH SPLIT MONITOR ELECTRODES

HALLIBURTON ENERGY SERVIC...

1. A resistivity logging system that comprises:
a tool body having:
a center electrode positioned between multiple pairs of guard electrodes, wherein said multiple pairs of guard electrodes
are positioned between a pair of return electrodes on said tool body; and

multiple pairs of split monitor electrodes, each of said split monitor electrodes having two electrically-coupled component
electrodes with an associated guard electrode therebetween; and

electronics that provide a primary current from the center electrode to the pair of return electrodes and provide a respective
guard current from each pair in said multiple pairs of guard electrodes to the pair of return electrodes, the electronics
further operating to acquire a voltage measurement from each of said pairs of split monitor electrodes.

US Pat. No. 9,297,255

NON-INVASIVE COMPRESSIBILITY AND IN SITU DENSITY TESTING OF A FLUID SAMPLE IN A SEALED CHAMBER

Halliburton Energy Servic...

1. A method, comprising:
changing a hydraulic pressure applied to a floating piston within a sealed sample chamber such that the pressure on each side
of the piston is substantially equal, said sample chamber containing a formation fluid sample;

measuring said hydraulic pressure with a pressure sensor external to said sample chamber;
measuring a distance associated with said piston with a magnetic sensor; and
computing compressibility of said formation fluid sample contained within said sealed sample chamber based on the distance
and the measured hydraulic pressure.

US Pat. No. 9,279,904

SIMULATING DOWNHOLE FLOW THROUGH A PERFORATION

Halliburton Energy Servic...

1. A system for testing a core sample, comprising:
a non-permeable sleeve configured to be placed over a core sample;
a first pair of opposing actuators to apply opposing force to the non-permeable sleeve in a first axis normal to an axis of
the core sample;

a second pair of opposing actuators to apply opposing force to the non-permeable sleeve in a second axis normal to the axis
of the core sample and normal to the first axis;

a wellbore pressure reservoir to provide simulated wellbore pressure; and
a formation pressure reservoir to provide simulated formation fluid pressure.

US Pat. No. 9,234,404

DOWNHOLE FLUID FLOW CONTROL SYSTEM AND METHOD HAVING A FLUIDIC MODULE WITH A FLOW CONTROL TURBINE

HALLIBURTON ENERGY SERVIC...

1. A flow control screen comprising:
a base pipe with an internal passageway;
a filter medium positioned around the base pipe;
a housing positioned around the base pipe defining an annular fluid flow path between the filter medium and an exterior surface
of the base pipe;

an opening formed through said base pipe fluidly coupling said annular fluid flow path with said internal passageway; and
at least one fluidic module disposed within the annular fluid flow path, the fluidic module having a turbine chamber with
a flow control turbine rotatably disposed therein, the flow control turbine operable to provide fluid discriminating flow
resistance such that a pressure drop for a desired production fluid passing through the fluidic module is less than a pressure
drop for an undesired production fluid passing through the fluidic module.

US Pat. No. 9,091,782

MODULAR RESISTIVITY LOGGING TOOL SYSTEMS AND METHODS EMPLOYING AN ADAPTER IN AN ISOLATION JOINT CONFIGURATION

HALLIBURTON ENERGY SERVIC...

1. A resistivity logging tool module, comprising:
a mandrel with connector sections at each end and a ring support section between the connector sections;
a composite layer disposed around the ring support section;
a set of ring electrodes disposed along the ring support section around the composite layer, wherein the composite layer electrically
isolates the set of ring electrodes from the ring support section and wherein at least one of the ring electrodes includes
an electrode pin slot aligned with an aperture that extends to an interior of the mandrel; and

an adapter in an isolation joint configuration with one of the connector sections.

US Pat. No. 9,316,095

AUTONOMOUS INFLOW CONTROL DEVICE HAVING A SURFACE COATING

Halliburton Energy Servic...

16. A method of providing a variable resistance to fluid flow in a wellbore, the method comprising:
receiving a first fluid and a second fluid at an autonomous inflow control device;
directing the first fluid into a vortex chamber via a first leading passageway coupled to the vortex chamber by a first inlet
and a second inlet, and directing the second fluid toward the vortex chamber via a second leading passageway coupled to the
vortex chamber by a third inlet and a fourth inlet, wherein the first leading passageway and the second leading passageway
are separated by the vortex chamber; and

changing the resistance to flow of at least a portion of the first fluid and a portion of the second fluid with a super hydrophobic
surface within the vortex chamber, wherein the resistance to flow through the autonomous inflow control device varies based
on a fluid pathway through the vortex chamber.

US Pat. No. 9,267,072

WEIGHTED ELASTOMERS, CEMENT COMPOSITIONS COMPRISING WEIGHTED ELASTOMERS, AND METHODS OF USE

Halliburton Energy Servic...

1. A method comprising;
providing a fluid that comprises a weighted elastomer, wherein the weighted elastomer comprises an elastomer and a weighting
agent attached to an outer surface of the elastomer, wherein the fluid comprises a fluid selected from the group consisting
of a drilling fluid, a stimulation fluid, a spacer fluid, a well clean-up fluid, and combinations thereof; wherein the weighting
agent is attached to the elastomer with an adhesive, wherein the adhesive comprises at least one adhesive selected from the
group consisting of a water-based acrylic paint, an oil-based paint, and an oil-based primer; and

introducing the fluid into a subterranean formation.

US Pat. No. 9,328,583

SET-DELAYED CEMENT COMPOSITIONS COMPRISING PUMICE AND ASSOCIATED METHODS

Halliburton Energy Servic...

1. A method of cementing in a subterranean formation comprising:
providing a cement composition comprising water, pumice, hydrated lime, a set retarder, a dispersant, and a strength enhancer,
wherein the strength enhancer comprises at least one material selected from the group consisting of cement kiln dust, slag,
amorphous silica, a pozzolan, and any combination thereof, wherein the set retarder comprises a phosphonic acid derivative
and the dispersant comprises a polycarboxylated ether dispersant;

introducing the cement composition into the subterranean formation; and
allowing the cement composition to set in the subterranean formation.

US Pat. No. 9,291,030

ANNULAR FLOW CONTROL DEVICES AND METHODS OF USE

Halliburton Energy Servic...

9. A method of regulating a flow of a fluid, comprising:
conveying the fluid in a work string defining one or more flow ports therein;
receiving a portion of the fluid in an annular flow control device coupled to an exterior of the work string and including
an inner shroud and an outer shroud radially offset from the inner shroud and defining a channel therebetween to receive the
portion of the fluid, the channel being in fluid communication with at least one of the one or more flow ports;

conveying the portion of the fluid through one or more tubular fluid conduits that extend radially into an interior of the
work string and are inserted at least partially into the one or more flow ports; and

conducting the portion of the fluid through the channel and the at least one of the one or more flow ports, and thereby creating
a flow restriction on the fluid through the annular flow control device.

US Pat. No. 9,285,355

METHOD AND APPARATUS FOR TESTING LOST CIRCULATION MATERIALS FOR SUBTERRANEAN FORMATIONS

Halliburton Energy Servic...

1. An cell for testing lost circulation materials (LCM) used in a formation, comprising:
a housing, wherein the housing defines an internal cavity;
at least one vugular formation simulation component positioned within the internal cavity, wherein the at least one formation
simulation component comprises balls positioned between a cylindrical inner structure and a housing liner disposed within
the internal cavity;

a retainer positioned above the at least one formation simulation component in the internal cavity; and
a cap removably engaged with the housing, wherein the cap compresses the at least one formation simulation component and the
retainer within the internal cavity when engaged.

US Pat. No. 9,328,587

PULSATING ROTATIONAL FLOW FOR USE IN WELL OPERATIONS

Halliburton Energy Servic...

1. A system for use with a subterranean well, the system comprising:
a fluid oscillator which discharges pulsating fluid from a tubular string in a first direction at least partially toward a
first end of the tubular string proximate a surface of the earth; and

a fluid switch to control selection of a port from among a plurality of ports to discharge the pulsating fluid from the tubular
string in the first direction, each port arranged to discharge the pulsating fluid from the tubular string in the first direction
at least partially toward the first end of the tubular string proximate the surface of the earth.

US Pat. No. 9,316,057

ROTARY DRILL BITS WITH PROTECTED CUTTING ELEMENTS AND METHODS

Halliburton Energy Servic...

1. A method for designing a drill bit including cutting elements having a protector operable to control a depth of cut of
the associated cutting element in a downhole formation, comprising:
(a) selecting, by a processor, a downhole drilling parameter;
(b) determining, by the processor, a maximum rate of penetration (ROP) based on the downhole drilling parameter;
(c) calculating, by the processor, maximum depth of cut for a cutting element based on the maximum ROP;
(d) selecting, by the processor, an effective diameter and a back rake angle for the cutting element, and an effective diameter
for the protector, wherein the protector is integrated in the cutting element;

(e) calculating, by the processor, a protector length based on:
a difference between the effective diameter of the cutting element and the effective diameter of the protector,
the back rake angle of the cutting element, and
the maximum depth of cut of the cutting element;
(f) comparing, by the processor, the calculated protector length with an allowable range of protector lengths; and
(g) if the calculated protector length is not in the allowable range of protector lengths, reselecting, by the processor the
effective diameter of the cutting element, the back rake angle of the cutting element, or the effective diameter of the protector
until the calculated protector length is in the allowable range of protector lengths.

US Pat. No. 9,302,693

COILED TUBING SERVICING TOOL

Halliburton Energy Servic...

1. A coiled tubing servicing system comprising: a servicing cart comprising two or more support frames; a length of coiled
tubing supported by the servicing cart; a servicing fixture disposed about a portion of the length of coiled tubing adjacent
the servicing cart, wherein the servicing fixture is movable along a longitudinal axis of the length of coiled tubing and
radially about the longitudinal axis of the length of coiled tubing; and a servicing tool coupled to the servicing fixture,
wherein the servicing tool comprises an x-ray assembly.

US Pat. No. 9,284,817

DUAL MAGNETIC SENSOR ACTUATION ASSEMBLY

Halliburton Energy Servic...

13. A wellbore servicing tool comprising:
a housing comprising one or more ports and generally defining a flow passage;
a first magnetic sensor and a second magnetic sensor disposed within the housing, wherein the first magnetic sensor is positioned
up-hole of the second magnetic sensor;

an electronic circuit coupled to the first magnetic sensor and the second magnetic sensor; and
a memory coupled to the electronic circuit, wherein the memory comprises instructions that cause the electronic circuit to:
detect a magnetic device within the housing;
determine the flow direction of the magnetic device through the housing; and
adjust a counter in response to the detection of the magnetic device and the determination of the flow direction of the magnetic
device through the housing.

US Pat. No. 9,267,361

CASING WINDOW ASSEMBLY

Halliburton Energy Servic...

1. A casing window assembly, comprising:
a tubular casing sleeve having an inside diameter, an outside diameter and a position for a casing window, the inside diameter
including a recessed wall profile for receipt of a portion of an expandable wall and a recess for receipt of a portion of
a securing element, wherein an end of the recessed wall profile includes a shoulder; and

an inner sleeve releasably secured within the casing sleeve by the expandable wall or the securing element and having an inside
diameter, an outside diameter and a wall between the inside diameter and the outside diameter, a portion of the wall forming
the expandable wall and another portion of the wall including a portion of the securing element.

US Pat. No. 9,238,966

AZIMUTHAL BRITTLENESS LOGGING SYSTEMS AND METHODS

HALLIBURTON ENERGY SERVIC...

1. A brittleness logging method that comprises:
taking measurements of compressional wave velocity as a function of position and orientation from inside a borehole;
taking measurements of shear wave velocity as a function of position and orientation from inside said borehole;
deriving azimuthal brittleness at least in part from said compressional and shear wave velocities; and
displaying azimuthal brittleness as an image log.
US Pat. No. 9,395,294

SYSTEMS AND METHODS FOR MONITORING CHEMICAL PROCESSES

Halliburton Energy Servic...

1. A method of monitoring a fluid, comprising:
containing the fluid in which a chemical reaction is occurring within a flow path;
interacting an electromagnetic radiation source with the fluid to form a sample interacted light;
separating a portion of the sample interacted light with a beam splitter;
measuring the intensity of the separated portion of the sample interacted light with a first detector to form a compensating
signal indicative of radiative deviations from the electromagnetic radiation source;

optically interacting at least one integrated computational element with the fluid using the sample interacted light, thereby
generating modified electromagnetic radiation, the integrated computational element comprising a plurality of layers of dielectric
materials deposited on an optical substrate according to a characteristic of the chemical reaction;

producing an output signal by measuring the modified electromagnetic radiation with a second detector coupled to the integrated
computational element;

receiving the output signal and the compensating signal with a signal processor communicably coupled to the first and second
detectors; and

determining the characteristic of the chemical reaction with the signal processor by comparing the output signal with the
compensating signal,

wherein the processor is programmed to adjust a flow of a treatment reagent being introduced into a flow path based on the
determined characteristic of the chemical reaction in response to an out of range condition.

US Pat. No. 9,309,862

NUTATING FLUID-MECHANICAL ENERGY CONVERTER

Halliburton Energy Servic...

1. A fluid-mechanical device comprising:
a stator comprising:
an outer cylinder having a longitudinal passage;
an inner guide cylinder disposed longitudinally within the outer cylinder, the inner guide cylinder and outer cylinder defining
an annulus for flow of a fluid; and

a longitudinal guide positioned inside at least a portion of the outer cylinder, the longitudinal guide attached to a portion
of an outer surface of the inner guide cylinder and extending outwardly toward an inner surface of the outer cylinder, wherein
the longitudinal guide comprises a helical guide spanning at least a portion of a length of the inner guide cylinder; and

a rotor positioned in the annulus, the rotor including a rotor cylinder having a sidewall with a guide opening that receives
the longitudinal guide.

US Pat. No. 9,297,254

METHODS FOR MONITORING FLUIDS WITHIN OR PRODUCED FROM A SUBTERRANEAN FORMATION USING OPTICOANALYTICAL DEVICES

Halliburton Energy Servic...

1. A method comprising:
providing a treatment fluid comprising a base fluid and at least one additional component;
introducing the treatment fluid into a subterranean formation;
allowing the treatment fluid to perform a treatment operation in the subterranean formation; and
monitoring a characteristic of the treatment fluid using a first integrated computational element in a first optical computing
device by exposing the treatment fluid to incident electromagnetic radiation and impinging output electromagnetic radiation
from the treatment fluid on the first integrated computational element, the output electromagnetic radiation comprising background
electromagnetic radiation and electromagnetic radiation related to the characteristic;

wherein the first integrated computational element is configured to discriminate between the background electromagnetic radiation
and the electromagnetic radiation related to the characteristic, the first integrated computational element comprising a layered
structure whose transmissive, reflective or absorptive properties are suitable for detection of the characteristic; and

wherein the first integrated computational element is located within the subterranean formation when the treatment fluid is
being introduced thereto.

US Pat. No. 9,273,534

TOOL WITH PRESSURE-ACTIVATED SLIDING SLEEVE

HALLIBURTON ENERGY SERVIC...

9. A method for actuating a downhole tool, said tool having a housing and a sleeve slideably disposed within said housing,
the method comprising:
fluidly coupling an upper end of said housing to a lower end of said housing by a through bore of said sleeve;
subjecting said upper and lower ends of said housing and said through bore to a uniform interior pressure throughout;
directly holding said sleeve in a shut position with respect to said housing against an influence of said interior pressure
by a shear pin;

selectively directly connecting said sleeve to said housing by a locking mechanism on the basis of said interior pressure;
raising said interior pressure to exceed a locking pressure to cause said locking mechanism to engage said sleeve to said
housing; then

raising said interior pressure to an activation pressure to shear said shear pin, said engaged locking mechanism holding said
sleeve in said shut position; and then

lowering said interior pressure to an opening pressure to cause said locking mechanism to disengage said sleeve from said
housing and allowing said influence of said interior pressure to move said sleeve to an open position.

US Pat. No. 9,371,478

PLUGGING COMPOSITION USING SWELLABLE GLASS ADDITIVES

Halliburton Energy Servic...

1. A temporary plugging composition comprising:
a cementitious material;
a swellable glass additive that provides a swellable glass force to exceed a bond strength of the cementitious material after
setting of the temporary plugging composition; and

water.

US Pat. No. 9,321,956

METHODS FOR HINDERING THE SETTLING OF PARTICULATES IN A SUBTERRANEAN FORMATION

Halliburton Energy Servic...

1. A method comprising:
providing gas-forming particulates comprising:
coating particulates with a first binding agent
wherein the first binding agent holds a gas-generating chemical onto the particulates;
coating the gas-forming particulates with a first encapsulating material;
coating the first encapsulating material with a second binding agent,
wherein the second binding agent holds an activator onto the first encapsulating material;
suspending in a treatment fluid the gas-forming particulates coated first with the first encapsulating material and coated
second with the second binding agent; and

reacting the gas-generating chemical and the activator so as to generate gas-formed particulates.

US Pat. No. 9,250,349

OPTIMIZED ARRAYS FOR LOOK AHEAD-OF-BIT APPLICATIONS

Halliburton Energy Servic...

1. A system to measure signals indicative of properties downhole, the apparatus comprising:
a tool having an arrangement of transmitters and receivers along a longitudinal axis of the tool to capture, when the tool
is disposed downhole, signals from a first downhole region in response to activation of the transmitters; and

a control unit to control activation of the transmitters and signal acquisition of the receivers to process signals received
from the receivers, wherein the placement of the transmitters and receivers with respect to each other is such that signal
contributions from a second downhole region in the vicinity of the tool are substantially canceled by the control unit structured
to process a specified combination of the signals received from the receivers, based on the placement of the transmitters
and receivers with respect to each other, the placement correlated to location of the first and second downhole regions relative
to the tool.

US Pat. No. 9,395,721

IN-SITU MONITORING OF FABRICATION OF INTEGRATED COMPUTATIONAL ELEMENTS

Halliburton Energy Servic...

1. A method comprising:
receiving, by a fabrication system, a design of an integrated computational element (ICE), the ICE design comprising specification
of a substrate and a plurality of layers, their respective target thicknesses and complex refractive indices, wherein complex
refractive indices of adjacent layers are different from each other, and wherein a notional ICE fabricated in accordance with
the ICE design is related to a characteristic of a sample;

forming, by the fabrication system, at least some of the plurality of layers of the ICE in accordance with the ICE design;
performing, by a measurement system associated with the fabrication system, at least two different types of in-situ measurements,
wherein a first type of in-situ measurement from among the at least two different types of in-situ measurements is performed
when fewer than a first number of layers of the ICE have been formed, and a second type of in-situ measurement from among
the at least two different types of in-situ measurements is performed when at least the first number of layers of the ICE
have been formed;

predicting, by the fabrication system using results of the at least two different types of in situ measurements, performance
of the ICE relative to the ICE design; and

adjusting, by the fabrication system, said forming of the layers remaining to be formed, at least in part, by updating the
ICE design based on the predicted performance.

US Pat. No. 9,284,224

CEMENT COMPOSITIONS AND METHODS OF USING THE SAME

Halliburton Energy Servic...

1. A method comprising:
introducing a cement composition into a subterranean formation having corrosive components therein, wherein the cement composition
comprises:

an aluminosilicate;
a potassium aluminate at 20% to 80% by weight of the aluminosilicate;
a fluid loss control additive comprising a copolymer of diallyldimethylammonium chloride and 2-acrylamido-2-methylpropane
sulfonic acid; and

water; and
allowing the cement composition to set to provide a set cement sheath;
wherein the set cement sheath is resistant to degradation from the corrosive components within the subterranean formation.

US Pat. No. 9,284,802

METHODS OF USING AN EXPANDABLE BULLNOSE ASSEMBLY WITH A WELLBORE DEFLECTOR

Halliburton Energy Servic...

1. A method, comprising:
introducing a bullnose assembly into a main bore of a wellbore, the bullnose assembly including a body and a bullnose tip
actuatable between a default configuration, where a coil wrapped about the bullnose tip exhibits a first diameter, and an
actuated configuration, where the coil exhibits a second diameter different than the first diameter;

advancing the bullnose assembly to a deflector arranged within the main bore and defining a first channel that exhibits a
predetermined diameter and communicates with a lower portion of the main bore, and a second channel that communicates with
a lateral bore; and

directing the bullnose assembly into either the lower portion of the main bore or the lateral bore based on a diameter of
the coil as compared to the predetermined diameter.

US Pat. No. 9,284,824

METHOD AND APPARATUS FOR EXPENDABLE TUBING-CONVEYED PERFORATING GUN

Halliburton Energy Servic...

1. A method of perforating a well casing, the method comprising:
inserting, into the well casing, a tubing conveyed perforator comprising:
an outer tubular made from a plurality of non-bonded metallic glass alloy tubulars having high strength and low impact resistance,
and

an inner structure positioned within the outer tubular and holding one or more explosive charges;
detonating the one or more explosive charges; and
fragmenting the outer tubular upon detonation of the one or more explosive charges.

US Pat. No. 9,273,243

LIGHT WEIGHT PROPPANT WITH IMPROVED STRENGTH AND METHODS OF MAKING SAME

Halliburton Energy Servic...

1. A method for producing a proppant comprising
a. forming, a green body comprising a hollow template from a green body material comprising
i. at least one metal oxide or precursor thereof that is capable of forming a crystalline phase in said proppant, and
ii. at least one amorphous material containing at least one entrapped vaporizable material, and
iii. at least one fluxing agent
b. reactive sintering said green body under reactive sintering conditions to form a sintered body comprising at least one
crystalline phase, at least one amorphous phase, and having gas bubbles contained therein, and wherein said gas bubbles are
optionally at least partially surrounded by at least one glassy compound, and a majority of said gas bubbles are not in contact
with each other; and wherein said reactive sintering forms at least one mullite whisker phase and an amorphous phase in said
template.

US Pat. No. 9,187,970

WELLBORE ISOLATION DEVICES AND METHODS OF USE TO PREVENT PUMP OFFS

Halliburton Energy Servic...

1. A downhole tool, comprising:
a housing coupled to a wellbore isolation device;
a tension-actuated valve arranged within the housing and having a first piston movably arranged within a first piston chamber,
the first piston being operatively coupled to a conveyance such that tension in the conveyance is transmitted to the first
piston, wherein, when the tension in the conveyance is reduced, the first piston is moved within the first piston chamber
such that wellbore fluids are able to enter the first piston chamber; and

a pressure-actuated valve arranged within the housing and having a second piston movably arranged within a second piston chamber
in order to place the second piston chamber in fluid communication with the first piston chamber,

wherein, upon experiencing a pressure drop across the downhole tool, the second piston is moved within the second piston chamber
such that the wellbore fluids are able to pass into the second piston chamber and through the wellbore isolation device, thereby
reducing hydraulic forces on the downhole tool when the tension in the conveyance is restored.

US Pat. No. 9,157,315

ANTENNA COUPLING COMPONENT MEASUREMENT TOOL HAVING A ROTATING ANTENNA CONFIGURATION

HALLIBURTON ENERGY SERVIC...

1. An electromagnetic resistivity logging tool that comprises:
a rotational position sensor;
at least one receiver antenna;
a first transmitter antenna having a first transmitter antenna orientation; and
a second transmitter antenna having a second, different transmitter antenna orientation; and
a processor to receive at least one of a phase and amplitude measurement in response to each of the transmitter antennas at
each of a plurality of azimuthal angles to calculate at least one component of a coupling matrix using only transmitter antennas
having the first and second transmitter antenna orientations.

US Pat. No. 9,303,483

SWELLABLE PACKER WITH ENHANCED SEALING CAPABILITY

HALLIBURTON ENERGY SERVIC...

1. A packer assembly, comprising:
multiple annular-shaped seal elements which swell and expand into contact with a well surface in response to contact with
a fluid, each seal element having at least one face inclined relative to a longitudinal axis of the packer assembly, and the
inclined faces of adjacent seal elements contacting each other, wherein at least one of the inclined faces radially outwardly
biases at least one seal element into contact with the well surface when the multiple seal elements swell downhole.

US Pat. No. 9,284,795

RISER DISPLACEMENT AND CLEANING SYSTEMS AND METHODS OF USE

Halliburton Energy Servic...

1. A riser displacement system, comprising:
a mandrel coupled to a work string;
a seal containment canister arranged about at least a portion of the mandrel;
a seal assembly movable between an un-deployed configuration, where the seal assembly is arranged within the seal containment
canister, and a deployed configuration, where the seal assembly is arranged outside of the seal containment canister, the
seal assembly including a sleeve movably arranged about the mandrel and one or more sealing elements disposed at a distal
end of the sleeve; and

a piston bore defined between the sleeve and the mandrel, the piston bore being in fluid communication with an interior of
the work string via one or more orifices defined in the mandrel.

US Pat. No. 9,284,798

METHODS AND COMPOSITIONS FOR TREATING SUBTERRANEAN FORMATIONS WITH SWELLABLE LOST CIRCULATION MATERIALS

Halliburton Energy Servic...

1. A method of treating a fluid loss zone in a wellbore in a subterranean formation comprising:
providing swellable particles having an initial unswelled volume and a first shape,
wherein the swellable particles comprise a non-swellable polymer portion that is coextruded adjacent and attached to a swellable
polymer portion,

wherein the coextrusion is asymmetric,
wherein the swellable polymer portion is present in a greater proportion than the non-swellable polymer portion,
wherein the swellable particles upon swelling adopt a second shape, and
wherein the first and second shape are different due to the swelling of the swellable particle alone, and at least one of
the first or second shapes is a cone-shape; a torus-shape; a cross-shape; a lattice-shape; a star-shape; a crescent-shape;
a bowtie-shape; or a spiral-shape;

introducing the swellable particles into the wellbore in the subterranean formation; and
swelling the swellable particles so as to adopt a swelled volume beyond the initial unswelled volume and the second shape;
and

sealing at least a portion of the fluid loss zone.

US Pat. No. 9,273,538

ECONOMICAL CONSTRUCTION OF WELL SCREENS

Halliburton Energy Servic...

1. A well screen for use in a subterranean well, the well screen comprising:
a generally tubular base pipe; and
a filter media comprising a foam which filters fluid that flows between an interior and an exterior of the base pipe, wherein
the foam is positioned in an annular space formed radially between the base pipe and a shroud, wherein the shroud has a lower
coefficient of thermal expansion than that of the base pipe so that at downhole temperatures the base pipe expands radially
outward at a rate greater than that of the shroud, thereby radially compressing the filter media.

US Pat. No. 9,284,793

EXTERNALLY SERVICEABLE SLIP RING APPARATUS

Halliburton Energy Servic...

19. A method of servicing a slip ring apparatus comprising a contact assembly recess defined by a housing, the contact assembly
recess having an exterior recess side which is accessible from an exterior of the housing and an interior recess side which
is in communication with an interior of the housing, a slip ring rotor assembly contained within the interior of the housing
adjacent to the interior recess side of the contact assembly recess, wherein the slip ring rotor assembly is rotatable relative
to the housing, a slip ring contact assembly mounted within the interior of the housing so that the slip ring rotor assembly
is rotatable relative to the slip ring contact assembly, wherein the slip ring contact assembly is electrically connected
with the slip ring rotor assembly, and a hatch cover covering the contact assembly recess and the slip ring contact assembly,
the method comprising:
(a) removing the hatch cover via the exterior recess side of the contact assembly recess;
(b) servicing the slip ring apparatus via the exterior recess side of the contact assembly recess; and
(c) replacing the hatch cover via the exterior recess side of the contact assembly recess.

US Pat. No. 9,376,890

RESILIENT DOWNHOLE FLOW RESTRICTOR

Halliburton Energy Servic...

1. A gravel packing assembly configured for being disposed in a wellbore, the gravel packing assembly comprising:
a main tube for providing a main flow path for gravel packing slurry; a transport tube for providing an alternative flow path
to the main flow path for the gravel packing slurry; and

a flow restrictor for use downhole, the flow restrictor being on a surface of the transport tube and comprising a plurality
of resilient flaps that overlap each other and that are configured for flexing outwardly from a first position that forms
a gap to a second position that forms an opening larger than the gap in response to flow pressure in an inner area of the
transport tube and for returning to the first position,

wherein the plurality of resilient flaps are configured for variably restricting flow of the gravel packing slurry between
the first position and the second position based on the flow pressure in the transport tube.

US Pat. No. 9,322,807

ULTRASONIC SIGNAL TIME-FREQUENCY DECOMPOSITION FOR BOREHOLE EVALUATION OR PIPELINE INSPECTION

Halliburton Energy Servic...

1. A method for borehole evaluation or pipeline inspection, the method comprising:
receiving an ultrasonic signal in response to a transmitted signal;
generating a set of non-orthogonal basis functions based on a synthetic signal generated from properties of a physical model
of a pipeline and the transmitted signal;

decomposing the ultrasonic signal into at least one wavelet using a constrained matching pursuit decomposition and the set
of non-orthogonal basis functions as constraint parameters;

determining parameters associated with each wavelet; and
performing the borehole evaluation or pipeline inspection based on the parameters.

US Pat. No. 9,249,649

BIDIRECTIONAL DOWNHOLE FLUID FLOW CONTROL SYSTEM AND METHOD

Halliburton Energy Servic...

1. A bidirectional downhole fluid flow control system comprising:
a plurality of injection flow control components having direction dependent flow resistance, the injection flow control components
further comprising two stage flow control components including, in series, a first vortex diode stage and a second vortex
diode stage, each of the first and second stages of the injection flow control components having a central inlet port and
a radial outlet port, wherein the radial outlet port of the first stage is in fluid communication with the central inlet port
of the second stage of the injection flow control components; and

a plurality of production flow control components having direction dependent flow resistance, the production flow control
components further comprising two stage flow control components including, in series, a first vortex diode stage and a second
vortex diode stage, each of the first and second stages of the production flow control components having a central outlet
port and a radial inlet port, wherein the central outlet port of the first stage is in fluid communication with the radial
inlet port of the second stage of the production flow control components,

wherein, the production flow control components are in parallel with the injection flow control components;
wherein, injection fluid flow experiences a greater flow resistance through the production flow control components than through
the injection flow control components; and

wherein, production fluid flow experiences a greater flow resistance through the injection flow control components than through
the production flow control components.

US Pat. No. 9,157,317

COMBINATION POWER SOURCE FOR A MAGNETIC RANGING SYSTEM

Halliburton Energy Servic...

1. A magnetic ranging system, comprising:
a downhole apparatus sized to couple to a drill string;
a transmitter coupled to the downhole apparatus;
a receiver coupled to the downhole apparatus; and
a power management system coupled to the downhole apparatus, wherein the power management system selectively provides power
to the transmitter from a first power source or a second power source based, at least in part, on an estimated distance to
a target well.

US Pat. No. 9,267,369

MODELING INTERSECTING FLOW PATHS IN A WELL SYSTEM ENVIRONMENT

Halliburton Energy Servic...

1. A fluid flow modeling method comprising:
generating, by operation of one or more computers, flow model data associated with a one-dimensional flow model for well system
fluid in a fracture network in a subterranean region, the flow model representing flow paths that intersect at a flow path
intersection in the fracture network, the flow model data including:

a band matrix representing fluid flow within the respective flow paths; and
an intersection table representing fluid flow between the flow paths at the flow path intersection; and
simulating, using the one or more computers, fluid flow in the fracture network using the band matrix and the intersection
table.

US Pat. No. 9,249,654

METHOD AND SYSTEM FOR PREDICTING PERFORMANCE OF A DRILLING SYSTEM

Halliburton Energy Servic...

13. A computer readable medium having a set of instructions stored thereon such that when executed by a computer perform a
set of operations comprising:
calculating, in real time, using a torque versus weight on bit model, an updated bit friction slope and an updated worn bit
slope for the drilling interval using a weight on bit, a torque on bit, and a bit revolutions per minute measured over a drilling
interval in a wellbore; and

calculating an updated weight on bit and a bit revolutions per minute for drilling the next drilling interval of the wellbore
based on the updated bit friction slope and the updated worn bit slope;

wherein the updated bit friction slope and the updated worn bit friction slope are each slopes determined by a ratio of a
change in the torque on bit to a change in the weight on bit.

US Pat. No. 9,074,430

COMPOSITE LIMIT COLLAR

Halliburton Energy Servic...

1. A tubular component comprising:
a limit collar disposed about the tubular component, wherein the limit collar comprises:
a body portion comprising a plurality of upsets disposed on an inner surface of the body portion, wherein the plurality of
upsets define a first ring, a second ring, and at least one rib, wherein the at least one rib comprises one or more channels
extending through the at least one rib;

a plurality of chambers formed between the inner surface of the body portion, an outer surface of the tubular component, and
one or more surfaces of the first ring, the second ring, or the at least one rib, wherein the one or more channels provide
fluid communication between at least two chambers of the plurality of chambers that are adjacent to the at least one rib;

one or more holes disposed through at least one of the first ring, the second ring, and the at least one rib, wherein the
one or more holes are in fluid communication with at least one of the plurality of chambers; and

a binder portion disposed in the at least one chamber of the plurality of chambers.

US Pat. No. 9,291,740

SYSTEMS AND METHODS FOR DOWNHOLE ELECTRIC FIELD MEASUREMENT

Halliburton Energy Servic...

1. A downhole micro-opto-electro-mechanical system (MOEMS) electromagnetic field sensor that includes:
a first surface that is at least partially reflective;
a second surface that is at least partially reflective, said second surface suspended by one or more flexible members to define
an optical cavity having a variable distance between the first and second surfaces;

a first conductive layer attached to the second surface and having a first electric charge, wherein an electric field passing
through the optical cavity interacts with the first electric charge and displaces the second surface to alter the variable
distance and cause a spectrum variation in light exiting the sensor;

a second conductive layer attached to the first surface;
a third conductive layer positioned such that the first conductive layer is located between the second and third conductive
layers;

a first electrode positioned to contact the formation and electrically coupled to the second conductive layer; and
a second electrode positioned to contact the formation at a different location from the first electrode and electrically coupled
to the third conductive layer;

wherein an electrical potential, present in the formation and induced by the electromagnetic field, is applied across the
second and third conductive layers through the first and second electrodes to produce the electric field between the second
and third conductive layers.

US Pat. No. 9,284,476

TREATMENT FLUIDS COMPRISING MAGNETIC SURFACTANTS AND METHODS RELATING THERETO

Halliburton Energy Servic...

1. A method comprising:
providing a treatment fluid comprising a base fluid and a magnetic surfactant, the magnetic surfactant comprising a cationic
surfactant having a magnetically susceptible counterion, wherein the magnetically susceptible counterion comprises at least
one anion of the group of dysprosium chloride, dysprosium sulfide, erbium sulfide, and any derivative thereof; and

introducing the treatment fluid into a wellbore penetrating a subterranean formation; and
applying a magnetic field to the treatment fluid so as to increase a viscosity of the treatment fluid at a location outside
the wellbore.

US Pat. No. 9,284,478

SALT OF WEAK BRONSTED BASE AND BRONSTED ACID AS GELATION RETARDER FOR CROSSLINKABLE POLYMER COMPOSITIONS

Halliburton Energy Servic...

1. A treatment fluid for use in a subterranean formation, the treatment fluid comprising:
(a) a water-soluble polymer, wherein the water-soluble polymer comprises a polymer of at least one non-acidic ethylenically
unsaturated polar monomer;

(b) a polymeric organic cross linker comprising amine groups, wherein the polymeric organic crosslinker is capable of crosslinking
the water-soluble polymer;

(c) a salt of a weak Bronsted base and a Bronsted acid, wherein the salt of a weak Bronsted base and a Bronsted acid is not
a formate or a carbonate and is present in a concentration of at least about 0.1% by weight of water (10 lb/Mgal); and

(d) water;
wherein the treatment fluid comprises a crosslinkable polymer composition.

US Pat. No. 9,200,482

WELLBORE JUNCTION COMPLETION WITH FLUID LOSS CONTROL

Halliburton Energy Servic...

1. A method of installing a wellbore junction assembly in a well, the method comprising:
inserting a first tubular string into a deflector;
sealingly engaging the first tubular string within the deflector; and
opening a flow control device positioned below the deflector with the first tubular string in response to the inserting.

US Pat. No. 9,394,784

ALGORITHM FOR ZONAL FAULT DETECTION IN A WELL ENVIRONMENT

Halliburton Energy Servic...

1. A method, comprising:
placing a first fluid into an annulus surrounding a casing in a borehole, the first fluid containing a first plurality of
radio frequency identification device (RFID) tags;

monitoring a plurality of azimuthally offset regions of the annulus for individual tags of the first plurality of RFID tags,
the plurality of azimuthally offset regions including a first azimuthal region and a second azimuthal region at least partially
offset from the first azimuthal region;

detecting during a first time period, a number of the first plurality of RFID tags in the first azimuthal region; and
detecting during a second time period, a number of the first plurality of RFID tags in the second azimuthal region.

US Pat. No. 9,268,050

DETERMINING A CONFIDENCE VALUE FOR A FRACTURE PLANE

Halliburton Energy Servic...

1. A computer-implemented method for analyzing microseismic data, the method comprising:
selecting a subset of microseismic events associated with a fracture treatment of a subterranean zone; and
determining, by data processing apparatus, confidence in associating the selected subset of microseismic events with a common
fracture plane, wherein the confidence is determined based on a moment magnitude for each microseismic event in the subset.

US Pat. No. 9,103,176

INSTRUMENTED CORE BARREL APPARATUS AND ASSOCIATED METHODS

Halliburton Energy Servic...

1. An instrumented coring apparatus comprising:
an inner core barrel configured to retrieve and contain a core sample;
an outer core barrel;
a coring bit;
an instrumented core barrel comprising an analysis device in fluid communication with the inner core barrel for receiving
a gas released from the core sample contained in the inner core barrel; and

a plurality of seals axially spaced along a length of the inner core barrel and configured to engage the core sample contained
in the inner barrel to create a plurality of isolated sections of the core sample along a length of the inner core barrel
where each of the isolated sections of the core sample are independently in fluid communication with the analysis device.

US Pat. No. 9,068,109

NANO-ENCAPSULATED TRIGGERED-RELEASE VISCOSITY BREAKER

William Marsh Rice Univer...

1. A method of servicing a wellbore in a subterranean formation comprising:
(a) preparing a wellbore servicing a fluid comprising a nanoencapsulate containing a wellbore servicing additive, wherein
the nanoencapsulate is prepared by:

i) providing an amount of a polyelectrolyte having a charge;
ii) providing an amount of a counterion having a valence of at least 2;
iii) combining the polyelectrolyte and the counterion in a solution such that the polyelectrolyte self-assembles to form aggregates;
iv) adding to the aggregates the wellbore servicing additive to be encapsulated; and
v) adding nanoparticles to the solution such that the nanoparticles arrange themselves around the aggregates to form nanoencapsulates
that encapsulate the wellbore servicing additive; and

(b) introducing the wellbore servicing fluid to the wellbore, wherein the wellbore servicing additive is released from the
nanoencapsulates into the wellbore and/or surrounding formation and wherein the release of the wellbore servicing additive
occurs following the addition of a salt solution to the wellbore servicing fluid in an amount effective to produce deformation
of the nanoencapsulates.

US Pat. No. 9,309,454

USE OF EXPANDABLE SELF-REMOVING FILLER MATERIAL IN FRACTURING OPERATIONS

Halliburton Energy Servic...

1. A method comprising:
a) providing a propping fluid comprising a first carrier fluid, a thermal set resin, and a plurality of propping agents;
b) providing a spacer fluid comprising a second carrier fluid and a first expandable filler material, wherein the first expandable
filler material is boric oxide and is present in the range of about 0.001% to about 50% by weight of the spacer fluid;

c) introducing the propping fluid into a fracture in a subterranean formation;
d) introducing the spacer fluid into the fracture by introducing the spacer fluid into the subterranean formation at a location
higher in the fracture relative to the propping fluid in the fracture;

e) exposing the first expandable filler material to an expanding agent that causes the first expandable filler material to
expand and press against adjacent propping agents;

f) allowing the first expandable filler material to degrade, wherein the first expandable filler material generates heat as
it degrades, thereby aiding in curing the thermal set resin in the propping fluid and further degrading the first expandable
filler material; and

g) removing at least 85% of the degraded first expandable filler material from the subterranean formation to achieve a high
porosity fracture having a conductivity of greater than about 40%.

US Pat. No. 9,273,533

WELL TOOL INCLUDING SWELLABLE MATERIAL AND INTEGRATED FLUID FOR INITIATING SWELLING

Halliburton Energy Servic...

3. A method of swelling a first swellable material included in a well tool, the method comprising the steps of:
positioning the well tool in a well; and
then activating a fluid to cause swelling of the first swellable material, wherein the activating step further comprises providing
fluid communication between a first reservoir and the first swellable material, and

wherein the well tool further comprises a second reservoir and a second swellable material, and wherein the activating step
further comprises providing fluid communication between the second reservoir and the second swellable material.

US Pat. No. 9,109,437

METHOD OF USING AN EXPANSION TOOL FOR NON-CEMENTED CASING ANNULUS (CCA) WELLBORES

Halliburton Energy Servic...

1. A method for centralizing an inner casing within an outer casing, comprising:
introducing an expansion tool into the inner casing, the expansion tool having an elongate body having a first force multiplier
case coupled to an expansion tool case;

actuating a piston arranged within the first force multiplier case and thereby moving the piston axially in a first direction
within the first force multiplier case;

engaging a ram arranged within the expansion tool case with the piston, the ram defining a tapered surface engageable with
a correspondingly tapered surface defined on the expansion tool case;

radially expanding one or more lug assemblies arranged within the expansion tool case with the ram as the ram axially translates
in the first direction;

centering the ram within the first force multiplier case while the ram axially translates in the first direction by engaging
the tapered surface of the ram on the correspondingly tapered surface of the expansion tool case; and

plastically deforming the inner casing with the one or more lug assemblies, the one or more lug assemblies generating a corresponding
one or more lobes in the inner casing configured to engage an inner surface of the outer casing.

US Pat. No. 9,279,299

SYSTEM AND METHOD FOR MANAGED PRESSURE DRILLING

Halliburton Energy Servic...

1. A drilling system for managed pressure drilling comprising:
at least one sensor to continually sense at least one real-time fluid property of an input fluid to a well and a return fluid
from the well;

a controllably adjustable flow control apparatus disposed in a return flow line to regulate a flow of the return fluid; and
a controller operably connected to the controllably adjustable flow control apparatus to instruct the controllably adjustable
flow apparatus to regulate the flow of the return fluid to maintain a wellhead setpoint pressure based at least in part on
the real-time sensed fluid property of the input fluid and the return fluid,

wherein the at least one continually sensed fluid property comprises at least one of: fluid density, oil/water ratio, chlorides
content, electric stability, shear stress, gel strength, plastic viscosity, yield point, and combinations thereof.

US Pat. No. 9,756,714

NANO-EMITTER ION SOURCE NEUTRON GENERATOR

Halliburton Energy Servic...

1. A neutron generator comprising:
a housing defining an ion source chamber;
an electron nano-emitter arrangement comprising multiple field electron emitters located in the ion source chamber;
an electrode arrangement comprising an anode separated from the electron nano-emitter arrangement by a separation space, wherein
the separation space holds an ionizable gas; and

a permanent magnet that provides a magnetic field in misalignment with an electric field generated by the electrode arrangement.

US Pat. No. 9,250,350

SYSTEMS AND METHODS FOR DOWNHOLE MAGNETIC FIELD MEASUREMENT

HALLIBURTON ENERGY SERVIC...

1. A downhole micro-opto-electro-mechanical system (MOEMS) electromagnetic field sensor that includes: a first surface that
is at least partially reflective;
a second surface that is at least partially reflective, said second surface suspended by one or more flexible members to define
an optical cavity having a variable distance between the first and second surfaces; and

a magnetically polarized layer attached to the second surface, wherein a magnetic field based on an electromagnetic field
passing through the optical cavity interacts with the magnetically polarized layer and a gradient in the magnetic field produces
a displacement of the second surface that alters the variable distance and causes a spectrum variation in light exiting the
sensor.

US Pat. No. 9,168,612

LASER MATERIAL PROCESSING TOOL

Gas Technology Institute,...

1. A laser material processing tool for processing material within a wellbore, the laser material processing tool comprising:
a laser head assembly comprising a housing having at least one laser energy outlet and a plurality of purge fluid outlets
concentrically disposed around said at least one laser energy outlet;

at least one optical emitter suitable for emitting laser energy disposed within said housing;
laser energy control means for directing said laser energy over a target surface;
at least one automated purge fluid emitter adapted to emit a purge fluid through at least one of said plurality of purge fluid
outlets; and

synchronization means for synchronizing cyclic sequential emissions of said laser energy and said purge fluid directed at
said target surface, said synchronization means comprises activation program for activating purge fluid flow through said
purge fluid outlets in a user-defined programmable sequence,

wherein said sequential emission of laser energy from said at least one optical emitter and emission of purge fluid from said
plurality of purge fluid outlets comprises a laser beam is followed by a purge fluid jet which removes material weakened by
the laser beam from the target surface to form a hole at the target surface.

US Pat. No. 9,617,465

LEAKOFF MITIGATION TREATMENT UTILIZING SELF DEGRADING MATERIALS PRIOR TO RE-FRACTURE TREATMENT

Halliburton Energy Servic...

1. A method of treating a wellbore in a subterranean formation comprising:
combining self-degrading particles with a carrier fluid;
placing the self-degrading particles and the carrier fluid into at least one fracture in a treatment zone in the subterranean
formation;

penetrating and plugging off the connection to existing fractures with the self-degrading particles and bridging off fracture
propagation near the wellbore with the self-degrading particles; and

initiating a re-fracture treatment comprising re-fracture fluids and proppant materials prior to the degradation of the self-degrading
particles and after the penetrating and plugging off of the connection to the existing fractures by the self-degrading particles.

US Pat. No. 9,534,486

METHOD AND SYSTEM FOR TRACKING TIME IN A DOWNHOLE TOOL WITHOUT THE NEED FOR A BATTERY

HALLIBURTON ENERGY SERVIC...

1. A method of tracking time in a downhole tool, the method comprising:
powering up and resetting a first sub-unit of the downhole tool;
starting a first clock in the first sub-unit so that the first clock keeps track of the duration of time since the first sub-unit
was powered up and reset, the first sub-unit logging sensor data samples and associated timestamps from the first clock in
a log;

establishing communication from a second sub-unit in the tool to the first sub-unit and sending a timestamp from a second
clock in the second sub-unit to the first sub-unit, and thereafter the first sub-unit logging sensor data samples and associated
timestamps synchronized to the second clock in the log, and the first sub-unit logging an indication in the log that the timestamps
have been synchronized to the second clock;

processing data downloaded from the log; and
using the indication in the log that the timestamps have been synchronized to the second clock to adjust the timestamps that
were logged prior to the first sub-unit obtaining a timestamp from the second clock.

US Pat. No. 9,518,462

TURBINE FOR TRANSMITTING ELECTRICAL DATA

HALLIBURTON ENERGY SERVIC...

1. A downhole turbine having a first end and a second end with the first end and the second end being opposite one another,
the turbine comprising:
a turbine body;
a shaft positioned at about the center of the turbine body;
a motor comprising a plurality of rotors, stators and bearings interposed between the shaft and the turbine body, the motor
interposed between the first end and the second end of the turbine,

the plurality of rotors and stators disposed radially about the circumference of the shaft arranged in alternating successive
concentric rows, each row one below the other along a longitudinal length of the shaft, the successive rows of rotors rotatable
within apertures formed by the successive rows of stators; and

at least one non-conductor insulator assisting in electrically isolating the shaft and the turbine body from one another,
wherein the non-conductor insulator is a non-conducting coating extending along an entire length interposed between the turbine
body and each of the plurality of rotors, stators and bearings, or extending along an entire length interposed between the
shaft and each of the plurality of rotors, stators and bearings.

US Pat. No. 9,322,649

TOROIDAL LINK FOR RPM MEASUREMENT

Halliburton Energy Servic...

1. A measurement-while-drilling system, comprising:
a lower toroid, wherein the lower toroid has a lower toroid winding and is further adapted to receive a signal from one or
more sensors;

an upper toroid, wherein the upper toroid has a upper toroid winding; and
a magnet disposed along a rotating member within one of the lower toroid or the upper toroid; wherein:
one of the lower toroid or the upper toroid is further adapted to engage the rotating member;
the lower toroid and the upper toroid are disposed so that a signal from the lower toroid is induced in the upper toroid;
and

the lower toroid winding is non-uniform so that the signal from the lower toroid induced in the upper toroid is indicative
of a rotation rate of the rotating member.

US Pat. No. 9,109,338

CONTROLLED DEWATERING OF CONFINED, SATURATED FORMATIONS IN EXCAVATION MINES

Halliburton Energy Servic...

1. A method comprising:
providing an untreated smectite shale barrier confining a saturated formation that comprises water;
accessing the untreated smectite shale barrier adjacent to an excavation mine;
drilling a borehole into the untreated smectite shale barrier from the excavation mine with a dewatering fluid without breaching
the untreated smectite shale barrier into the saturated formation, wherein a portion of the untreated smectite shale barrier
contacted by the dewatering fluid becomes a treated smectite shale barrier that has a greater water permeability than the
untreated smectite shale barrier, wherein the dewatering fluid comprises an aqueous base fluid and a dewatering additive;
and

draining at least a portion of the water from the confined, saturated formation through the treated smectite shale barrier.

US Pat. No. 9,428,980

HYDRAULIC/MECHANICAL TIGHT HOLE JAR

Halliburton Energy Servic...

14. A method of operating a downhole jar, the jar including a housing with a longitudinal axis and a mandrel telescopically
disposed within the housing, the method comprising:
(a) applying a tensile load to the jar so as to move the mandrel relative to the housing in a first axial direction;
(b) compressing a first biasing member that biases the mandrel in a second axial direction that is opposite the first axial
direction with a first biasing force;

(c) removing the first biasing force from the mandrel after sufficient axial movement of the mandrel relative to the housing;
(d) continuing to apply a tensile load to the jar so as to move the mandrel relative to the housing after (c); and
(e) compressing a second biasing member that biases the mandrel in the second axial direction with a second biasing force
during (d).

US Pat. No. 9,376,888

DIVERTING RESIN FOR STABILIZING PARTICULATE IN A WELL

Halliburton Energy Servic...

1. A method of treating a treatment zone of a subterranean formation penetrated by a wellbore of a well, the method comprising:
(A) introducing into the treatment zone a first particulate, wherein:
(i) the first particulate comprises a first degradable material;
(ii) the first particulate comprises a first particulate having a first particulate D50 size selected to bridge a plurality
of pore throats of a first matrix of the treatment zone where the permeability of the first matrix is in the range of 10,000
mD to 100 mD; and

(B) introducing into the treatment zone a second particulate, wherein:
(i) the second particulate comprises a second degradable material;
(ii) the second particulate comprises a second particulate having a second particulate D50 size selected to bridge a plurality
of pore throats of a second matrix of the treatment zone, where the permeability of the second matrix is in the range of 5,000
mD to 50 mD subject to the second matrix permeability also being less than one-half the first matrix permeability;

(iii) the first degradable material and the second degradable material can be the same or different; and
(iv) the second particulate is introduced into the treatment zone simultaneously with the first particulate or separately
from the first particulate but at least before the first degradable material of the first particulate degrades more than 50%
by weight in the treatment zone; and

(C) introducing into the treatment zone a liquid resin, wherein the liquid resin is introduced into the treatment zone:
(i) simultaneously with the first particulate or separately from the first particulate but at least before the first degradable
material of the first particulate degrades more than 50% by weight in the treatment zone; and

(ii) simultaneously with the second particulate or separately from the second particulate but at least before the second degradable
material of the second particulate degrades more than 50% by weight in the treatment zone.

US Pat. No. 9,322,947

ACOUSTIC RECEIVER ASSEMBLY FOR DOWNHOLE TOOLS

Halliburton Energy Servic...

1. An acoustic receiver for use in a downhole environment, comprising:
a linear central structure defining a non-linear acoustic path along at least a portion of its length;
a plurality of mass members coupled to the central structure along at least a portion of its length, each mass member coupled
in spaced relation to an adjacent mass member, and physically and acoustically coupled to the central structure;

a plurality of coupling mechanisms, each coupling mechanism coupling a respective mass member to a respective adjacent mass
member, wherein each coupling mechanism facilitates relative movement between the respective coupled mass members within a
range of motion, and precludes relative movement beyond such range of motion; and

at least one receiver assembly supported by at least one of the mass members.

US Pat. No. 9,322,247

SYSTEMS AND METHODS OF HARVESTING INFORMATION FROM A WELL-SITE

Halliburton Energy Servic...

1. A system for collecting information of a rig operation, the system comprising:
an integrated control system;
wherein the integrated control system monitors one or more rig operations;
wherein the integrated control system comprises a centralized data acquisition server communicatively coupled to one or more
functional units;

at least one memory;
at least one processor executing the steps comprising:
receiving data from a sensor corresponding to the one or more functional units;
storing the data in a central time-synchronized database in the at least one memory, wherein the central time-synchronized
database is accessible by the centralized data acquisition server;

collecting the data from a plurality of the functional units to generate a time synchronized overview of rig operations; wherein
the overview of rig operations is operable to monitor the data from the plurality of the functional units at a single location;

monitoring a quality of the data based, at least in part, on a flag status;
processing the data from the plurality of functional units to generate a report, wherein the report is accessible by a rig
operation personnel on a display, further wherein the report is operable to identify a metric, wherein the metric is operable
to assist the rig operation personnel in analyzing deviations in the one or more rig operations.

US Pat. No. 9,291,789

PUMPING OF OPTICAL WAVEGUIDES INTO CONDUITS

Halliburton Energy Servic...

1. An optical waveguide pumping method, comprising:
pumping a liquid fluid through a conduit, thereby causing an optical waveguide to extend further into the conduit; and
operating a fluid recovery device, thereby causing a condition to exist in the conduit, the condition being selected from
the group consisting of: a) fluid pressure in the conduit being less than a vapor pressure of the fluid, and b) fluid temperature
in the conduit being reduced from above a boiling point temperature of the fluid to below the boiling point temperature of
the fluid.

US Pat. No. 9,075,252

REMOTE WORK METHODS AND SYSTEMS USING NONLINEAR LIGHT CONVERSION

Halliburton Energy Servic...

1. A remote work system, comprising:
a light source;
a nonlinear light converter optically coupled to and remote from the light source, wherein the nonlinear light converter converts
a narrowband light pulse received from the light source to a converted spectrum light pulse corresponding to a supercontinuum
light pulse or a shifted spectrum light pulse; and

a work element in situ with and coupled to the nonlinear light converter, wherein the work element performs an operation using
the converted spectrum light pulse.

US Pat. No. 9,390,064

MODELING TOOL PASSAGE THROUGH A WELL

Halliburton Energy Servic...

1. A computer-implemented method for modeling passage of an elongate well tool through a well, the method comprising:
receiving, with a computing system, inputs representing a plurality of geometric characteristics of the well tool including
three dimensional surface data characterizing the shape of outwardly facing, lateral surfaces of the well tool;

receiving, with the computing system, inputs representing a plurality of geometric characteristics of the well;
determining, with the computing system, a radial position of the well tool within the well and relative to a radial surface
of the well due to loads on the well tool; and

determining, with the computing system, a prediction of the force to pass the well tool through at least a portion of the
well based on a comparison of the three dimensional surface data of the well tool, the radial position of the well tool relative
to the well, and the plurality of geometric characteristics of the well.

US Pat. No. 9,080,391

INSULATED CONDUCTOR FOR DOWNHOLE DRILLING EQUIPMENT AND METHOD

Halliburton Energy Servic...

26. A method of conducting electricity in a well drilling operation, the method comprising:
providing a downhole drilling motor, the motor including:
a tubular housing having a first longitudinal end and a second longitudinal end and a longitudinal bore having a sidewall,
a stator disposed in the longitudinal bore of the tubular housing, said stator defining an internal cavity passing therethrough,
wherein the stator includes a first protective electrically insulated layer, a second protective electrically insulated layer,
and an electrically conductive layer disposed between the first and second electrically protective insulated layers, the first
protective electrically insulated layer being disposed as a first substantially circumferential layer adjacent to an inner
surface of the sidewall of the longitudinal bore of the tubular housing, the electrically conductive layer being disposed
as a second substantially circumferential layer upon at least a portion of an inner surface of the first protective layer,
and the second protective electrically insulated layer being disposed as a third substantially circumferential layer upon
at least a portion of an inner surface of the electrically conductive layer, said electrically conductive layer coupled at
a first end to a first electrical end conductor disposed proximal to the first longitudinal end of the tubular housing and
coupled at a second end to a second electrical end conductor disposed proximal to the second longitudinal end of the tubular
housing, and

a rotor operatively positioned in the internal cavity to cooperate with the stator; providing electrical current to the conductive
layer from the first electrical end conductor located proximal to the first longitudinal end;

conducting the electrical current along the conductive layer from the first longitudinal end of the housing to the second
longitudinal end of the housing; and

receiving the electrical current from the conductive layer at the second electrical end conductor located proximal to the
second longitudinal end of the housing.

US Pat. No. 9,429,009

METHODS AND SYSTEMS FOR PROVIDING A PACKAGE OF SENSORS TO ENHANCE SUBTERRANEAN OPERATIONS

Halliburton Energy Servic...

1. An integrated system for enhancing the performance of subterranean operations comprising:
an integrated control system;
wherein the integrated control system monitors one or more subterranean operations;
wherein the integrated control system comprises a centralized functional unit communicatively coupled to one or more functional
units that require monitoring;

wherein the one or more functional units record data;
wherein the centralized functional unit monitors the one or more functional units based, at least in part, on the recorded
data;

a package of sensors, wherein the package of sensors comprises a plurality of sensors, and wherein the plurality of sensors
comprises at least two different types of sensors; and

wherein the package of sensors is communicatively coupled to at least one of the one or more functional units, wherein the
centralized function unit receives data from the package of sensors corresponding to the at least one of the one or more functional
units.

US Pat. No. 9,304,054

NON-ELECTRONIC AIR CHAMBER PRESSURE SENSOR

HALLIBURTON ENERGY SERVIC...

20. A method of determining whether a seal has failed between a first chamber and a second chamber in a downhole apparatus,
the first chamber having disposed therein a sealed, compressible container, the container having first and second magnets
disposed therein, the first and second magnets being separated by a first distance when a fluid within the sealed, compressible
container is at a first pressure, the method comprising:
changing a pressure of fluid within the second chamber;
determining a measured distance between the magnets; and
comparing the measured distance to the first distance.

US Pat. No. 9,296,939

COMPOSITIONS FOR MODIFYING RHEOLOGICAL PROPERTIES OF CEMENT SYSTEMS

Halliburton Energy Servic...

1. A method of servicing a wellbore penetrating a subterranean formation comprising:
contacting a wellbore servicing composition comprising a cementitious material with a rheology modifying additive, wherein
the rheology modifying additive comprises a gum and a polymeric material; wherein the gum has an average molecular weight
in the range of from about 20,000 Daltons to about 10,000,000 Daltons; wherein the polymeric material comprises acrylamide
vinyl phosphoric acid, NN-dimethyl acrylamide, lignite grafted acrylamide, tannin grafted 2-acrylamido-2-methylpropane sulfonic
acid polymer, humate grafted acrylamide diallyldimethlyammonium chloride, acrylic acid, itaconic acid, or combinations thereof:

wherein the wellbore servicing composition comprises water and has a water content of from about 80 wt. % to about 125 wt.
% by weight of cement; and wherein the composition has a plastic viscosity of from about 1 cP to about 300 cP.

US Pat. No. 9,151,138

INJECTION OF FLUID INTO SELECTED ONES OF MULTIPLE ZONES WITH WELL TOOLS SELECTIVELY RESPONSIVE TO MAGNETIC PATTERNS

Halliburton Energy Servic...

6. A method of actuating at least one well tool in a well, the method comprising:
producing a first magnetic pattern in the well, thereby transmitting a corresponding first magnetic signal to the well tool,
wherein the first magnetic pattern comprises a predetermined spacing in time between displacement of first and second magnetic
devices in the well; and

the well tool actuating in response to detection of the first magnetic signal.

US Pat. No. 9,052,124

VERY HIGH PRESSURE SAMPLE CAPTURE AND TRANSPORTATION VESSEL

Halliburton Energy Servic...

1. A method comprising:
acquiring a pressure vessel, the pressure vessel including:
a cylindrical sample compartment having an inner volume,
a sample piston slidingly located within the sample compartment;
an annulus piston slidingly located within the sample compartment;
reducing the inner volume of the cylindrical sample volume by securely sealing a sleeve within the cylindrical sample compartment,
the sleeve having an inner diameter;

replacing the sample piston with a replacement sample piston having a diameter substantially the same as the inner diameter
of the sleeve; and

replacing the annulus piston with a replacement annulus piston having a diameter substantially the same as the inner diameter
of the sleeve.

US Pat. No. 9,465,133

DOWNHOLE DIFFERENTIATION OF LIGHT OIL AND OIL-BASED FILTRATES BY NMR WITH OLEOPHILIC NANOPARTICLES

Halliburton Energy Servic...

1. A method comprising:
drilling a wellbore penetrating a subterranean formation;
measuring a first porosity distribution for the subterranean formation with a first nuclear magnetic resonance (NMR) wellbore
tool;

reaming a wellbore surface to remove a filter cake from the wellbore, thereby yielding a reamed wellbore;
introducing a wellbore fluid into the reamed wellbore, the wellbore fluid comprising an oil base fluid and a plurality of
oleophilic nanoparticles;

measuring a second porosity distribution of the subterranean formation with a second NMR wellbore tool; and
determining a vug porosity of the subterranean formation based on a comparison of the first porosity distribution in the second
porosity distribution.

US Pat. No. 9,310,514

METHOD AND SYSTEM OF DETERMINING ELEMENTAL CONTENT OF AN EARTH FORMATION

Halliburton Energy Servic...

1. A method comprising:
irradiating with neutrons a portion of a formation that surrounds a borehole with a source of neutrons from a tool positioned
in the borehole;

counting gammas of different energy levels in response to the irradiation to obtain a spectrum of counted gammas with a gamma
detector positioned in the borehole;

finding a solution to a system of equations based on the spectrum of counted gammas, which system of equations has a plurality
of solutions, the solution being indicative of a plurality of weight percentages for a respective plurality of elements within
the formation;

determining whether the solution meets a predetermined constraint on the relative weight percentages indicated for at least
two of the elements within the formulation;

repeating the finding and determining until a solution is found that is determined to meet the predetermined constraint; and
outputting an indication of the elemental content of the formation using the solution that meets the predetermined constraint.

US Pat. No. 9,296,938

RADIATION-INDUCED TRIGGERING FOR SET-ON-COMMAND SEALANT COMPOSITIONS

Halliburton Energy Servic...

1. A sealant composition comprising:
a wellbore treatment fluid;
a set modifier; and
a polymeric component that inhibits release of the set modifier,
wherein the polymeric component comprises one or more polymers selected from the group consisting of copolymers of methyl-methacrylate
(MMA) with a o-substituted chloro or cyano acrylate, MMA based polymers with incorporation of fluorine into the methacrylates,
polymers having a Photosensitive Acid Generator group (PAG) in the polymer structure; and combinations thereof;

wherein exposure to ionizing radiation causes degradation of the polymeric component resulting in release of the set modifier
and an increase in the mechanical strength of the sealant composition.

US Pat. No. 9,359,882

MONITOR AND CONTROL OF DIRECTIONAL DRILLING OPERATIONS AND SIMULATIONS

Halliburton Energy Servic...

1. A method comprising:
receiving data wirelessly in a mobile device, the data including performance data of a directional drilling operation downhole
at a drill site, the mobile device being a hand mobile communication device; and

displaying a representation of the data on a graphical user interface screen of the mobile device including displaying a graphical
representation of a downhole component disposed as part of a drill string that shows animated movement in an interior of the
downhole component.

US Pat. No. 9,334,727

DOWNHOLE FORMATION FLUID CONTAMINATION ASSESSMENT

Halliburton Energy Servic...

1. A method of detecting synthetic mud filtrate or determining filtrate contamination in a downhole fluid, comprising:
placing a downhole tool into a wellbore;
introducing a downhole fluid sample into the downhole tool; analyzing the downhole fluid sample in the downhole tool;
producing at least two filtrate markers from the analyzing of the downhole fluid sample; and
converting the at least two filtrate markers by vector rotation to a sufficiently orthogonal signal.
US Pat. No. 9,518,206

INVERT EMULSION FLUID CONTAINING A HYGROSCOPIC LIQUID, A POLYMERIC SUSPENDING AGENT, AND LOW-DENSITY SOLIDS

Halliburton Energy Servic...

1. An invert emulsion treatment fluid comprising:
(A) an external phase, wherein the external phase comprises a hydrocarbon liquid;
(B) an internal phase, wherein the internal phase comprises a hygroscopic liquid;
(C) a suspending agent, wherein the suspending agent is a polymer, and wherein the polymer comprises urea linkages; and
(D) a particulate, wherein the particulate has a density less than 3.5 g/cm3, wherein the particulate is in a concentration in the range of about 35 to about 200 pounds per barrel of the treatment fluid,

wherein a test fluid consisting essentially of the external phase, the internal phase, the suspending agent, and the particulate,
and in same proportions as the treatment fluid, and after static aging for 2 months at a temperature of 200° F. (93.3° C.),
has a 10 minute gel strength of at least 30 lb/100 ft2 (1,436 Pa) at a temperature of 120° F. (48.9° C.).

US Pat. No. 9,222,828

DOWNHOLE FLOW MEASUREMENTS WITH OPTICAL DISTRIBUTED VIBRATION/ACOUSTIC SENSING SYSTEMS

Halliburton Energy Servic...

1. A method of verifying a substance interface location during a cementing operation, the method comprising:
optically measuring vibrations caused by substances flowing across structures distributed along a wellbore, the vibrations
being caused at each structure; and

the vibrations changing at each structure as the interface displaces across the structure during the cementing operation.

US Pat. No. 9,157,297

PUMP-THROUGH FLUID LOSS CONTROL DEVICE

HALLIBURTON ENERGY SERVIC...

1. A method of controlling flow in a subterranean well extending through a hydrocarbon bearing formation, the method comprising
the steps of:
disposing a downhole submersible pump in said well, said pump defining a critical reverse flow rate;
selecting a one-way primary valve characterized by a low resistance to flow and a low opening differential pressure;
disposing said primary valve within a standing valve assembly so as to allow uphole flow;
selecting a one-way pump-through valve characterized by a high resistance to flow and a high opening differential pressure
so that a flow rate through said pump-through valve at said high opening differential pressure is less than said critical
reverse flow rate;

disposing said pump-through valve within said standing valve assembly so as to allow downhole flow;
disposing said standing valve assembly in said well uphole of said submersible pump;
opening the primary valve in response to a differential pressure acting upward across the primary valve greater than said
low opening differential pressure;

pumping fluid by said submersible pump through the primary valve;
closing the primary valve in response to a differential pressure acting upward across the primary valve less than said low
opening differential pressure;

opening the pump-through valve in response to a differential pressure acting downward across the pump-through valve greater
than said high opening differential pressure; and

flowing fluid downward through the pump-through valve while the first one-way valve is closed.

US Pat. No. 9,110,166

ACOUSTIC IMAGING

Halliburton Energy Servic...

1. A method comprising:
acquiring an acoustic wave at a detector, the acoustic wave propagating from a target to the detector, the target being acoustically
illuminated to provide the acoustic wave; and

processing, in a model using a processor, a signal from the detector in response to acquiring the acoustic wave to provide
pressure and its spatial derivatives such that the processing implements a synthetic acoustic lens based on the pressure and
its spatial derivatives to generate an image of the target.

US Pat. No. 9,068,426

FLUID BYPASS FOR INFLOW CONTROL DEVICE TUBE

Halliburton Energy Servic...

1. An inflow control device tube comprising:
a body; and
an inlet portion at a first end of the body, wherein the inlet portion is adapted to provide a fluid bypass for a fluid flowing
from the inlet portion to an outlet portion at a second end of the body, wherein the fluid bypass is shaped to allow the fluid
to bypass one or more objects causing a blockage at an opening of the inlet portion, wherein the fluid bypass comprises a
slotted fluid bypass, the slotted fluid bypass comprising a plurality of protrusions at the first end of the body, wherein
each of the plurality of protrusions extends an inner surface of the body to an edge of the opening of the inlet portion,
wherein the plurality of protrusions are located at a plurality of intervals to allow the fluid to bypass the opening and
enter the body via a gap between two of the plurality of protrusions, wherein the body is a tubular body having a diameter
and a length that creates a pressure differential in the fluid flowing from the inlet portion to the outlet portion.

US Pat. No. 10,030,191

NANOPARTICLE KINETIC GAS HYDRATE INHIBITORS

Halliburton Energy Servic...

1. A method of transporting hydrocarbon fluids, the method comprising:providing a kinetic gas hydrate inhibitor that comprises a rubber latex and a heterocyclic compound comprising nitrogen;
adding the kinetic gas hydrate inhibitor to a fluid capable of producing gas hydrates; and
transporting the fluid that comprises the kinetic gas hydrate inhibitor.

US Pat. No. 9,494,015

DUAL CLOSURE SYSTEM FOR WELL SYSTEM

Halliburton Energy Servic...

1. A dual closure system configured for being disposed in a wellbore through a fluid-producing formation, the dual closure
system comprising:
a subsurface safety valve comprising a body having an active closure mechanism configured to be positioned in a passageway
defined by a tubing string, the subsurface safety valve being coupleable to a control line; and

a passive closure mechanism coupleable to the tubing string such that the passive closure mechanism is physically separated
from the control line by the body of the subsurface safety valve,

wherein the passive closure mechanism is configured to be in a closed position that prevents a flow of fluid to a portion
of the passageway that is closer to a surface of the wellbore than the passive closure mechanism in the absence of the subsurface
safety valve in the tubing string, and wherein the subsurface safety valve is configured to be positioned in the passageway
of the tubing string such that the subsurface safety valve causes the passive closure mechanism to be in an open position
that allows the flow of fluid to a second portion of the passageway that is closer to the surface of the wellbore than the
passive closure mechanism.

US Pat. No. 9,321,954

CONSOLIDATION COMPOSITIONS FOR USE IN SUBTERRANEAN FORMATION OPERATIONS

Halliburton Energy Servic...

1. A method comprising:
providing a consolidation composition comprising the reaction product of a liquid curable resin and a liquid curing agent,
wherein the liquid curable resin is an epoxy-functionalized alkoxysilane, and
wherein the liquid curing agent is selected from the group consisting of: a hydrophobically modified polyamine; a hydrophobically
modified polyimine; hydrophobically modified polyacrylamide; a hydrophobically modified polyacrylate; and any combination
thereof, and

wherein the liquid curing agent is present in the range of from about 0.1% to about 10% by weight of the consolidation composition;
coating proppant particulates with the consolidation composition, thereby creating coated proppant particulates;
introducing the coated proppant particulates into a subterranean formation and placing the coated proppant particulates into
a fracture therein; and

curing the consolidation composition so as to consolidate the coated proppant particulates in the fracture and form a proppant
pack therein.

US Pat. No. 9,315,713

AMPHOTERIC POLYMER SUSPENDING AGENT FOR USE IN CALCIUM ALUMINATE CEMENT COMPOSITIONS

HALLIBURTON ENERGY SERVIC...

1. A method of cementing in a subterranean formation comprising:
introducing a cement composition into the subterranean formation, wherein the cement composition comprises:
(A) a calcium aluminate cement or calcium magnesia cement;
(B) water;
(C) a fluid loss additive; and
(D) a suspending agent, wherein the suspending agent is a polymer and wherein the polymer:
(i) is amphoteric;
(ii) has a molecular weight greater than 100,000; and
(iii) does not increase the fluid loss of the cement composition greater than 15% at a temperature of 145° F. and a pressure
differential of 1,000 psi compared to a test cement composition consisting of the cement, the water, and the fluid loss additive
and in the same proportions as the cement composition; and

causing or allowing the cement composition to set after the step of introducing.

US Pat. No. 9,158,031

INTERCHANGEABLE MEASUREMENT HOUSINGS

Halliburton Energy Servic...

1. A system comprising:
a sensor housing containing a detector, the sensor housing arranged for placement with a drill-string element, the sensor
housing being a modular unit of hardware to make measurements in a well; and

a processor operable to apply calibration coefficients from a data storage unit relative to a measurement reading from the
detector such that the sensor housing is transferable to another drill-string element without a calibration measurement during
or after the transfer, the calibration coefficients including calibration data correlated to variations in spacing and/or
orientation associated with the detector due to the transfer to another drill-string element.

US Pat. No. 9,068,425

SAFETY VALVE WITH ELECTRICAL ACTUATOR AND TUBING PRESSURE BALANCING

Halliburton Energy Servic...

1. A well tool for use with a subterranean well, the well tool comprising:
a flow passage extending longitudinally through the well tool;
an internal chamber containing a dielectric fluid, wherein the chamber is in fluid communication with a source of the dielectric
fluid via a conduit extending to a remote location, and wherein a line extends through the conduit to an actuator in the chamber;
and

a flow path extending between the internal chamber and the flow passage, the flow path including first, second, and third
longitudinal flow path sections, the first longitudinal flow path section being connected to a first end of the second longitudinal
flow path section, and the third longitudinal flow path section being connected to a second end of the second longitudinal
flow path section opposite the first end, whereby communication between the internal chamber and the flow passage via the
flow path reverses longitudinal direction at least twice.

US Pat. No. 9,051,508

METHODS OF PREVENTING EMULSIFICATION OF CRUDE OIL IN WELL BORE TREATMENT FLUIDS

Halliburton Energy Servic...

1. A method of preventing emulsification of crude oil into an aqueous-based treatment fluid, comprising:
contacting crude oil in a well bore with the aqueous-based treatment fluid comprising a styrene-acrylate copolymer, wherein
the aqueous-based treatment fluid has a density of about 12 pounds per gallon to about 18 pounds per gallon, wherein the crude
oil has an API gravity of about 10 or greater; and

allowing the styrene-acrylate copolymer to interact with the crude oil in the well bore; wherein the crude oil is not emulsified.

US Pat. No. 9,642,240

PRINTED CIRCUIT BOARD ASSEMBLIES AND A WELLBORE SYSTEM

Halliburton Energy Servic...

1. A printed circuit board assembly comprising:
a non-conductive substrate having a plurality of planar conductive pathways disposed thereon;
an electronic component that is in electrical communication with one or more of the planar conductive pathways and is configured
to supply an electrical current thereto;

a superficial metallic conductor overlaying one or more of the planar conductive pathways, at least in part, the superficial
metallic conductor being electrically connected to the electronic component via one or more leads attached to the superficial
metallic conductor and the electronic component; and

wherein the superficial metallic conductor is also in electrical communication with the planar conductive pathways;
a current-withdrawing conductive element in electrical communication with the superficial metallic conductor, and
wherein the current-withdrawing conductive element comprises a bus bar elevated above a surface of the non-conductive substrate
by an electrically conductive standoff that establishes electrical communication between the superficial metallic conductor
and the bus bar.

US Pat. No. 9,410,388

ACOUSTIC GENERATOR AND ASSOCIATED METHODS AND WELL SYSTEMS

Halliburton Energy Servic...

1. A well system, comprising:
an acoustic generator which transmits acoustic waves into an annulus surrounding a well screen;
a vibration isolation device between the acoustic generator and a string on which the acoustic generator is conveyed; and
an isolator section to reflect or attenuate acoustic energy associated with the acoustic waves.

US Pat. No. 9,388,332

CHEMICALLY TAGGED POLYMERS FOR SIMPLIFIED QUANTIFICATION AND RELATED METHODS

Halliburton Energy Servic...

1. A method comprising:
obtaining a sample of a return drilling fluid, the return drilling fluid containing a tagged detectable additive, the tagged
detectable additive comprising a polymer comprising at least one chemical tag covalently bonded to the polymer wherein the
chemical tag comprises a plurality of compounds containing radio-labeled isotopes of at least one from the group consisting
of 13N, 18F, 76Br, 123I, and 124I; and

determining a concentration of the tagged detectable additive in the return drilling fluid by measuring the concentration
of the at least one radio-labeled isotope in the sample.

US Pat. No. 9,359,545

BRANCHED VISCOELASTIC SURFACTANT FOR HIGH-TEMPERATURE ACIDIZING

Halliburton Energy Servic...

1. A method of treating a zone of a subterranean formation penetrated by a wellbore, the method comprising the steps of:
(A) forming a treatment fluid comprising:
(i) water;
(ii) strong acid; and
(iii) a branched viscoelastic surfactant having a hydrophobic portion with a total of 16 to 20 carbons;
wherein the treatment fluid has an initial pH of less than 0.5; and
wherein the treatment fluid has a viscosity of less than 5 cP at 40 sec?1 at the initial pH;

(B) introducing the treatment fluid through the wellbore into the zone; and
(C) allowing time for the strong acid in the treatment fluid to spend in the formation.

US Pat. No. 9,274,038

APPARATUS AND METHOD FOR CONSTANT SHEAR RATE AND OSCILLATORY RHEOLOGY MEASUREMENTS

HALLIBURTON ENERGY SERVIC...

1. A rheometer that comprises:
a rotatable sleeve that defines a cylindrical cavity;
a cylindrical bob positioned within the cavity to define an annular space, the bob being supported by a cross-spring pivot
that permits limited rotation of the bob;

a force rebalance system that senses rotation of the bob and imposes a feedback force to counter any deviation of the bob
from a reference point; and

a processor that derives at least one viscoelastic parameter for a fluid in the annular space based at least in part on the
feedback force.

US Pat. No. 9,256,701

MODELING WELLBORE FLUIDS

Halliburton Energy Servic...

1. A computer-implemented method of modeling a wellbore fluid that comprises a base fluid and one or more fluid additives,
the method comprising:
identifying, with a hardware computer processor, a target viscosity profile of the wellbore fluid;
determining, with the hardware computer processor, an initial set of values of the fluid additives that are based at least
in part on the target viscosity profile;

determining, with the hardware computer processor, with one or more non-linear predictive models, a computed viscosity profile
of the wellbore fluid and a computed set of values of the fluid additives based, at least in part, on the initial set of values
of the fluid additives;

determining, with the hardware computer processor, with one or more non-linear predictive models, an inverse computed set
of values of the fluid additives based, at least in part, the computed set of values of the fluid additives and the computed
viscosity profile;

comparing, with the hardware computer processor, the computed viscosity profile with the target viscosity profile and at least
one of the inverse computed set of values of the fluid additives with at least one of the initial set of values of the fluid
additives;

preparing, with the hardware computer processor, based on the comparison, an output comprising at least one of the computed
viscosity profile or the computed set of values; and

controlling, with the hardware computer processor, one or more properties of the wellbore fluid based on the comparison.

US Pat. No. 9,189,576

ANALYZING SAND STABILIZATION TREATMENTS

Halliburton Energy Servic...

1. A method comprising:
determining, by a computing system, a first predicted resource production output for a subterranean reservoir based on a sand
stability model analysis for a native condition of the subterranean reservoir;

determining, by the computing system, a second predicted resource production output for the subterranean reservoir based on
a sand stability model analysis for a stabilization-treated condition of the subterranean reservoir; and

outputting an economic value comparison of resource production for the native condition and resource production for the stabilization-treated
condition based on the first predicted resource production output and the second predicted resource production output.

US Pat. No. 9,176,052

SYSTEMS AND METHODS FOR INSPECTING AND MONITORING A PIPELINE

Halliburton Energy Servic...

1. A system for inspecting and monitoring an inner surface of a pipeline, comprising:
a movable inline inspection device arranged within the pipeline;
one or more optical computing devices arranged on the movable inline
inspection device adjacent the inner surface of the pipeline for monitoring at least one substance present on the inner surface,
the one or more optical computing devices comprising:

an electromagnetic radiation source configured to emit electromagnetic radiation that optically interacts with the at least
one substance;

at least one integrated computational element configured to optically interact with the at least one substance and thereby
generate optically interacted light;

a first detector arranged to receive the optically interacted light and generate an output signal corresponding to a characteristic
of the at least one substance; and

a second detector configured to generate a compensating signal indicative of radiating deviations of the electromagnetic radiation
source; and

a signal processor configured to computationally combine the output signal of the first detector and the compensating signal
of the second detector and provide a resulting output signal.

US Pat. No. 9,068,396

ANTI-STALL MECHANISM

Halliburton Energy Servic...

1. A locking clutch to selectively transmit torque from a rotatable stator coupled to a drilling motor positionable in a wellbore
and a rotatable output shaft coupled to a rotatable rotor of the drilling motor, said locking clutch comprising:
a plurality of slidable locking blocks slidably coupled to the rotatable output shaft, said slidable locking blocks slidable
radially inwardly and outwardly with respect to a central longitudinal axis of the rotatable output shaft, said slidable locking
blocks spaced apart circumferentially about the rotatable output shaft, each of said slidable locking blocks having a first
contacting face and a second contacting face; and

a plurality of fixed locking blocks coupled to the rotatable stator, said fixed locking blocks positioned radially around
the rotatable output shaft and spaced apart circumferentially about an interior of the rotatable stator a distance sufficient
to receive one of the slidable locking blocks when it moves inwardly toward the central axis of the rotatable output shaft,
each of said fixed locking blocks having a first contacting face and a second contacting face.

US Pat. No. 10,150,907

SEQUENTIAL SURFACTANT TREATMENTS FOR ENHANCING FRACTURING FLUID RECOVERY

Halliburton Energy Servic...

13. A method comprising:introducing an aqueous fracturing fluid that comprises a first surfactant into a well bore penetrating at least a portion of a subterranean formation at or above a pressure sufficient to create or enhance a fracture in the subterranean formation, wherein
the fracture comprises a fracture face,
the aqueous fracturing fluid does not comprise proppant particulates, and
the first surfactant comprises a hydrophobic tail;
introducing the first surfactant into the fracture such that the first surfactant forms an oil-wet layer on at least a portion of the fracture face in the fracture;
ceasing the introduction of the first surfactant into the fracture;
introducing a second surfactant that comprises a hydrophobic tail into the fracture, wherein the hydrophobic tail of the second surfactant is attracted to the hydrophobic tail of the first surfactant in the fracture such that the second surfactant forms a water-wet layer on top of at least a portion of the oil-wet layer; and
allowing at least a portion of the aqueous fracturing fluid to flow out of the well bore after the second surfactant has increased the water-wettability of at least a portion of the fracture face in the fracture.

US Pat. No. 9,404,358

WIPER PLUG FOR DETERMINING THE ORIENTATION OF A CASING STRING IN A WELLBORE

HALLIBURTON ENERGY SERVIC...

1. A system for determining a circumferential orientation of a casing string relative to a wellbore in which the casing string
extends, the system comprising:
a latch coupling interconnected in the casing string and having a fixed circumferential orientation relative thereto, wherein
the latch coupling and the casing string are together permitted to rotate relative to the wellbore;

a wiper plug received and maintained within the latch coupling in a known circumferential orientation relative to the casing
string;

a sensor module operably associated with the wiper plug and configured to obtain data relating to the circumferential orientation
of the wiper plug and thus the circumferential orientation of the latch coupling together with the casing string, relative
to the wellbore; and

a communication module operably associated with the sensor module, the communication module configured to transmit information
to a surface location, wherein the information corresponds to the data obtained by the sensor module relating to the circumferential
orientation of the wiper plug, the latch coupling, and the casing string, relative to the wellbore.

US Pat. No. 9,366,095

TUBULAR STRING DISPLACEMENT ASSISTANCE

Halliburton Energy Servic...

1. A tubular string displacement assistance device, comprising:
at least first and second flow paths in fluid communication with a flow passage; and
a blocking member that blocks flow through the first flow path in response to the flow through the first flow path, and blocks
flow through the second flow path in response to the flow through the second flow path, wherein change of blocking through
the first flow path and change of blocking through the second flow path follows reversal of flow in the respective first flow
path or second flow path.

US Pat. No. 9,255,468

CHELATING AGENT-BASED SELF-DIVERTING ACIDIZING FLUIDS AND METHODS RELATING THERETO

Halliburton Energy Servic...

1. A method comprising:
providing or preparing a complexing-acidizing treatment fluid having a pH of about 2 or less and comprising:
an aminopolycarboxylic acid chelating agent, any salt thereof, or any derivative thereof,
an aqueous base fluid, and
an acid having a concentration of at least about 0.6 Molar in the complexing-acidizing treatment fluid;
placing the complexing-acidizing treatment fluid in a carbonate subterranean formation matrix penetrated by a well bore;
allowing the acid in a first portion of the treatment fluid to generate metal cations by dissolution of a first portion of
the subterranean formation matrix;

reacting the aminopolycarboxylic acid chelating agent in the first portion of the treatment fluid with the metal cations so
as to form at least a plurality of aggregate blocking agents in wormholes within the carbonate subterranean formation matrix;
and

allowing the plurality of aggregate blocking agents to divert a second portion of the complexing-acidizing treatment fluid
to a main channel in a second portion of the carbonate subterranean formation matrix that is distinct from the wormholes.

US Pat. No. 9,227,872

CEMENT SET ACTIVATORS FOR SET-DELAYED CEMENT COMPOSITIONS AND ASSOCIATED METHODS

Halliburton Energy Servic...

1. A method of cementing in a subterranean formation, comprising:
providing a set-delayed cement composition comprising water, pumice, hydrated lime, a phosphonic acid derivative set retarder,
and a polycarboxylated ether dispersant;

activating the set-delayed cement composition with a cement set activator, wherein the cement set activator comprises at least
one activator selected from the group consisting of nanosilica, a polyphosphate, and combinations thereof;

introducing the set-delayed cement composition into a subterranean formation; and
allowing the set-delayed cement composition to set in the subterranean formation.

US Pat. No. 9,222,349

CEMENTING PLUG TRACKING USING DISTRIBUTED STRAIN SENSING

Halliburton Energy Servic...

14. A downhole cementing plug tracking method that comprises:
introducing a first cementing plug, coupled to a fixed point along an optical cable, into a borehole casing at least partially
filled with fluid;

injecting a cement slurry into the borehole casing behind the first cementing plug while maintaining tension on the optical
cable;

introducing a second cementing plug into the borehole casing behind the cement slurry, the second cementing plug being traversed
by the optical cable and slidably coupled to the optical cable, and the second cementing plug comprising a frictional coupler
engaging the optical cable to cause a detectable feature in a strain profile along the optical cable at any location along
a downhole portion of the optical cable;

injecting fluid behind the second cementing plug and tracking borehole positions of the first and second cementing plugs based
at least in part on a tracked location of the detectable feature; and

presenting to a user the tracked borehole positions of the first and second cementing plugs.

US Pat. No. 9,194,222

SYSTEM AND METHOD FOR IMPROVED PROPPED FRACTURE GEOMETRY FOR HIGH PERMEABILITY RESERVOIRS

Halliburton Energy Servic...

1. A method of determining a pad volume and a proppant volume for fracturing a subterranean formation comprising:
selecting an initial proppant volume for placement in a fracture to be created in the subterranean formation;
determining a fracture geometry for the fracture, based upon the initial proppant volume;
determining a pad volume sufficient to create the desired fracture geometry at a first fluid efficiency value;
determining a fracture length and width that would result from injecting the pad volume into the subterranean formation at
a second fluid efficiency value; and

calculating a proppant volume sufficient to fill a fracture having the length and width; wherein the first fluid efficiency
value is lower than the second fluid efficiency value; and,

creating a propped fracture within a subterranean formation using a fluid comprising the calculated pad volume and a proppant
volume equal to or less than the calculated proppant volume.

US Pat. No. 9,175,529

METHODS AND COMPOSITIONS FOR TREATING SUBTERRANEAN FORMATIONS WITH INTERLOCKING LOST CIRCULATION MATERIALS

Halliburton Energy Servic...

1. A method of treating a fluid loss zone in a wellbore in a subterranean formation comprising:
providing interlocking notched particulates having an outer face comprising at least one notch therethrough;
wherein the at least one notch has a shape and an inner perimeter value, and
wherein the at least one notch is partially-drilled through the outer face of the interlocking notched particulates or is
completely-drilled through the outer face of the interlocking notched particulates;

providing interlocking protruding particulates having an outer perimeter portion that protrudes in an approximate equivalent
to the shape and value of the inner perimeter of the at least one notch;

introducing the interlocking protruding particulates and the interlocking notched particulates into the wellbore in the subterranean
formation;

interlocking the interlocking protruding particulates and the interlocking notched particulates through the at least one notch
to form an interlocking network of at least one interlocking protruding particulate and at least one interlocking notched
particulate;

sealing at least a portion of the fluid loss zone.

US Pat. No. 9,127,532

OPTICAL CASING COLLAR LOCATOR SYSTEMS AND METHODS

Halliburton Energy Servic...

1. A casing collar locator system that comprises:
a sonde configured to be conveyed through a casing string, wherein the sonde comprises:
at least one permanent magnet producing a magnetic field that changes in response to passing a collar in the casing string;
a coil that receives at least a portion of the magnetic field and provides an electrical signal in response to said changes
in the magnetic field; and

a voltage source, a switch, and a light source in series with the coil,
when the switch is closed, the light source responds to said electrical signal to communicate light along an optical fiber
to indicate passing collars,

wherein said switch is opened and closed at a duty cycle that conserves energy stored in the voltage source.

US Pat. No. 9,091,152

PERFORATING GUN WITH INTERNAL SHOCK MITIGATION

Halliburton Energy Servic...

1. A perforating gun, comprising:
at least one explosive component; and
a shock mitigation device including a shock reflector which indirectly reflects a shock wave in a fluid within the perforating
gun, the shock wave produced by detonation of the explosive component, wherein the shock reflector comprises multiple tiered
shock reflecting surfaces having different diameters, wherein the shock reflecting surfaces are generally conical-shaped,
wherein the shock reflecting surfaces are convex relative to the explosive component, and wherein at least two of the shock
reflecting surfaces have different incidence angles, whereby the shock wave is reflected as respective multiple reflected
shock waves in different directions, thereby breaking up the shock wave and reducing an energy transfer from the fluid to
an internal surface of the perforating gun.

US Pat. No. 9,085,940

OFFSHORE UNIVERSAL RISER SYSTEM

Halliburton Energy Servic...

1. A method of constructing a riser system, the method comprising the steps of:
installing a valve module in a flow passage extending longitudinally through a riser string, the valve module configured to
selectively permit and prevent fluid flow through the flow passage;

installing at least one annular seal module in the flow passage, the annular seal module configured to prevent fluid flow
through an annular space between the riser string and a tubular string positioned in the flow passage; and

retrieving the valve module and annular seal module simultaneously from the riser system.
US Pat. No. 9,051,506

HYDRATION ACCELERATION SURFACTANTS IN CONJUNCTION WITH HIGH MOLECULAR WEIGHT POLYMERS, AND METHODS AND COMPOSITIONS RELATING THERETO

Halliburton Energy Servic...

1. A method comprising:
mixing an aqueous base fluid, a nonionic hydration acceleration surfactant having a hydrophilic-lipophilic balance of about
10 or greater, a crosslinker polymer, and a base polymer, thereby yielding a treatment fluid,

wherein the base polymer is provided in the form of a first polymeric emulsion before mixing and/or the crosslinker polymer
is provided in the form of a second polymeric emulsion before mixing;

introducing the treatment fluid into a wellbore penetrating a subterranean formation;
allowing the crosslinker polymer to react with the base polymer, thereby forming a gel; and
allowing the gel to perform at least one function within the wellbore and/or the subterranean formation selected from the
group consisting of bridge a fracture, provide fluid loss control, seal a rock surface, enable fluid diversion, plug a void,
reduce formation permeability, control water production, and any combination thereof.

US Pat. No. 9,453,395

AUTONOMOUS FLUID CONTROL ASSEMBLY HAVING A MOVABLE, DENSITY-DRIVEN DIVERTER FOR DIRECTING FLUID FLOW IN A FLUID CONTROL SYSTEM

HALLIBURTON ENERGY SERVIC...

1. An apparatus for autonomously controlling fluid flow in a subterranean well, the fluid having a density which changes over
time, the apparatus comprising:
a vortex assembly having a vortex chamber, a vortex outlet, and a first flow inlet and a second flow inlet into the vortex
chamber;

a fluid control system having a first fluid passageway and a second passageway, fluid exiting the first and second passageway
directed into the vortex assembly; and

a movable fluid diverter positioned in the second passageway, the fluid diverter moved by change in the fluid density, the
fluid diverter movable to restrict fluid flow through the second passageway in response to change in the fluid density,

wherein the movable fluid diverter comprises a floating element unattached to the walls of the passageways.

US Pat. No. 9,441,437

ELECTRONIC RUPTURE DISCS FOR INTERVENTIONLESS BARRIER PLUG

Halliburton Energy Servic...

1. A method for removing a plug positioned to block fluid flow through a passageway in a downhole tubular positioned in a
subterranean wellbore, the plug isolated from fluid in the passageway by at least one cover, the method comprising the steps
of:
actuating an electronic rupture disc assembly to open a fluid bypass to the plug, the rupture disk assembly having a rupture
disc initially positioned to block fluid flow along the fluid bypass between the plug and the rupture disc;

allowing a degrading fluid to flow from a fluid chamber and through the fluid bypass, thereby contacting the plug, wherein
the fluid chamber extends across the passageway; and

substantially degrading the plug using the degrading fluid.

US Pat. No. 9,388,660

CUT-TO-RELEASE PACKER WITH LOAD TRANSFER DEVICE TO EXPAND PERFORMANCE ENVELOPE

Halliburton Energy Servic...

8. A method of constructing a releasable packer, the method comprising: assembling a mandrel, at least one slip, a slip support,
and a load transfer device, the mandrel having a longitudinal section, and the packer being releasable from a set configuration
in response to the longitudinal section being severed; and wherein the assembling comprises preventing relative longitudinal
displacement between the load transfer device and the mandrel on a first longitudinal side of the longitudinal section while
preventing relative longitudinal displacement between the load transfer device and the slip support on a second opposite longitudinal
side of the longitudinal section, wherein the assembling further comprises engaging an engagement member of the load transfer
device with the slip support, and supporting the engagement member with the mandrel.

US Pat. No. 9,383,029

MULTIPLE PISTON PRESSURE INTENSIFIER FOR A SAFETY VALVE

Halliburton Energy Servic...

1. A method of actuating a safety valve, comprising:
conveying hydraulic fluid pressure to a piston bore defined in a sidewall of a housing and providing an upper bore having
a first diameter and a lower bore having a second diameter smaller than the first diameter, wherein a piston assembly is movably
arranged within the piston bore and comprises an upper piston sealingly engaging the upper bore and a lower piston sealingly
engaging the lower bore;

axially displacing the piston assembly within the piston bore as the hydraulic fluid pressure acts on the upper piston, wherein
a connecting rod couples the upper and lower pistons such that simultaneous movement of each piston is achieved when the piston
assembly moves within the piston bore, and wherein a cavity is defined between the upper and lower pistons within the piston
bore and the connecting rod extends within the cavity;

maintaining pressure equilibrium within the cavity and an annulus region with a conduit defined in the housing; and
moving a valve closure device as the piston assembly moves within the piston bore, the valve closure device being arranged
within a central flow passage defined in the housing and operably coupled to the piston assembly.

US Pat. No. 9,366,691

MULTIPLEXED FIBER OPTIC SENSING SYSTEM AND METHOD

Halliburton Energy Servic...

1. A distributed system for measuring physical parameters, comprising:
a source of high-power broadband pulsed light having a generally flat output wavelength spectrum;
at least one input optical fiber coupled to the source of broadband light;
a plurality of sensors coupled to the input optical fiber at spaced locations along the fiber, at least some of the sensors
each including a plurality of Fabry-Perot cavities for measuring a plurality of respective physical parameters at the location
of the sensor, the plurality of Fabry-Perot cavities producing, within a plurality of respective data channels occupying a
plurality of respective wavelength bands, output optical signals comprising respective narrow transmission bands whose peak
wavelengths shift in response to the respective physical parameters;

at least one output optical fiber coupled to the plurality of sensors and configured to receive and communicate the sensor
output optical signals; and

an interrogation module coupled to the at least one output optical fiber, the interrogation module being configured to separate
the output optical signals from different ones of the sensors by time division demultiplexing and to separate the output optical
signals from different ones of the Fabry-Perot cavities within each sensor by coarse wavelength demultiplexing and further
configured to convert the output optical signals to electrical output signals.

US Pat. No. 9,254,453

ECONOMICAL METHOD FOR SCAVENGING HYDROGEN SULFIDE IN FLUIDS

Halliburton Energy Servic...

1. A method of removing hydrogen sulfide from a fluid containing hydrogen sulfide, the method comprising:
adding a gluconate additive other than ferrous gluconate to the fluid, and adding a source of iron to the fluid where the
fluid does not comprise iron or iron ions or where more iron is needed in sufficient quantity to react with the gluconate
to form iron gluconate in the fluid;

mixing the fluid such that the gluconate additive contacts the iron and forms iron gluconate in the fluid, wherein the fluid
has a pH no lower than about 11 during the mixing; and

allowing the iron gluconate in the fluid to react with the hydrogen sulfide in the fluid, forming iron sulfide, water and
gluconic acid, such gluconic acid then being available to react with iron in the fluid to form iron gluconate.

US Pat. No. 9,249,638

WELLBORE PRESSURE CONTROL WITH OPTIMIZED PRESSURE DRILLING

Halliburton Energy Servic...

7. A method of maintaining a desired pressure in a wellbore, the method comprising:
providing an accumulator connected to a fluid return line between a blowout preventer stack and a choke manifold; and
applying pressure to the wellbore from the accumulator in response to pressure in the wellbore being less than the desired
pressure.

US Pat. No. 9,217,294

EROSION RESISTANT HARD COMPOSITE MATERIALS

Halliburton Energy Servic...

1. A hard composite composition comprising:
a binder; and
a polymodal blend of matrix powder; wherein the polymodal blend of matrix powder has first local maxima at a particle size
of 30 ?m or less, a second local maxima at a particle size of 200 ?m or more, and a local minima between a particle size of
about 30 ?m to about 200 ?m that has a volume percent that is less than the first local maxima; and wherein the polymodal
blend of matrix powder has one selected from the group consisting of: a third local maxima at a particle size of 30 ?m or
less, a fourth local maxima at a particle size of 200 ?m or more, and both the third and fourth local maxima.

US Pat. No. 9,157,298

FLUID FLOW CONTROL

HALLIBURTON ENERGY SERVIC...

1. A flow control device configured for being disposed between a subterranean formation and a tubular in a wellbore, the flow
control device comprising:
a chamber having (i) an exit opening and (ii) a flow path; and
a flow influencer device in the chamber, the flow influencer device being configured to affect fluid flowing into a turbulence
having a structure that is based on at least one property of the fluid and the flow influencer device, wherein the chamber
is configured for restricting fluid flow in the flow path by different amounts based on the structure of the turbulence, wherein
the chamber comprises:

an inlet at a first end of the chamber; and
a second exit opening located between the exit opening and a second end of the chamber,
wherein the flow influencer device is a diverter positioned between the inlet and the exit opening and configured to influence
flow of fluid based on the at least one property (i) toward the exit opening and (ii) toward the second exit opening, by causing
the fluid to flow into the turbulence that is a vortex and creating an area of low pressure between the diverter and the second
end of the chamber.

US Pat. No. 9,091,347

SAFETY CAP

Halliburton Energy Servic...

1. A cap for a cell, comprising:
a base;
a top engaging the base and moveable relative to the base;
a connector arranged between the base and the top and moveable relative to one of the base and the top;
one or more wings movably disposed between the base and the top, each wing having a first portion engaging the connector and
a second portion engageable with the cell, wherein the one or more wings comprise a fulcrum between the first portion and
the second portion; and

a lock lying in a first position when pressure within the cell exceeds pressure outside the cell to prevent relative movement
between the base and the top, and lying in a second position when pressure within the cell does not exceed pressure outside
the cell to allow relative movement between the base and the top,

wherein relative movement between the base and the top causes the connector to move the first portion of each wing, thereby
causing the second portion of each wing to move, and wherein relative movement between the base and the top causes the first
portion of the one or more wings to rotate about the fulcrum in a first direction, which, in turn, causes the second portion
of the wing to also rotate about the fulcrum.

US Pat. No. 9,388,672

WELLBORE SCREENS AND METHODS OF USE THEREOF

Halliburton Energy Servic...

1. A sand control screen assembly, comprising:
a base pipe having an exterior surface and defining one or more perforations;
a screen jacket disposed about the exterior surface of the base pipe and having a primary screen arranged axially adjacent
a secondary screen;

a screen isolator directly coupled to and supporting the primary and secondary screens; and
at least one relief valve that prevents a fluid flow from passing through both the secondary screen and the base pipe until
experiencing a predetermined differential pressure generated when the primary screen becomes plugged,

wherein the predetermined differential pressure opens the at least one relief valve to divert the fluid flow from the primary
screen to the secondary screen.

US Pat. No. 9,284,829

SIMULATING SUBTERRANEAN FRACTURE PROPAGATION

Halliburton Energy Servic...

1. A system for performing an injection treatment, the system comprising:
an injection treatment control subsystem adapted to control an injection treatment applied to a subterranean formation through
a well bore defined in the subterranean formation,

the injection treatment based on a simulation that predicts, for each of a plurality of rock blocks of the subterranean formation,
a response of the rock block to one or more forces acting on the rock block during the injection treatment, wherein the simulation
comprises:

receiving a subterranean formation model comprising:
a mesh that represents the plurality of rock blocks of the subterranean formation; and
a contact model that models interactions among the plurality of rock blocks; and
using the mesh and the contact model of the subterranean formation model to predict the response for each of the plurality
of the rock blocks to the one or more forces, the one or more forces comprising:

normal contact forces and shear contact forces arising from physical contact between rock blocks; and
fluid forces arising from fluid pressure acting on the rock blocks during fluid injection.

US Pat. No. 9,051,830

TWO LINE OPERATION OF TWO HYDRAULICALLY CONTROLLED DOWNHOLE DEVICES

Halliburton Energy Servic...

5. A hydraulic control module for use in a downhole hydraulic control system having first and second hydraulic control lines
for operating first and second hydraulically controlled devices having first and second actuators, respectively, the hydraulic
control module comprising:
a housing having a plurality of first ports in fluid communication with the first hydraulic control line, a plurality of second
ports in fluid communication with the second hydraulic control line, a third port and a fourth port;

a release assembly disposed within the housing; and
a piston slidably disposed within the housing, the piston having a first position relative to the housing in which at least
one of the first ports is in fluid communication with the third port, the piston having a second position relative to the
housing in which at least one of the first ports is in fluid communication with the fourth port and at least one of the second
ports is in fluid communication with the third port, the piston selectively retained in the first position by the release
assembly;

wherein, the release assembly is unlocked responsive to a high pressure signal in the second hydraulic control line; and
wherein, while the release assembly is unlocked, the piston is shifted from the first position to the second position responsive
to a high pressure signal in the first hydraulic control line.

US Pat. No. 9,447,662

ABANDONMENT AND CONTAINMENT SYSTEM FOR GAS WELLS

HALLIBURTON ENERGY SERVIC...

1. A method for plugging and abandoning a subterranean wellbore having a casing positioned therein, the method comprising
the steps of:
running a tool string into the wellbore, the tool string having a swellable annular sealing device, an expandable liner hanger
with at least one annular sealing element mounted thereon, and a valve in an open position to allow fluid communication between
the interior of the tool string and a wellbore annulus defined between the swellable annular sealing device and the casing;
radially expanding the swellable annular sealing device;
creating a fluid-tight annular seal between the swellable annular sealing device and the casing;
radially expanding the expandable liner hanger and contacting the casing with the at least one annular sealing element;
creating a fluid-tight annular seal between the expandable liner hanger and the casing, wherein the step of radially expanding
the swellable annular sealing device further comprises the step of exposing a swellable material positioned on the device
to an actuating fluid, an actuating chemical, or to heat; and

closing the valve after creating a fluid-tight annular seal between the expandable liner hanger and the casing to block fluid
communication between the interior of the tool string and the wellbore annulus.

US Pat. No. 9,430,590

OPTICAL DESIGN TECHNIQUES FOR ENVIRONMENTALLY RESILIENT OPTICAL COMPUTING DEVICES

Halliburton Energy Servic...

1. A method for designing an integrated computational element (ICE), comprising:
generating a plurality of ICE designs with a design suite stored on a non-transitory, computer-readable medium, each ICE design
having at least one of a random number of layers and a random thickness for each layer;

optimizing the plurality of ICE designs based on performance criteria and thereby generating a plurality of theoretical ICE
designs configured to detect a characteristic of interest;

sorting the theoretical ICE designs based on the performance criteria in view of a known value for the characteristic of interest
and thereby identifying one or more predictive ICE designs;

approximating a spectral shift on each predictive ICE design resulting from an expected temperature shift, wherein approximating
the spectral shift includes calculating a theoretical effect of the expected temperature shift on each individual layer of
each predictive ICE design;

altering a design of the one or more predictive ICE designs based on the calculated theoretical effect of the expected temperature
shift; and

selecting for fabrication one or more predictive ICE designs based on favorable temperature stability in view of the calculated
theoretical effect of the expected temperature shift.

US Pat. No. 9,398,640

DIGITAL MULTI-USE THERMO-CUP

HALLIBURTON ENERGY SERVIC...

1. A multi-use thermal cup device for taking engineering measurements, the multi-use thermal cup device comprising:
a cup having an inner wall with an open mouth and a closed bottom defining a space for containing a sample therein, wherein
the cup further includes a thermally insulated or insulating outer wall;

a disposable thin walled cup insert positionable within the inner wall of the cup, wherein oil or other media is provided
between the cup and the disposable thin walled cup insert to assure efficient heat transfer;

a heating element disposed between the inner and outer walls of the cup;
an electronic controller detachably and operably connected to the cup via an electromechanical connection, wherein the electromechanical
connection comprises mating of a portion of an electromechanical connector on the electronic controller to another portion
of the electromechanical connector on the thermally insulated or insulating outer wall of the cup, and wherein the electromechanical
connection is sized to create an air gap between the electronic controller and the thermally insulated or insulating outer
wall of the cup; and

a temperature probe detachably coupled to the electronic controller to provide a measure of the cup temperature,
wherein the electronic controller operates to control a supply of power to the heating element in accordance with said measure
and at least one user-entered parameter to within two degrees of a digital set point, wherein said electronic controller comprises
a digital signal processor that acquires digital samples of said measure.

US Pat. No. 9,376,892

MAGNETIC VALVE ASSEMBLY

Halliburton Energy Servic...

1. An actuation system for a downhole component comprising:
a wellbore tubular comprising a central flowbore and a magnetic valve seat, wherein the magnetic valve seat is disposed about
the wellbore tubular;

a disposable member comprising at least one magnet, wherein the disposable member is configured to be received within the
central flowbore; and

a ball,
wherein the at least one magnet is configured to axially shift the magnetic valve seat from a first position to a second position
when the disposable member passes within the central flowbore,

wherein the ball is configured to sealingly engage the magnetic valve seat,
wherein the magnetic valve seat is configured to retain and engage the ball when the magnetic valve seat is in the first position,
and

wherein the magnetic valve seat is configured to release the ball into the central flowbore when the magnetic valve seat is
in the second position.

US Pat. No. 9,353,616

IN-LINE SAND SCREEN GAUGE CARRIER AND SENSING METHOD

Halliburton Energy Servic...

16. A method of sensing in a wellbore, the method comprising:
retaining at least one gauge along a wellbore tubular string using a gauge carrier, wherein the gauge carrier comprises a
housing disposed about a mandrel, wherein an annular flowpath is formed between the housing and the mandrel, wherein the at
least one gauge is disposed about an outside of the housing;

communicating fluid through the annular flowpath; and
sensing at least one parameter using the at least one gauge, wherein the at least one parameter is provided through a sensing
link from a point axially separate from the gauge carrier.

US Pat. No. 9,297,767

DOWNHOLE SPECIES SELECTIVE OPTICAL FIBER SENSOR SYSTEMS AND METHODS

Halliburton Energy Servic...

14. A method for operating a well, comprising:
deploying one or more downhole optical sensors in a fluid flow path along an exterior of a casing string or production tubing
in the well, each of the one or more downhole optical sensors having a waveguide for conducting light and a reagent region
between the waveguide and a fluid of the fluid flow path, wherein the reagent region comprises a reagent for complexing with
a chemical species in the fluid, causing a change in an absorption spectrum of the reagent in dependence upon a concentration
of the chemical species in the fluid;

probing the one or more downhole optical sensors from a surface interface to detect concentrations of one or more chemical
species; and

deriving a rate or quantity of scale buildup or corrosion on one or more metal surfaces within the well based at least in
part on the detected concentrations.

US Pat. No. 9,212,538

MODELING FLUID FLOW INTERACTIONS AMONG REGIONS OF A WELL SYSTEM

Halliburton Energy Servic...

1. A fluid flow simulation method for simulating well system fluid flow in a subterranean region, the method comprising:
identifying subsystem models associated with distinct subsystems within a subterranean region, each subsystem model including
fluid flow variables and representing well system fluid flow dynamics associated with a sub-region in the subterranean region,
the subsystem models being connected by junction models that represent interactions among the subsystem models;

for each of the subsystem models, performing, by operation of one or more computers, an elimination of internal variables
of the subsystem model to express the internal variables in terms of junction variables of the junction models;

solving, using the one or more computers, the junction variables based on the junction models; and
solving, using the one or more computers, the internal variables of the subsystem model based on the solved junction variables.

US Pat. No. 9,151,864

MONITORING AND DETECTION OF MATERIALS USING HYPERSPECTRAL IMAGING

Halliburton Energy Servic...

1. A method for analyzing gaseous emissions from a subterranean formation comprising:
positioning a hyperspectral image capturing mechanism to monitor an area of interest,
wherein the hyperspectral image capturing mechanism comprises two cameras,
wherein central axis of the two cameras are substantially orthogonal and wherein the two cameras capture images of at least
one unique common volume;

detecting presence of one or more materials of interest in the area of interest using the hyperspectral image;
quantifying amount of the one or more materials of interest in the area of interest;
estimating amount of the one or more materials of interest in the at least one unique common volume; and
determining the density of the one or more materials of interest using the amount of the one or more materials of interest
in the at least one unique common volume and the volume of the at least one unique common volume.

US Pat. No. 9,133,385

METHOD FOR IMPROVING HIGH TEMPERATURE RHEOLOGY IN DRILLING FLUIDS

Halliburton Energy Servic...

1. A method for drilling in a subterranean formation comprising providing or using in the drilling a clay free invert emulsion
drilling fluid having an oleaginous continuous phase, a non-oleaginous discontinuous phase, and a rheology additive comprising
a silicon oil, wherein the drilling fluid with the rheology additive, when compared to the drilling fluid without the rheology
additive, restricts the increase in plastic viscosity to 50% or less and has at least one of an increased yield point and
an increased low shear yield point.

US Pat. No. 9,441,451

SELF-SETTING DOWNHOLE TOOL

HALLIBURTON ENERGY SERVIC...

15. A method of anchoring a downhole tool in a wellbore comprising:
(a) introducing said downhole tool having an expandable member into said wellbore to locate said downhole tool at a desired
position; and

(b) providing fluid pressure to said expandable member to axially expand said expandable member such that said downhole tool
is moved from an unset position in which said downhole tool is not anchored to a set position in which said downhole tool
is anchored in said wellbore, wherein said providing fluid pressure to said expandable member comprises providing an electrical
pulse to a chemical associated with said expandable member such that said electrical pulse causes said chemical to undergo
a gas producing chemical reaction sufficient for said gas to inflate said expandable member and cause axial expansion.

US Pat. No. 9,371,577

FABRICATION OF INTEGRATED COMPUTATIONAL ELEMENTS USING SUBSTRATE SUPPORT SHAPED TO MATCH SPATIAL PROFILE OF DEPOSITION PLUME

Halliburton Energy Servic...

1. A system comprising:
a computational system to receive a design of an integrated computational element (ICE), the ICE design comprising specification
of a substrate and a plurality of layers, their respective target thicknesses and complex refractive indices; and

a deposition chamber comprising
a deposition source to provide a deposition plume having a plume spatial profile, and
a support to support a plurality of instances of the substrate during fabrication of a plurality of instances of an ICE in
accordance with the ICE design, wherein the support

is spaced apart from the deposition source along an azimuthal axis of the plume spatial profile by a source distance, a center
axis of the support being parallel to the azimuthal axis of the plume spatial profile and displaced relative to the azimuthal
axis of the plume spatial profile in a radial direction of the support by half a radius of the support, and

has a shape that corresponds, at the source distance, to the plume spatial profile along the radial direction of the support,
such that, when the support, with the plurality of supported instances of the substrate distributed over the support, is rotated
around the center axis of the support, thicknesses of instances of each of the deposited layers are substantially uniform
across the plurality of instances of the ICE.

US Pat. No. 9,365,763

LOW-VISCOSITY TREATMENT FLUIDS FOR TRANSPORTING PROPPANT

Halliburton Energy Servic...

1. A method comprising:
forming swellable micro-gel fragments comprising a reaction product comprising acrylamide, polyethylene glycol diacrylate,
ammonium persulfate, and tetramethyl ethylene diamine,

wherein the swellable micro-gel fragments are crosslinked by ester based bonds;
forming a fracturing fluid comprising an aqueous base fluid, proppant, and the swellable micro-gel fragments,
wherein the fracturing fluid has a low-viscosity in the range of about 0 to about 800 centipoise, and
wherein when the swellable micro-gel fragments are in a dry state, they are present in an amount of about 0.01% to about 50%
by weight of the fracturing fluid, and wherein when the swellable micro-gel fragments are in a wet state, they are present
in the fracturing fluid in an amount of about 1% to about 35% by weight of the fracturing fluid;

swelling the swellable micro-gel fragments, thereby forming a matrix by suspending the proppant between surfaces of the swelled
micro-gel fragments in the fracturing fluid,

wherein the fracturing fluid comprising the matrix retains the low-viscosity in the range of about 0 to about 800 centipoise;
placing the fracturing fluid in a fracture within the subterranean formation; and
at least partially degrading the matrix in the subterranean formation by degrading the ester based bonds of the swellable
micro-gel fragments.

US Pat. No. 9,366,121

MODELING FRACTURING FLUID LEAK-OFF

Halliburton Energy Servic...

1. A computer-implemented method for modeling fracturing fluid leak-off in a subterranean formation, the method comprising:
modeling, with a reservoir block flow model, fluid flow in multiple fluid phases and in multiple spatial dimensions within
reservoir media in a subterranean formation;

modeling, with a fracture network flow model, fluid flow within a fracture network in the subterranean formation;
modeling, with an interface flow model, fluid flow between the fracture network and the reservoir media, wherein the interface
flow model comprises a filtration with linear-invasion and crossflow (FLIC) model with a time-dependent pressure drop across
a filter-cake on a fracture face;

wherein the reservoir block flow model includes a mesh representation of the reservoir media, the mesh representation including
a plurality of mesh elements, the mesh representation bounded by a boundary, the boundary representing fractures of the fracture
network;

wherein the mesh representation comprises coarser resolution mesh elements in the middle region and finer resolution mesh
elements near the boundary;

wherein the fracture network flow model includes a first system of differential equations, the reservoir block flow model
includes a second system of differential equations, and the interface flow model includes a third set of equations that couples
the first system of differential equations with the second system of differential equations; and

generating output data representing characteristics of fracturing fluid leak-off from the fracture network into the reservoir
media, the output data generated based on coupling the fracture network flow model, the reservoir block flow model, and the
interface flow model, wherein generating the output data includes making time-dependent modifications to the mesh representation
that includes the plurality of mesh elements.

US Pat. No. 9,260,945

EXPANDABLE AND VARIABLE-LENGTH BULLNOSE ASSEMBLY FOR USE WITH A WELLBORE DEFLECTOR ASSEMBLY

Halliburton Energy Servic...

1. A wellbore system, comprising:
an upper deflector arranged within a main bore of a wellbore and defining first and second channels;
a lower deflector arranged within the main bore and spaced from the upper deflector by a predetermined distance, the lower
deflector defining a first conduit that exhibits a predetermined diameter and communicates with a lower portion of the main
bore and a second conduit that communicates with a lateral bore; and

a bullnose assembly including a body and a bullnose tip arranged at a distal end of the body, the bullnose assembly being
actuatable between a default configuration and an actuated configuration to vary a length and a diameter of the bullnose tip,

wherein the upper and lower deflectors direct the bullnose assembly into one of the lateral bore and the lower portion of
the main bore based on the length and the diameter of the bullnose tip as compared to the predetermined distance and the predetermined
diameter, respectively.

US Pat. No. 9,200,500

USE OF SENSORS COATED WITH ELASTOMER FOR SUBTERRANEAN OPERATIONS

Halliburton Energy Servic...

11. A wellbore servicing composition comprising:
a base fluid; and
a plurality of elastomer-coated sensors, wherein each of the plurality of elastomer-coated sensors is configured to detect
one or more parameters, the one or more parameters including a change in the elastomer.

US Pat. No. 9,176,246

IDENTIFYING DOMINANT FRACTURE ORIENTATIONS

Halliburton Energy Servic...

1. A computer-implemented method for identifying dominant fracture orientations in a subterranean zone, the method comprising:
receiving microseismic event data associated with a fracture treatment of a subterranean zone;
identifying coplanar subsets of microseismic events in the received microseismic event data, each of the coplanar subsets
comprising a non-collinear triplet of microseismic events in the received microseismic event data;

determining a basic plane orientation for each of a plurality of basic planes defined by the coplanar subsets, each basic
plane orientation being defined by the non-collinear triplet of microseismic events in a respective one of the coplanar subsets;

calculating, by data processing apparatus, the quantity of the basic plane orientations in each of a plurality of orientation
ranges;

identifying a dominant fracture orientation for the subterranean zone based on one or more of the quantities;
identifying a cluster of microseismic events associated with the identified dominant fracture orientation;
generating a fracture plane based on the identified dominant fracture orientation and the identified cluster of microseismic
events associated with the identified dominant fracture orientation; and

displaying a histogram of the basic plane orientations, wherein the histogram indicates the quantity of basic plane orientations
in each of the orientation ranges.

US Pat. No. 9,145,760

DOWNHOLE SUPERCAPACITOR DEVICE

Halliburton Energy Servic...

1. A supercapacitor device configured to be disposed in a wellbore through a fluid-producing formation, the supercapacitor
device comprising:
a body configured to be disposed in the wellbore;
a supercapacitor disposed in the body and configured to store energy;
at least two terminals disposed at least partially outside the body, the at least two terminals configured to be electrically
connected with the supercapacitor, wherein an electrical connection between the supercapacitor and the at least two terminals
is adapted to cause the energy to be discharged from the supercapacitor in response to a conductive material providing an
electrical path between the at least two terminals; and

an actuation mechanism configured to selectively prevent discharge of the energy from the supercapacitor when the supercapacitor
device is deployed into the wellbore, wherein the actuation mechanism comprises at least one retention pin, wherein the at
least one retention pin is adapted to retain at least one terminal in a position that is electrically disconnected from the
supercapacitor and is further adapted to be sheared in response to a force applied to the at least one terminal in the direction
of the body.