US Pat. No. 9,458,715

DETERMINING THE PLUS FRACTION OF A GAS CHROMATOGRAM

SCHLUMBERGER TECHNOLOGY C...

1. A method for analyzing a fluid having a plurality of components, comprising:
obtaining a gas chromatogram of the fluid, the gas chromatogram comprising a plus fraction;
determining, from the gas chromatogram, a first ratio of a first at least one component of the fluid to a second at least
one component of the fluid;

comparing the first ratio to a dataset of a plurality of fluids having a respective plurality of component ratios;
determining the plus fraction using the comparison; and
quantifying at least one of the components in the fluid using the determined plus fraction.

US Pat. No. 9,395,463

EM PROCESSING USING FIELD RATIOS

SCHLUMBERGER TECHNOLOGY C...

1. A method, comprising:
operating an electronic device to model expected electromagnetic (EM) field components to be measured by an EM apparatus associated
with a subterranean formation, wherein the EM apparatus comprises at least one EM source and at least one EM receiver;

operating the electronic device to determine one or more ratios of the modeled EM field components;
operating the at least one EM source to emit an EM signal into the subterranean formation, and operating the at least one
EM receiver to measure actual EM field components of the EM signal;

operating the electronic device to compare the one or more ratios of the modeled EM field components with one or more ratios
of the actual EM field components; and

updating the one or more ratios of the modeled EM field components based on the comparison.

US Pat. No. 9,062,520

RETRIEVABLE CEMENTING BUSHING SYSTEM

Schlumberger Technology C...

7. A method, comprising:
preparing a retrievable cementing bushing with a body;
movably mounting an engagement lug on the body such that an outer engagement feature is oriented radially outward and an inner
engagement feature is oriented radially inward;

spring biasing the engagement lug in a radially outward direction with respect to the body;
positioning a slick joint within the retrievable cementing bushing and orienting a slick joint engagement feature of the slick
joint to abut the inner engagement feature of the engagement lug along a surface substantially perpendicular to an axis of
the slick joint; and

moving the retrievable cementing bushing into a packer until the outer engagement feature is received in a corresponding internal
engagement feature of the packer.

US Pat. No. 9,284,811

UNIVERSAL ROTATING FLOW HEAD HAVING A MODULAR LUBRICATED BEARING PACK

Schlumberger Technology C...

1. A modular lubricated bearing pack for a rotating control device comprising:
a bearing pack housing and a rotatable cylindrical sleeve adapted for passage of a tubular, forming an annular assembly space
therebetween;

bearing elements positioned in the annular assembly space for radially and axially supporting the rotatable cylindrical sleeve
within the bearing pack housing;

one or more seal assemblies, each of the one or more seal assemblies having at least one sealing element, each of the at least
one sealing element further comprising,

an elastomeric body operable between a first non-activated state and a second activated state, the elastomeric body having
an annular cavity, an inner sealing surface adapted to engage the rotatable cylindrical sleeve, and a radially outwardly extending
flange supported in the bearing pack housing; and

a loading ring, fit within the annular cavity, for urging the inner sealing surface to expand radially inwardly to engage
the rotatable cylindrical sleeve for sealing thereto,

wherein when the elastomeric body is in the first non-activated state, the radially outwardly extending flange has a first
radial extent being less than a radial extent of a space in which the elastomeric body is disposed, the first radial extent
and the radial extent being measured from the rotatable cylindrical sleeve; and

wherein when the elastomeric body is in the second activated state, the radially outwardly extending flange is axially compressed,
distending radially towards the bearing pack housing and has a second radial extent greater than the first radial extent,
the second radial extent being measured from the rotatable cylindrical sleeve; and

an elastomeric stripper element for sealing the tubular against the wellbore fluids from passing thereby.

US Pat. No. 9,097,819

THERMOELASTIC LOGGING

Schlumberger Technology C...

1. A method for thermoelastic logging in a borehole of a subterranean formation, comprising:
generating, by a computer processor, a reference dispersion based on a borehole wave dispersion measurement of the borehole,
wherein the reference dispersion represents far-field elastic properties in the subterranean formation;

analyzing, by the computer processor, a difference between the reference dispersion and the borehole wave dispersion measurement
based on a thermoelastic model of the subterranean formation to generate an analysis result; and

determining, by the computer processor and based on the analysis result, a temperature dependent parameter of the subterranean
formation.

US Pat. No. 9,426,243

REMOTE CONTEXTUAL COLLABORATION

Schlumberger Technology C...

1. A method for remote collaboration, the method comprising:
receiving, over a computer network, posting content from a drill device in an oilfield managed by a company, wherein the posting
content comprises a plurality of key terms and a message specifying a drill bit failure;

generating a posting using the posting content;
extracting the plurality of key terms from the posting content;
matching one of the plurality of key terms to a key term label;
storing the key term label in the posting;
selecting a company channel corresponding to the key term label by:
receiving, from a subscriber, a set of subscription terms,
matching the set of subscription terms to the key term label,
determining a number of postings comprising the key term label exceeds a threshold,
generating, in response to determining the number of postings exceeds the threshold, the company channel based on the subscription
terms, and

subscribing the subscriber to the company channel; and
sending, in response to the subscriber being subscribed to the company channel, the posting content over the computer network
to a field operator computing device operated by the subscriber,

wherein the subscriber is a field operator of the company, and
wherein the field operator slows a drill bit in response to the posting content to avoid failure of the drill bit.

US Pat. No. 9,121,223

DRILLING SYSTEM WITH FLOW CONTROL VALVE

Schlumberger Technology C...

10. A method for drilling, comprising:
coupling a drill bit to a rotary steerable system having a plurality of actuators;
delivering actuating fluid to the rotary steerable system to enable actuation of the plurality of actuators;
positioning a valve system, having a rotor, a blind, and a stator, in the flow path of the actuating fluid moving toward the
plurality of actuators;

controlling delivery of the actuating fluid to specific actuators at specific rotational positions via relative rotation of
the rotor and the stator; and

causing relative rotation of the rotor and the blind via an electric motor to selectively allow or block flow of actuating
fluid to the stator; and

operating the electric motor independently of the flow of actuating fluid.

US Pat. No. 9,389,333

RADIATION GENERATOR AND POWER SUPPLY CONFIGURATION FOR WELL LOGGING INSTRUMENTS

SCHLUMBERGER TECHNOLOGY C...

1. A well logging instrument, comprising:
a housing;
at least one of an ionizing and nuclear radiation generator disposed in the housing;
a high voltage power supply disposed in the housing and functionally coupled to the radiation generator, the generator and
the power supply longitudinally separated by a distance sufficient for emplacement of a radiation detector between the radiation
generator and the power supply and configured to supply power to the radiation generator to enable the radiation generator
to emit radiation in short pulses and to enable the radiation generator to emit radiation in pulses of substantially continuous
character;

at least a first radiation detector disposed in the housing and between the generator and the supply; and
an electrical connection disposed in the housing and between the supply and the generator, wherein the electrical connection
comprises a conductive material surrounded by an electrically insulating gas or an electrically insulating liquid.

US Pat. No. 9,412,492

TORQUE-BALANCED, GAS-SEALED WIRELINE CABLES

SCHLUMBERGER TECHNOLOGY C...

1. A cable, comprising:
an electrically conductive cable core for transmitting electrical power; a hard polymer layer surrounding said cable core,
and a first layer of polymer surrounding said hard polymer layer, wherein the cable core has a core diameter of from 0.25
inch to 0.40 inch, and wherein the cable has a completed diameter of from 0.50 inch to 0.54 inch;

an inner layer of a plurality of first armor wires surrounding said cable core, said first armor wires being imbedded in said
first layer of polymer to prevent gaps between said first armor wires and said cable core; and

an outer layer of a plurality of second armor wires surrounding said inner layer, said second armor wires having a smaller
diameter than a diameter of said first armor wires for preventing torque imbalance in the cable, wherein the diameter of armor
wires in the inner layer are from 0.05 inch to 0.07 inch and the diameter of armor wires in the outer layer are from 0.03
inch to 0.05 inch.

US Pat. No. 9,091,136

SUBSEA SAFETY VALVE SYSTEM

Schlumberger Technology C...

1. A safety valve assembly for control of a subsea well below an offshore platform, the assembly comprising:
a separation segment of a landing string providing tubular access to the platform, said segment for separating upon exposure
to a predetermined condition;

a valve segment positioned below said separation segment and for governing access to the well;
a supplemental power segment positioned below said separation segment to provide supplemental powering upon the separating
of said separation segment; and

a relay mechanism coupled to said separation segment and said supplemental power segment to communicate the separating of
said separation segment for triggering the supplemental powering by said supplemental power segment.

US Pat. No. 9,431,375

HIGH DENSITY MICROELECTRONICS PACKAGING

SCHLUMBERGER TECHNOLOGY C...

1. A high temperature multi-chip module packaging comprising:
a ceramic substrate having a first side and a second side;
a housing having at least one hole extending therethrough, wherein the at least one hole has a first diameter portion and
a second diameter portion, wherein a shoulder is formed between the first diameter portion and the second diameter portion,
and wherein a diameter of the first diameter portion is different than a diameter of the second diameter portion;

a plurality of metal posts that are brazed to the ceramic substrate and welded to the housing, wherein a base of a first of
the metal posts is in physical contact with the shoulder;

a first active die positioned on the first side of the ceramic substrate;
a second active die stacked vertically on the first active die;
one or more bonding pads attached to the first side of the ceramic substrate;
a first bonding wire connected to the first active die and the one or more bonding pads; and
a second bonding wire connected to the second active die and the one or more bonding pads.

US Pat. No. 9,134,457

MULTISCALE DIGITAL ROCK MODELING FOR RESERVOIR SIMULATION

Schlumberger Technology C...

1. A computer-implemented method for upscaling with a processing system, borehole-scale digital rock modeling data representing
reservoir rock, the method comprising:
using the processing system to upscale the borehole-scale digital rock modeling data to interwell-scale digital rock modeling
data based at least in part on combining the borehole-scale digital rock modeling data with interwell-scale source data to
generate interwell-scale digital rock modeling data that at least partially captures heterogeneity at an interwell scale;

using the processing system to upscale the generated interwell-scale digital rock modeling to generate full-field-scale digital
rock modeling data wherein the borehole-scale digital rock modeling data has been at least partially upscaled from pore-scale
digital rock modeling data; and

wherein the upscaling to generate full-field-scale digital rock modeling data is based at least in part on computed values
at an interwell-scale from the interwell-scale digital rock modeling data.

US Pat. No. 9,371,728

DOWNHOLE PRESSURE COMPENSATOR AND METHOD OF SAME

SCHLUMBERGER TECHNOLOGY C...

1. A pressure compensation system for at least one sensor positionable in a wellbore penetrating a subterranean formation,
the wellbore having a wellbore fluid therein, comprising:
a downhole tool positionable in the wellbore, the downhole tool comprising the at least one sensor; and
at least one pressure compensator positionable in the downhole tool, comprising:
a first compensating fluid section having a first compensating fluid therein;
a first pressure compensation section in pressure communication with the wellbore fluid and the first compensating fluid section,
the first pressure compensation section having a first pressure regulation device separating the wellbore fluid from the first
compensating fluid and for adjusting a compensation pressure of the first compensating fluid based on a wellbore pressure
of the wellbore fluid;

at least one second compensating fluid section having a second compensating fluid therein, the second compensating fluid is
in contact with the at least one sensor;

at least one second pressure compensation section in pressure communication with the first compensating fluid section and
the at least one second compensating fluid section, the at least one second pressure compensation section having a second
pressure regulation device separating the first compensating fluid from the second compensating fluid and for adjusting a
sensor pressure of the second compensating fluid based on the compensation pressure of the first compensating fluid;

at least one third compensating fluid section having a third compensating fluid therein, the third compensating fluid is in
contact with the at least one sensor, and

at least one third pressure compensation section in pressure communication with the wellbore fluid and the at least one third
compensating fluid section, the at least one third pressure compensation section having a third pressure regulation device
separating the wellbore fluid from the third compensating fluid and for adjusting a sensor pressure of the third compensating
fluid based on the wellbore pressure of the wellbore fluid.

US Pat. No. 9,603,233

PARTICLE ACCELERATOR WITH A HEAT PIPE SUPPORTING COMPONENTS OF A HIGH VOLTAGE POWER SUPPLY

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus for downhole logging, comprising:
a) an enclosure having a metal target having a target face that generates neutrons in response to bombardment of ions accelerated
thereto;

b) a high voltage power supply including (i) a high voltage power supply (HVPS) bulkhead and (ii) a plurality of electronic
components electrically coupled to said target, wherein said plurality of electronic components generate a voltage with a
magnitude of at least 50 kV; and

c) a heat pipe disposed between said HVPS bulkhead and said target, said heat pipe having a housing portion with an exterior
surface supporting said plurality of electronic components of said high voltage power supply, said heat pipe being in thermal
contact with said target and comprising a wick and heat transfer fluid disposed within said housing portion, the wick for
circulating the heat transfer fluid within the housing portion in order to transfer heat away from the target to said HVPS
bulkhead.

US Pat. No. 9,322,267

DOWNHOLE SAMPLING OF COMPRESSIBLE FLUIDS

Schlumberger Technology C...

5. A method for obtaining at least one of a compressible and a non-compressible fluid, the method comprising:
(a) deploying a downhole sampling tool in a subterranean borehole, the sampling tool including fluid analysis module, a fluid
pumping module including a bypass valve in parallel with a pump, and first and second fluid sampling vessels both deployed
downstream of the fluid pumping module;

(b) pumping downhole fluid through the fluid analysis module until a desired fluid purity or property is obtained;
(c) measuring a gas content of the downhole fluid;
(d) comparing the gas content measured in (c) with a predetermined threshold;
(e) pumping downhole fluid into the first fluid sampling vessel when the gas content is less than the predetermined threshold;
and

(f) turning off the pump and opening the bypass valve thereby enabling the downhole fluid to flow into the second fluid sampling
vessel when the gas content is greater than the predetermined threshold; wherein (f) further comprises closing the bypass
valve and turning on the pump to further pressurize the downhole fluid in the second fluid sampling vessel.

US Pat. No. 9,217,299

DRILLING BOTTOM HOLE ASSEMBLY HAVING WIRELESS POWER AND DATA CONNECTION

Schlumberger Technology C...

1. A method for providing wireless power and data communications in a bottom hole assembly for use in a drill string, the
method comprising:
coupling a measuring-while-drilling (MWD) module to a drill string;
locating a wireless power and data connection above a drilling motor in the drilling string, the wireless power and data connection
for providing power and data between the MWD module and the drilling motor; and

coupling a rotary steerable system (RSS) to the drilling motor for receiving power from and communicating with the MWD module
via the wireless power and data connection;

electrically coupling first and second coils in the wireless power and data connection with a coupling coefficient, k, wherein,
k=M/?{square root over (L1L2)}?0.9, M is a mutual inductance between the first and second coils, L1 is a first self-inductance of the first coil, and L2 is a second self-inductance of the second coil; and

resonantly tuning the first coil at a first frequency, f1, with a first capacitance, C1, and the second coil at a second frequency, f2, with a second capacitance, C2, wherein f1 is approximately equal to f2,


wherein the first and second coils have a figure of merit, U, wherein U=k?{square root over (Q1Q2)}?3,

Q1 and Q2 comprise respective quality factors associated with the first and second coils, and R1 and R2 comprise respective resistances of the first and second coils.

US Pat. No. 9,175,523

ALIGNING INDUCTIVE COUPLERS IN A WELL

Schlumberger Technology C...

14. A method usable with a well, comprising:
after a first completion equipment section is installed in the well, running a second completion equipment section downhole
to engage the first completion equipment section; and

providing a mechanism comprising a snap latch or a no go shoulder, wherein the mechanism limits relative movement between
the first and second completion equipment sections, and wherein the mechanism provides feedback indicative of whether a first
inductive coupler of the first completion equipment is substantially aligned with a second inductive coupler of the second
completion equipment section; and

providing a telescoping joint to limit relative movement between the first and second inductive couplers after the second
completion equipment section engages the first completion equipment section.

US Pat. No. 9,383,176

SHAPED CHARGE ASSEMBLY SYSTEM

SCHLUMBERGER TECHNOLOGY C...

1. A method of shaped charge assembly at an oilfield, the method comprising:
shipping a container of substantially universal pre-manufactured unlined explosive pellet assemblies to the oilfield; and
selecting a specifically tailored charge liner from a group of substantially variable liners; and
combining the selected liner with any one of the assemblies to form a shaped charge having performance characteristics determined
by the selected liner.

US Pat. No. 9,368,901

SYSTEM AND METHOD FOR REDUCING PARTICULATE MATTER IN CONNECTORS FOR A WELLSITE DRILLING OPERATION

SCHLUMBERGER TECHNOLOGY C...

1. A breakable coupling mechanism comprising:
a center pin supporting a first electrical potential;
an outer case supporting a second electric potential different from the first electric potential;
a hollow member for receiving the outer case;
a fluid seal between the outer case and the hollow member; and
a spring surrounding the outer case and positioned between the hollow member and the outer case for conducting a signal and
which permits movement of the outer case relative to the hollow member, the spring comprising a canted coil spring for supporting
load forces and for passing electrical current.

US Pat. No. 9,410,394

METHODS FOR MINIMIZING OVERDISPLACEMENT OF PROPPANT IN FRACTURE TREATMENTS

Schlumberger Technology C...

1. A method of treating a subterranean formation penetrated by a wellbore comprising:
generating a fracture in the subterranean formation;
injecting a treatment fluid into the wellbore at a fluid pressure equal to or greater than a fracture initiation pressure
of the subterranean formation, wherein the treatment fluid is used to transport a predetermined amount of a proppant into
the wellbore;

while the treatment fluid is being injected, introducing a plugging agent without lowering the fluid pressure, wherein the
plugging agent is introduced into the treatment fluid after the entire predetermined amount of the proppant is introduced
into the wellbore, but before the entire predetermined amount of proppant reaches the fracture, wherein the method further
comprises pumping a volume of spacer between a tail end of the proppant and a leading edge of the plugging agent, said volume
being less than a volume of the wellbore between a surface opening of the wellbore and the fracture to be plugged with the
degradable plug; and

forming a removable plug from the plugging agent in the fracture thus preventing overdisplacement of proppant that entered
the fracture.

US Pat. No. 9,328,605

METHOD AND APPARATUS FOR DETECTING FLUID FLOW MODULATION TELEMETRY SIGNALS TRANSMITTED FROM AN INSTRUMENT IN A WELLBORE

SCHLUMBERGER TECHNOLOGY C...

1. A method for transmitting downhole measurements to a surface location, the method comprising:
deploying a mud pulse telemetry transmitter in a drill string in a subterranean wellbore;
causing the mud pulse telemetry transmitter to modulate a flow of drilling fluid in the drill string, said modulated flow
generating an acoustic signal in the drilling fluid, the acoustic signal representative of the downhole measurements;

deploying an accelerometer on an exterior surface of a conduit providing fluid communication between a discharge side of a
drilling fluid pump and an inlet to the drill string;

using the accelerometer to receive the acoustic signal in the drilling fluid; and
converting said received acoustic signal in the drilling fluid into representations of the downhole measurements;
wherein the accelerometer is deployed at a position corresponding to a maximum amplitude of a standing wave generated in the
conduit by the mud pulse telemetry transmitter and a minimum amplitude of a noise signal generated in the conduit by a drilling
fluid pump.

US Pat. No. 9,133,683

CHEMICALLY TARGETED CONTROL OF DOWNHOLE FLOW CONTROL DEVICES

Schlumberger Technology C...

1. A method of chemically targeting control of flow control devices installed in a wellbore comprising:
by an operator, selecting for actuation at least one of a plurality of flow control devices previously installed in a wellbore,
leaving at least one of said plurality of flow control devices as non-selected for actuation;

selecting a triggering chemical fluid configured to selectively trigger actuation of said flow control devices selected for
actuation and configured not to trigger actuation of said flow control devices non-selected for actuation;

flowing said selected triggering chemical fluid from a surface location through the wellbore and to expose both said flow
control devices selected for actuation and said flow control devices non-selected for actuation to said triggering chemical
fluid;

selectively triggering actuations of said flow control devices selected for actuation, said actuations being caused by one
or more chemical reactions resulting from exposure with said triggering chemical fluid, leaving un-actuated said flow control
devices non-selected despite being exposed to said triggering chemical fluid; and wherein the triggering chemical fluid dissolves
a mechanical stop retaining a choking member actuated with one or more spring members.

US Pat. No. 9,244,034

ELECTROCHEMICAL PH MEASUREMENT

Schlumberger Technology C...

1. A method of measuring the pH of an aqueous liquid, comprising
exposing the aqueous liquid comprising buffer at a concentration of 0.01 molar or less to an electrochemical sensor comprising
an electrode with a redox active compound immobilized to the electrode with at least one functional group convertible electrochemically
between reduced and oxidized forms upon transfer of at least one proton between the compound and surrounding aqueous phase,

wherein the reduced form of the redox active compound incorporates a partial structure,

wherein the oxidized form of the redox active compound incorporates a partial structure,

where the carbon atoms are joined by conjugated bonds in both the reduced form and the oxidized form of the redox active compound,
wherein the compound has at least one keto group, which is positioned to participate in internal hydrogen bonding with the
at least one functional group in its reduced form and increases the reaction rate of proton transfer by reducing the activation
energy for transfer of a proton and/or promoting hydrogen bonding at a said functional group,


and
observing the redox reaction at the electrochemical sensor.

US Pat. No. 9,394,750

COLLET COUPLING FOR ELECTRIC SUBMERSIBLE PUMP SHAFTS

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus, comprising:
a coupling for joining two rotatable shafts in an electric submersible pump (ESP) string;
a hollow tubular member of the coupling for receiving an end of each of the two rotatable shafts;
at least one collet for fixing the coupling to at least one of the two rotatable shafts, wherein the at least one collet comprises
a three-piece member, wherein a first collet member includes the hollow tubular member threaded at each end for adjustably
receiving a second collet member on one end and a third collet member on the other end;

expandable fingers on at least one end of the second collet member and on at least one end of the third collet member for
applying a radial force to an outside diameter of at least one of the two rotatable shafts wherein the second collet member
and the third collet member are each adjustable with respect to the first collet member via the threaded ends of the first
collet member;

ribs on the fingers for latching into at least one groove on at least one of the two rotatable shafts; and
shoulders on the at least one groove for transmitting and receiving axial load forces between the two rotatable shafts through
the ribs, expandable fingers, and the at least one collet.

US Pat. No. 9,297,743

DETERMINATION OF STICK SLIP CONDITIONS

Schlumberger Technology C...

1. A method for determining stick slip conditions, comprising:
disposing an operating apparatus in fluid communication with a pressure wave transmission medium;
disposing at least one pressure measurement device at least partially within the pressure wave transmission medium and at
some distance from the operating apparatus;

measuring one or more pressure waves generated by the operating apparatus within the pressure wave transmission medium with
the at least one pressure measurement device and generating pressure measurement data therefrom;

transmitting the pressure measurement data from the at least one pressure measurement device to a data acquisition system;
and

analyzing the pressure measurement data using the data acquisition system to detect one or more stick slip conditions from
one or more variations in the pressure measurement data.

US Pat. No. 9,383,465

QUANTITATIVE ANALYSIS OF TIME-LAPSE SEISMIC DATA

SCHLUMBERGER TECHNOLOGY C...

1. A method for managing a reservoir in a field comprising subterranean formations, comprising:
obtaining time-lapse seismic data of the reservoir;
obtaining a plurality of compressional and shear velocities from a seismic inversion analysis of the time-lapse seismic data;
selecting a rock physics model based on a property of the reservoir;
calculating, by a computer processor, a transform function using the rock physics model, wherein the transform function transforms
variations in the plurality of compressional and shear velocities into variations in saturation and pore pressure;

calculating, by the computer processor, a transform grid performing a domain transformation of the transform function;
obtaining a plurality of cloud points from the seismic inversion analysis and the transform grid; and
overlaying the plurality of cloud points onto the transform grid to estimate a plurality of reservoir parameters of the reservoir,
wherein the plurality of reservoir parameters is used to determine an adjustment of a field operation to manage a recovery
of fluids from the reservoir.

US Pat. No. 9,322,747

ISOTHERMAL SUBSEA SAMPLING SYSTEM AND METHOD

SCHLUMBERGER TECHNOLOGY C...

1. A system for collecting at least one selected phase of a representative sample from a multiphase fluid flowing through
a flowline, the system comprising:
a multiphase sampling apparatus attachable to a flowline for sampling a representative sample of a multiphase fluid flowing
through the flowline, wherein the multiphase sampling apparatus comprises a first sampling port and a second sampling port
in fluid communication with the multiphase fluid flowing through the flowline for sampling the representative sample;

a vehicle sampling apparatus locatable proximate the flowline, the vehicle sampling apparatus comprising a power supply and
a fluid sample collector for storing the at least one selected phase of the representative sample;

an interface for connecting the multiphase sampling apparatus and the vehicle sampling apparatus; and
a heating element configured to minimize the temperature difference between the representative sample and the multiphase fluid
flowing through the flowline.

US Pat. No. 9,217,809

ANTENNA OF AN ELECTROMAGNETIC PROBE FOR INVESTIGATING GEOLOGICAL FORMATIONS

Schlumberger Technology C...

1. An antenna (3) of an electromagnetic probe used in investigation of geological formations (GF) surrounding a borehole (WBH) comprising
a conductive base (31) and an antenna element (32), the conductive base (31) comprising an opened non-resonant cavity (33), the antenna element (32) being embedded in the cavity (33) and going right through the cavity, the antenna element (32) being isolated from the conductive base (31), the antenna element (32) being coupled to at least one electronic module via a first (34A) and a second (34B) port, respectively, the electronic module configured to apply a current distribution to the antenna element via one or
more of the first and second ports, such that the antenna is operated in a substantially pure magnetic dipole when the current
distribution is applied to the antenna such that current increases from a first end of the antenna to a middle portion of
the antenna, and then decreases from the middle portion of the antenna to a second end of the antenna, and a substantially
pure electric dipole when the current distribution is applied to the antenna such that current increases from the first end
of the antenna to the second end of the antenna.

US Pat. No. 9,382,790

METHOD AND APPARATUS FOR COMPLETING A MULTI-STAGE WELL

SCHLUMBERGER TECHNOLOGY C...

1. A method comprising:
deploying a string comprising a tool in a well;
perforating a designated region of the tool, the perforating causing a seat of the tool to shift from a first position which
the seat is adapted to allow an object deployed in the string to pass through the seat to a second position in which the seat
is adapted to catch the object to form a fluid barrier in the string;

deploying the object into the string using a perforating gun and releasing the object from the perforating gun so that the
object becomes untethered in the string;

catching the object on the seat to form the fluid barrier; and
diverting fluid in the string using the fluid barrier.

US Pat. No. 9,316,519

SAMPLE CAPTURE ASSURANCE FOR SAMPLE BOTTLES

SCHLUMBERGER TECHNOLOGY C...

1. An arrangement for determining a state of a sample bottle, comprising:
an external housing defining an interior space;
a fluid chamber configured to hold a fluid obtained from an environment, the fluid chamber within the external housing and
the interior space;

a separation piston positioned at one end of the fluid chamber, the separation piston configured to move from a first position
to a second position;

a closure device configured to establish a closure of the fluid chamber;
a central rod positioned within the external housing, the central rod configured to interface with the separation piston and
move the separation piston from the first position to the second position;

a protrusion extending from the central rod, the protrusion extending into a flowline; and
a limit switch located at a peripheral end of the protrusion, the limit switch configured to limit movement of the central
rod when the limit switch is activated.

US Pat. No. 9,175,515

WIRED MUD MOTOR COMPONENTS, METHODS OF FABRICATING THE SAME, AND DOWNHOLE MOTORS INCORPORATING THE SAME

Schlumberger Technology C...

1. A system for drilling, comprising:
a drive shaft for transmitting a torque to a downhole tool, the drive shaft having a hollow central passage formed by a tubular
wall extending along a longitudinal axis L thereof, the hollow central passage allowing a flow of a drilling fluid through
a bearing section of the system; and

an elongated flow diverter disposed in the tubular wall of the drive shaft, the elongated flow diverter having a body comprising
a plurality of axially-spaced apertures distributed along the longitudinal axis L of the drive shaft and the hollow central
passage, the distribution of the plurality of apertures along the longitudinal axis L reducing the impingement of the drilling
fluid while diverting the flow of the drilling fluid from an upstream annulus section of the system to the hollow central
passage.

US Pat. No. 9,372,277

NEUTRON POROSITY DOWNHOLE TOOL WITH IMPROVED PRECISION AND REDUCED LITHOLOGY EFFECTS

SCHLUMBERGER TECHNOLOGY C...

1. A downhole neutron porosity tool comprising:
a neutron source configured to emit neutrons into a subterranean formation;
a neutron monitor configured to detect a count rate of neutrons proportional to the neutrons emitted by the neutron source;
a neutron detector configured to detect a count rate of neutrons scattered off the subterranean formation;
data processing circuitry configured to determine an environmentally corrected porosity configured to be output to an operator
as representative of a true porosity of the subterranean formation using neutron measurements consisting of the count rate
of neutrons scattered off the subterranean formation normalized to the count rate of neutrons proportional to the neutrons
emitted by the neutron source to thereby determine the environmentally corrected porosity without using a ratio of count rates
from any other neutron detector ; and

an output device configured to output an indication of the environmentally corrected porosity as representative of the true
porosity of the subterranean formation.

US Pat. No. 9,366,559

CORIOLIS FLOW METER

Schlumberger Technology C...

5. A Coriolis flow meter comprising:
a vibratable measurement conduit configured, in use, to convey a wet gas flow;
a first system configured to measure an input energy required to vibrate the conduit;
a second system configured to measure vibrational energy of the conduit; and
a processor configured to determine a liquid volume fraction of the wet gas flow from the input energy and the vibrational
energy, wherein the liquid volume fraction of the wet gas flow is determined from a ratio of the input energy to the vibrational
energy.

US Pat. No. 9,360,578

SYSTEMS AND METHODS FOR OPTIMIZING LOW FREQUENCY OUTPUT FROM AIRGUN SOURCE ARRAYS

Schlumberger Technology C...

1. A system for increasing low frequency output of a marine source array, comprising:
a plurality of airguns arranged such that the airguns are held by a framework in sufficiently close proximity to one another
to generate an effective bubble energy of more than 4000·103 psi·in3 for at least some of the airguns.

US Pat. No. 9,732,609

DISTRIBUTED CLAMPS FOR A DOWNHOLE SEISMIC SOURCE

SCHLUMBERGER TECHNOLOGY C...

1. A method of using a clamped seismic or acoustic source disposed in a wellbore without damaging the borehole/casing/cement,
comprising:
providing a modular source with a plurality of source modules for producing a source signal;
coupling the modular source to a conveyance mechanism;
running the modular source along the wellbore via the conveyance mechanism;
applying distributed clamping to clamp the modular source to the wellbore; and
generating the source signal using the modular source while clamped to the wellbore, the generating comprising driving a selected
set of source modules of the plurality of source modules to provide a maximum active length of the modular source based on
a desired operating frequency of the source signal.

US Pat. No. 9,129,770

ION SOURCE HAVING NEGATIVELY BIASED EXTRACTOR

Schlumberger Technology C...

1. An ion source for use in a radiation generator comprising:
a sealed envelope configured to contain an ionizable gas;
a radio frequency (RF) antenna associated with the sealed envelope, wherein the RF antenna is configured to generate time-varying
electromagnetic fields within the sealed envelope to produce ions from the ionizable gas; and

at least one extractor within the sealed envelope, wherein the at least one extractor is configured to be pulsed to a negative
potential with respect to ground during operation such that the ions are attracted toward the at least one extractor.

US Pat. No. 9,318,271

HIGH TEMPERATURE SUPERCAPACITOR

SCHLUMBERGER TECHNOLOGY C...

1. A supercapacitor device, comprising:
a housing; and
at least one supercapacitor cell disposed in the housing, the supercapacitor cell comprising:
two working electrode layers separated by an electrode separator wherein each working electrode layer is electrically connected
to a current collector;

and
an ionic liquid electrolyte disposed within the area occupied by the working electrode layers and the electrode separator,
wherein the ionic liquid electrolyte has at least one cationic component comprising a central cation with an asymmetric arrangement
of substituents bonded thereto, wherein the cationic component has the generic formula (Rx)n Z+ where Z+ is the ammonium,
phosphonium, or sulfonium cation, the Rx substituents are linear or branched alkyl groups comprising 1-12 carbon atoms and
may be the same alkyl group or different alkyl groups, n=4 for the ammonium and phosphonium cations, and n=3 for the sulfonium
cation.

US Pat. No. 9,303,203

THERMOVISCOELASTIC SYSTEM FLUID AND WELL TREATMENT METHOD

SCHLUMBERGER TECHNOLOGY C...

1. A thermoviscoelastic system fluid useful in a well treatment fluid, comprising:
a polymer and a viscoelastic surfactant in an aqueous medium;
wherein the polymer comprises a hydrophilic backbone and LCST grafts comprising a component selected from the group consisting
of a polyalkylene oxide, a polyvinylmethylether, a poly N-isopropylacrylamide, a cellulosic derivative, and combinations thereof;

wherein the polymer has a lower critical solution temperature (LCST); wherein the LCST grafts are hydrophilic below the LCST
and hydrophobic above the LCST; and

wherein the fluid has a low viscosity at a temperature just below the lower critical solution temperature relative to the
fluid viscosity just above the lower critical solution temperature.

US Pat. No. 9,163,500

EXTENDABLE AND ELONGATING MECHANISM FOR CENTRALIZING A DOWNHOLE TOOL WITHIN A SUBTERRANEAN WELLBORE

Schlumberger Technology C...

13. A method comprising:
providing a downhole tool conveyable within a wellbore extending into a subterranean formation, wherein the downhole tool
comprises:

a feature to physically interface the formation or a sidewall of the wellbore via direct physical contact; and
first and second setting pistons each extendable from the downhole tool along paths substantially parallel to one another
and extending in a first direction substantially opposite the feature;

attaching a rigid member to the first and second setting pistons such that the rigid member spans the first and second setting
pistons, wherein a length of the rigid member is variable in a second direction that is substantially different from the first
direction and wherein the rigid member comprises:

a first portion coupled to the first setting piston but not the second setting piston; and
a second portion coupled to the second setting piston but not the first setting piston, wherein the first and the second portions
translate relative to one another;

conveying the downhole tool with the attached rigid member within the wellbore;
physically interfacing the feature with the sidewall of the wellbore; and
extending the first and second setting pistons and the attached rigid member in the first direction, away from the downhole
tool and into contact with the sidewall of the wellbore opposite the feature interface with the sidewall of the wellbore,
wherein the first portion and the second portion of the rigid member each contact the sidewall of the wellbore.

US Pat. No. 9,157,318

DETERMINING DIFFERENTIAL STRESS BASED ON FORMATION CURVATURE AND MECHANICAL UNITS USING BOREHOLE LOGS

Schlumberger Technology C...

1. A method for performing wellbore operations of a field having a subterranean formation, the method comprising:
determining, based on an image log of a wellbore penetrating the subterranean formation, a plurality of interpreted geological
surfaces;

identifying a plurality of estimated slickensides from the plurality of interpreted geological surfaces based on at least
one pre-determined criterion;

calculating, using a processor, a differential stress using a curvature model representing a formation curvature in at least
one mechanical unit defined by the plurality of estimated slickensides;

generating a stress model using the differential stress;
identifying a modeled wellbore stress-induced failure in response to a total stress value in the stress model exceeding a
strength property of the subterranean formation;

determining a difference between the modeled wellbore stress-induced failure and an observed stress-induced failure in the
subterranean formation; and

updating the stress model by adjusting the plurality of estimated slickensides to, in turn, adjust the difference
wherein generating the stress model comprises revising an initial stress model of the subterranean formation using the differential
stress, wherein the initial stress model represents at least far-field stresses of a wellbore in the subterranean formation,

wherein the plurality of interpreted geological surfaces comprises a curvature determined from the image log,
wherein the plurality of interpreted geological surfaces correspond to actual geological surfaces disposed about the wellbore
in the subterranean formation, and

wherein the curvature model represents the at least one mechanical unit as a bent layer based on a curvature of the plurality
of interpreted geological surfaces.

US Pat. No. 9,243,476

SYSTEM AND METHOD FOR SIMULATING OILFIELD OPERATIONS

Schlumberger Technology C...

1. A method for simulating oilfield operations, comprising:
receiving two or more reservoir models to be simulated;
receiving two or more surface models to be simulated;
automatically generating a communication file to couple the two or more reservoir models with the two or more surface models,
wherein automatically generating the communication file comprises:

receiving a communication file template; and
modifying information in the communication file template to correspond to variables and parameters of the reservoir models
and the surface models; and

automatically simulating the coupled reservoir models and surface models using the communication file such that the communication
file manages and balances the coupled reservoir models and surface models by taking into account one or more restrictions
set forth by one or more parameters of the reservoir models and the surface models.

US Pat. No. 9,404,327

METHODS FOR EVALUATING BOREHOLE VOLUME CHANGES WHILE DRILLING

SCHLUMBERGER TECHNOLOGY C...

1. A method for identifying a borehole washout event while drilling a subterranean wellbore, the method comprising:
(a) pumping drilling fluid through a drill string located in a subterranean wellbore, the drill string including a plurality
of axially spaced along string pressure sensors, said pumping operative to create a downstream flow rate in the drill string
and an upstream flow rate in an annulus external to the drill string;

(b) rotating a drill bit deployed on an end of the drill string, said rotating operative to drill the subterranean wellbore;
(c) using the plurality of along string pressure sensors to make a corresponding plurality of subsurface annular pressure
measurements at a corresponding plurality of measured depths while drilling in (a) and (b);

(d) transmitting the plurality of pressure measurements to a processor;
(e) causing the processor to process the plurality of measurements made in (c) to compute a plurality of annular interval
densities;

(f) monitoring the plurality of annular interval densities computed in (e) with time while drilling in (a) and (b); and
(g) evaluating (i) a decrease in at least one of the annular interval densities and a substantially constant differential
flow rate between the downstream and upstream flow rates as an indicator of the borehole washout and (ii) evaluating a decrease
in a measured annular interval static density obtained by removing annular friction effects from the measured annular interval
circulating density below a modeled annular interval static density as a further indicator of the borehole washout.

US Pat. No. 9,357,629

NEUTRON GENERATOR

Schlumberger Technology C...

1. A neutron generator comprising:
a sealed envelope providing a low pressure environment for a gas, said sealed envelope including a target electrode spaced
apart from an ion source including at least one electrode;

a high voltage power supply circuit for supplying a positive high voltage signal to the at least one electrode of said ion
source, said positive high voltage signal having a low voltage signal component floating on a positive high voltage signal
component;

high voltage insulation that surrounds and electrically insulates said high voltage power supply circuit;
a control circuit, isolated from said high voltage power supply circuit and operating at low voltage potentials, for controlling
generation of the low voltage signal component, wherein the control circuit includes an inductive interface for interfacing
said control circuit to said high voltage power supply, the inductive interface including a transmitter coil located external
to said high voltage insulation and a pickup coil located inside said high voltage insulation and electrically coupled to
the at least one electrode of said ion source; and

wherein said at least one electrode of said ion source operates at the positive high voltage potential of the positive high
voltage signal and said target electrode operates at or near ground potential in order to accelerate ions of a plasma produced
by said ion source toward said target electrode to induce collisions of ions with target material in the target electrode,
thereby causing reactions that generate neutrons.

US Pat. No. 9,475,981

FLUID VISCOSITY CONTROL

SCHLUMBERGER TECHNOLOGY C...

1. A method of treating a subterranean formation penetrated by a wellbore, the method comprising:
introducing a treatment fluid comprised at least a crosslinkable component, and a metal crosslinker comprising a polyvalent
metal ion to the subterranean formation;

forming a crosslinked treatment fluid, and
de-crosslinking bonds of the crosslinked treatment fluid by increasing a pH of the treatment fluid with a pH triggering agent,
wherein the pH triggering agent is an amine-precursor compound or a derivative thereof.

US Pat. No. 9,296,943

SUBTERRANEAN TREATMENT FLUID COMPOSITION AND METHOD OF TREATMENT

SCHLUMBERGER TECHNOLOGY C...

1. A method, comprising:
adding from 0.1% to 10% by weight cement, and from 4% to 40% by weight of a source of calcium ions selected from the group
consisting of calcium oxide, calcium hydroxide and calcium carbonate, to an aqueous treatment fluid containing a polymer,
proppant and water, based on the weight of the resulting composition;

increasing the viscosity of the aqueous treatment fluid.

US Pat. No. 9,184,019

ION SOURCE HAVING NEGATIVELY BIASED EXTRACTOR

Schlumberger Technology C...

1. An ion source for use in a radiation generator comprising:
an active cathode configured to emit electrons on a trajectory away from the active cathode, at least some of the electrons
as they travel interacting with an ionizable gas to produce ions; and

at least one extractor downstream of the active cathode having a potential such that the ions are attracted toward the at
least one extractor,

wherein the extractor is biased to a negative potential.

US Pat. No. 9,404,357

SHOCK TOLERANT HEAT DISSIPATING ELECTRONICS PACKAGE

SCHLUMBERGER TECHNOLOGY C...

1. An electronics package comprising:
a housing defining a channel therethrough;
a first electronics chassis disposed in the channel with a first inclined surface at an end thereof;
a second electronics chassis disposed in the channel adjacent said first electronics chassis and with a second inclined surface
at another end thereof; and

a screw operatively disposed through the housing and configured to apply axial downward force to the first electronics chassis
adjacent thereto; and a stop structurally integral with the housing and adjacent the second electronics chassis.

US Pat. No. 9,394,202

COMPOSITIONS AND METHODS FOR WELL CEMENTING

SCHLUMBERGER TECHNOLOGY C...

1. A method for cementing a subterranean well having a borehole, comprising:
(i) providing a cementing composition comprising:
a. a geopolymer composition consisting of an aluminosilicate source, an activator and a carrier fluid; and
b. a retarder that comprises at least one organic compound comprising at least one nitrogen atom such that the retarder retards
a setting time, a thickening time, or both of the geopolymer composition;

(ii) pumping the composition into the borehole; and
(iii) allowing the composition to set and harden,
wherein the activator is a carbonate salt, a metal silicate, a metal aluminate, sodium hydroxide or potassium hydroxide,
wherein the geopolymer composition undergoes dissolution followed by polycondensation to form a poly(sialate) network, a poly(sialate-siloxo)
network or a poly(sialate-disiloxo) network.

US Pat. No. 9,359,862

WELLBORE ISOLATION WHILE PLACING VALVES ON PRODUCTION

Schlumberger Technology C...

1. A method, comprising:
anchoring an internal completion string within a plurality of casing valves of a production liner in a wellbore that extends
from the Earth's surface into a subterranean formation, wherein:

the internal completion string comprises a plurality of shifting tools; and
each casing valve comprises a port and a movable member;
sealing an annulus defined between the production liner and the internal completion string; and
remotely operating the plurality of shifting tools to selectively open or close each casing valve without mechanically moving
the internal completion string to a different location in the production liner.

US Pat. No. 9,323,582

NODE TO NODE COLLABORATION

SCHLUMBERGER TECHNOLOGY C...

1. A computer-implemented method of allowing a primary node to utilize node to node collaboration to improve a performance
of a computer generated earth model, comprising:
identifying an operation in a workflow to be shared, wherein the workflow comprises modeling a reservoir, a production operation,
or both, by running an oilfield services application;

assessing, using a computing device, an attractiveness of sharing the operation with at least one of one or more secondary
nodes based at least partially on a presence of an object associated with the workflow cached on the at least one of the one
or more secondary nodes by the primary node, wherein assessing the attractiveness of sharing the operation with at least one
of one or more secondary nodes comprises ranking a plurality of secondary nodes based at least in part on one or more resources
available to the respective secondary nodes, and wherein the one or more resources are selected from the group consisting
of processing capacity, memory availability, communication bandwidth, and communication speed;

assigning an object identifier to the object, wherein assessing the attractiveness of sharing the operation with at least
one of one or more secondary nodes further comprises identifying a resource associated with the at least one of the one or
more secondary nodes using the object identifier;

selecting at least one selected secondary node from the one or more secondary nodes based partially on whether the object
is cached on the at least one of the one or more secondary nodes by the primary node, and based partially on the ranking of
the plurality of secondary nodes;

sharing the operation with the at least one selected secondary node over a network;
splitting, by operation of the at least one selected secondary node, the operation shared therewith into two or more portions;
transmitting at least one of the two or more portions to another one of the one or more secondary nodes of the network, for
execution;

receiving a result of the operation over the network from the at least one selected secondary node; and
integrating the result of the operation into the workflow,
wherein the primary node and the plurality of secondary nodes are configured to execute in parallel, such that the primary
node is capable of being one of the plurality of secondary nodes, and at least one of the plurality of secondary nodes is
capable of being the primary node.

US Pat. No. 9,243,473

SWELLABLE PACKER

Schlumberger Technology C...

1. A packer usable with a well, comprising:
a tubular inner core; and
a swellable longitudinally segmented body mounted to the core and being adapted to swell in the presence of a triggering agent
to form an annular seal at an inner surface of the well, the swellable body longitudinally extending between first and second
ends of the body and comprising:

a first region forming a first segment of a first material located between the first and second ends of the swellable body
having an exposed surface to swell at a first rate and into sealing engagement with the inner surface;

a second region forming a second segments of a second material, the second segments located closer to each of the first and
second ends than the first region, the second segments having exposed surfaces exceeding an amount of the exposed surface
of the first segment and to swell at a second rate and into sealing engagement with the inner surface and at a rate that is
less than the first rate; and

a boundary between the first and second segments, the boundary tapered to tailor an increased surface exposure of one of the
first and second segments to the well and triggering agent.

US Pat. No. 9,133,674

DOWNHOLE TOOL ACTUATION HAVING A SEAT WITH A FLUID BY-PASS

Schlumberger Technology C...

1. A downhole tool comprising:
a tubular body having a wall with an internal surface defining a bore;
a reciprocating sleeve located within the bore, the reciprocating sleeve having an outside diameter and a segmented seat with
a fluid by-pass, the reciprocating sleeve configured to translate from a first position to a second position downhole from
the first position, the segmented seat having at least one seat segment positioned by the internal surface of the bore and
being configured to pass a fluid there through and receive an obstruction, and in response to receiving the obstruction, restricting
a flow of fluid while allowing a portion of the fluid sufficient to maintain drilling fluid functions downstream to flow through
the fluid by-pass past the segmented seat, the flow of fluid impinging on the obstruction causing the reciprocating sleeve
to move from the first position to the second position; and

a relief formed in the wall adjacent the outer diameter of the sleeve and proximate the at least one seat segment with the
reciprocating sleeve at the second position, the relief configured to relieve the at least one segment releasing the obstruction
when the sleeve is at the second position.

US Pat. No. 9,134,449

DIRECTIONAL RESISTIVITY MEASUREMENT FOR WELL PLACEMENT AND FORMATION EVALUATION

Schlumberger Technology C...

1. A method to determine a formation property of a subsurface formation, comprising:
providing a downhole logging tool having two or more antennas, wherein at least one of the two or more antennas is a multi-axial
antenna comprising:

a first transverse antenna component arranged as a first pair of diametrically opposed saddle coils having a transversely-sensitive
element that is sensitive in a direction transverse to a longitudinal axis of the downhole logging tool, wherein the first
transverse antenna component has a dipole moment that is substantially perpendicular to the longitudinal axis; and

an axial antenna component arranged as a coil wound around a body of the downhole logging tool and having an axially-sensitive
element that is sensitive in the direction of the longitudinal axis, wherein the axial antenna component has a dipole moment
that is substantially parallel to the longitudinal axis;

obtaining azimuthally-sensitive measurements using the antennas of the downhole logging tool;
fitting the measurement to a Fourier series having Fourier coefficients that include channel gains;
determining a DC component, a first harmonic component, and a second harmonic component from the Fourier series;
determining a measurement type using at least one of the DC component, the measurement type comprising at least one of symmetrized
cross-component measurements, anti-symmetrized cross component measurements, resistivity harmonic measurements and resistivity
anisotropy; and

determining the formation property of the subsurface information using the determined measurement type, wherein the DC component
is directly proportional to (XX+YY)/2, and wherein X is representative of a transverse axis and Y is representative of an
axis perpendicular to the transverse axis.

US Pat. No. 9,394,783

METHODS FOR EVALUATING INFLOW AND OUTFLOW IN A SUBTERRANEAN WELLBORE

Schlumberger Technology C...

1. A method for computing a density of an inflow constituent in a subterranean wellbore, the method comprising:
(a) rotating a drill bit in a subterranean wellbore, the drill bit being deployed in a drill string including first and second
axially spaced along string pressure sensors, said rotating operative to drill the wellbore and produce formation cuttings
which are transported to a surface location via drilling fluid in a wellbore annulus;

(b) using the first and second spaced along string pressure sensors to make first and second subsurface annular pressure measurements
at corresponding first and second measured depths in the wellbore;

(c) transmitting the first and second pressure measurements to a processor;
(d) causing the processor to process the first and second annular pressure measurements to compute an annular interval density
between the first and second measured depths in the wellbore; and

(e) causing the processor to process the annular interval density, a volume fraction of drilling fluid in the annular region,
a density of the drilling fluid in an annular region of the wellbore, a volume fraction of the cuttings in the annular region,
a density of the cuttings in the annular region, and a differential flow rate to compute the density of the inflow constituent.

US Pat. No. 9,115,567

METHOD AND APPARATUS FOR DETERMINING EFFICIENCY OF A SAMPLING TOOL

Schlumberger Technology C...

16. A method, comprising:
receiving, via a processor, a signal indicative of a sensed parameter of a downhole tool configured to receive and collect
samples of a formation fluid; and

determining, via the processor, an active duty-cycle efficiency of the downhole tool in facilitating a flow of the formation
fluid through the downhole tool based on the received signal, wherein the active duty-cycle efficiency is determined by dividing
an in-flow fluid interval by a one-stroke interval or by dividing an out-flow fluid interval by the one-stroke interval.

US Pat. No. 9,322,268

METHODS FOR RESERVOIR EVALUATION EMPLOYING NON-EQUILIBRIUM COMPOSITIONAL GRADIENTS

Schlumberger Technology C...

1. A method for characterizing a hydrocarbon reservoir of interest traversed by at least one wellbore, the method comprising:
(a) using a numerical model to simulate over time non-equilibrium concentration of at least one hydrocarbon component as a
function of location within the wellbore; and

(b) analyzing fluid samples acquired from at least one wellbore that traverses the reservoir of interest to measure concentration
of the at least one hydrocarbon component as a function of location within the wellbore;

(c) comparing the non-equilibrium concentration of the at least one hydrocarbon component as a function of location within
the wellbore resulting from the simulation of (a) to the concentration of the least one hydrocarbon component as a function
of location within the wellbore as measured in (b); and

(d) characterizing the reservoir of interest based upon the comparing of (c).

US Pat. No. 9,353,307

METHOD OF PREPARING POLYMER-WATER EMULSION AND FURTHER SETTLING A STICKY POLYMER MATERIAL IN DOWNHOLE ENVIRONMENT

Schlumberger Technology C...

1. A method of preparing water emulsion of at least one polymer hydrolysable in the downhole environment, the polymer incorporated
into the internal organic phase of the emulsion dispersed in an external water phase, wherein the organic phase further comprises
an organic solvent, an emulsifier, a viscosifying agent, wherein the organic phase and the water phase are mixed with intense
stirring in a high-speed disperser, a spray injector, or a field blender, to produce a stable emulsion at surface conditions,
and wherein the emulsion controllably decomposes in downhole conditions to produce droplets of sticky polymer.

US Pat. No. 9,103,202

GELLED FOAM COMPOSITIONS AND METHODS

Schlumberger Technology C...

1. A method comprising:
a. injecting into a wellbore, a composition comprising a solvent, a surfactant, a foaming gas, a polysaccharide foam enhancer,
a synthetic crosslinkable polymer, and a crosslinking agent capable of crosslinking the polymer,

wherein the foam enhancer maintains a foam stability for at least 2-4 hours after injection is stopped and until gelation
begins, and

wherein the crosslinking agent is an inorganic crosslinking agent selected from the group consisting of chromium salts, aluminates
and gallates; and

b. allowing viscosity of the composition to increase and form a gel that plugs at least a portion of the subterranean formation.

US Pat. No. 9,366,613

MATRIX PERMITIVITY DETERMINATION

SCHLUMBERGER TECHNOLOGY C...

1. A method for determining a matrix permittivity of a porous material, the method comprising:
measuring a first indicator indicative of a first dielectric permittivity of a fluid composition;
saturating the porous material with the fluid composition;
measuring a first response indicative of the dielectric permittivity of the saturated porous material;
altering a thermodynamic property of the fluid composition, wherein the altered thermodynamic property produces a change in
the dielectric permittivity of the fluid composition;

measuring a second indicator indicative of a second dielectric permittivity of the altered fluid composition;
measuring a second response indicative of the dielectric permittivity of the porous material saturated with the thermodynamically
altered fluid composition;

using the first and second indicators and the first and second responses to process the matrix permittivity of the porous
material.

US Pat. No. 9,322,240

INFLATABLE PACKER WITH A REINFORCED SEALING COVER

Schlumberger Technology C...

1. An inflatable packer having an inflation assembly connected between end fittings, the assembly comprising:
an inner bladder defining an axial length thereof; and
a sealing member positioned circumferentially about and extending substantially along the entire axial length of the inner
bladder, wherein the sealing member comprises an elastomeric matrix with reinforcement fibers disposed therein formed as a
composite structure to strengthen the sealing member, wherein the sealing member is not directly connected to the end fittings.

US Pat. No. 9,309,884

DOWNHOLE MOTOR OR PUMP COMPONENTS, METHOD OF FABRICATION THE SAME, AND DOWNHOLE MOTORS INCORPORATING THE SAME

SCHLUMBERGER TECHNOLOGY C...

1. A progressive cavity drive component, comprising:
a first progressive cavity drive component rotatably positionable within a longitudinal bore of a second progressive cavity
drive component, the first progressive cavity drive component comprising:

a metallic shaft having a length and an outer surface, the outer surface being apportioned along the length of the metallic
shaft in to a plurality of sections, the metallic shaft having a first helical configuration formed on the outer surface that
is complementary to a helical surface configuration of the second progressive cavity drive component, and

a resilient outer layer formed of a resilient material bonded to the outer surface of the metallic shaft along the length
of the metallic shaft, the resilient material further including a first resilient outer layer formed of a first material and
a second resilient outer layer formed of a second material different from the first material of the first resilient outer
layer, wherein the first resilient outer layer is formed to surround the metallic shaft at a first section of the plurality
of sections of the outer surface of the metallic shaft and the second resilient outer layer is formed to surround the metallic
shaft at a second section of the plurality of sections along the metallic shaft that is different from the first section.

US Pat. No. 9,310,505

TECHNIQUE AND SYSTEM FOR PERFORMING A CROSS WELL SURVEY

Schlumberger Technology C...

1. A method of calibrating a seismic velocity model to characterize a subterranean region between a first well and a second
well, comprising:
providing a seismic velocity model;
deploying a source in a first well and a seismic receiver in a second well at a known first location to detect a seismic event
caused by the source, the seismic receiver having a downhole clock;

providing a surface system having at least one surface clock;
synchronizing the downhole clock and the at least one surface clock to a common reference time frame;
commanding the source to initiate the seismic event;
determining an initiation time in reference time frame at which the source initiated the seismic event in the first well;
communicating seismic data indicative of an arrival time in reference time frame at which the seismic receiver detected the
seismic event in the second well;

referencing the detected arrival time in reference time frame with a predicted arrival time generated by the seismic velocity
model; and

using the detected arrival time in reference time frame and the initiation time in reference time frame as a constraint to
calibrate the seismic velocity model.

US Pat. No. 9,128,210

METHOD TO CHARACTERIZE SHALES AT HIGH SPATIAL RESOLUTION

Schlumberger Technology C...

1. A method of characterizing a subterranean formation sample, comprising:
collecting a sample from a formation; and
analyzing the sample to obtain an image with 100 nm or less resolution, wherein the analyzing comprises using atomic force
microscopy (AFM), infrared spectroscopy (IR), and thermal analysis.

US Pat. No. 9,366,776

INTEGRATED FORMATION MODELING SYSTEMS AND METHODS

Schlumberger Technology C...

1. A method of performing seismic analysis of a subterranean formation, comprising:
obtaining seismic data of the formation;
obtaining fluid from the formation;
analyzing at least some of the fluid to determine a fluid parameter;
generating a model of the formation based at least on the seismic data; and
determining whether or not to modify the model based on the fluid parameter,
wherein generating the model comprises generating the model based at least on the seismic data and the fluid parameter,
wherein modifying the model comprises interpreting the model based on the fluid parameter by correlating a location where
the analyzed fluid was obtained within the formation with a corresponding location on the model to identify fluid distribution
within the formation.

US Pat. No. 9,335,435

SYSTEM AND METHOD FOR IMPROVING SURFACE ELECTROMAGNETIC SURVEYS

Schlumberger Technology C...

1. A method, comprising:
drilling a well into a subterranean reservoir;
estimating an initial structure of the reservoir layers and a spatial distribution of resistivity parallel to a bedding and
perpendicular to the bedding along a trajectory of the well;

conducting a surface electromagnetic survey;
causing a processor to run an inversion of the surface electromagnetic survey using the estimated structure of the reservoir
layers and the estimated spatial distribution of the resistivity;

causing a logging while drilling tool to make logging while drilling measurements while drilling the well into the subterranean
reservoir;

generating a calibrated structure and/or a spatial distribution of resistivity parallel to the bedding and perpendicular to
the bedding along the trajectory of the well being drilled based upon the logging while drilling measurements made while drilling
the well; and

causing the processor to run a subsequent inversion of the surface electromagnetic survey using said calibrated structure
and/or spatial distribution of resistivity to obtain an improved inversion.

US Pat. No. 9,321,951

HYDROGEN BONDING MATERIAL FOR OILFIELD APPLICATION

SCHLUMBERGER TECHNOLOGY C...

1. A method comprising:
providing a supramolecular polymer fluid comprising units connected via reversible hydrogen bonds to form a supramolecular
polymer, wherein the supramolecular polymer has a molecular weight less than 1,000 Daltons;

introducing the supramolecular polymer fluid in a well; and
treating the well with the supramolecular polymer fluid.

US Pat. No. 9,140,116

ACOUSTIC TRIGGERING DEVICES FOR MULTIPLE FLUID SAMPLERS

Schlumberger Technology C...

1. A testing apparatus for collecting one or more downhole fluid samples from a wellbore, comprising:
a carrier;
a first sampler assembly supported by the carrier, the first sampler assembly comprising:
a first sampler device including one or more first ports, a first flow control device to control flow through the one or more
first ports;

a first actuator to control the first flow control device, wherein the first actuator includes an electronics module comprising
a housing defining a bore and a waterproof coating surrounding the housing;

a first modem having a first transceiver assembly converting messages into electrical signals, and first receiver electronics
to decode the electrical signals and provide first control signals to the first actuator responsive to the message being directed
to the first modem; and

a second sampler assembly supported by the carrier, the second sampler assembly comprising:
a second sampler device including one or more second ports, a second flow control device to control flow through the one or
more second ports;

a second actuator to control the second flow control device; and
a second modem having a second transceiver assembly converting messages into electrical signals, and second receiver electronics
to decode the electrical signals and provide second control signals to the second actuator responsive to the message being
directed to the second modem.

US Pat. No. 9,322,245

METAL ENCASED CABLE POWER DELIVERY SYSTEM FOR DOWNHOLE PUMPING OR HEATING SYSTEMS

Schlumberger Technology C...

1. An assembly comprising:
a housing that comprises an opening, a bore extending from the opening along an axis and a sealable port in fluid communication
with the bore and disposed at an axial distance from the opening;

a cable feed-through body that comprises a first axial end, a second axial end, a bore extending between the axial ends, a
tapered bore surface and a sealable port, the cable feed-through body being partially disposed within the bore of the housing
to locate the second axial end at an axial distance from the opening of the housing that exceeds the axial distance of the
sealable port of the housing to at least in part for a gland seal between the cable feed-through body and the bore of the
housing, the gland seal being testable by introduction of fluid via the sealable port of the housing; and

a cable, a compression nut and a ferrule wherein a portion of the cable and the ferrule are disposed in the bore of the cable
feed-through body and wherein the compression nut is attached to the cable feed-through body to apply a compressive force
between the ferrule and the tapered bore surface of the cable feed-through body to at least in part form a gland seal, the
gland seal being testable by introduction of fluid via the sealable port of the cable feed-through body.

US Pat. No. 9,297,229

HARD BOTTOM CEMENT SEAL FOR IMPROVED WELL CONTROL

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus, comprising:
a. a tubular subject to a first pressure value at a distal end and a second pressure value at a proximal region within the
tubular;

b. a shoe disposed within the distal end of the tubular, wherein the shoe comprises a ball valve;
c. a rotating ball valve disposed within the proximal region within the tubular; and,
d. a cement composition contained within a medial region of the tubular formed between the distal end and the proximal region.

US Pat. No. 9,312,557

FUEL CELL APPARATUS AND METHOD FOR DOWNHOLE POWER SYSTEMS

Schlumberger Technology C...

1. A drill string for excavating a wellbore, the drill string comprising:
a turbine configured to rotate due to impingement of drilling mud on one or more turbine blades;
a generator in operable communication with the turbine, wherein the generator is configured to generate electricity using
rotation of the one or more turbine blades; and

a fuel cell system configured to operate in a discharge stage and a charge stage, wherein the fuel cell comprises:
an oxygen supply;
a hydrogen supply;
a fuel cell stack that comprises:
a first electrode;
a second electrode;
a proton exchange membrane located between the first electrode and the second electrode; and
at least one water storage medium located between the proton exchange membrane and the second electrode;
wherein, during the discharge stage, the fuel cell system is configured to (i) generate electricity within the fuel cell stack
by producing an electrochemical reaction between hydrogen and oxygen provided from the oxygen supply and hydrogen supply and
(ii) retain water produced by the electrochemical reaction within the fuel cell stack by storing the water in the at least
one water storage medium;

wherein, during the charge stage, the fuel cell system is configured to generate hydrogen and oxygen within the fuel cell
stack by using the electricity generated by the generator to electrolyze the water stored in the at least one water storage
medium.

US Pat. No. 9,309,742

SYSTEM AND METHOD UTILIZING FRANGIBLE COMPONENTS

SCHLUMBERGER TECHNOLOGY C...

1. A device for use in a wellbore, comprising:
an anchoring tool comprising a plurality of slips, each slip having a base portion and a wall gripping portion, the base portion
being formed with a frangible structure which breaks down into smaller portions following a predetermined input in the wellbore,
wherein the base portion is formed of a first material and the gripping portion is formed of a second material, wherein further
the frangible structure comprises at least one notch designed to fracture the base portion when placed under a predetermined
load.

US Pat. No. 9,285,547

OILFIELD OPTICAL DATA TRANSMISSION ASSEMBLY JOINT

Schlumberger Technology C...

1. An oilfield optical data transmission assembly joint, the joint comprising:
a rotatable coupling for receiving an optical termination of a rotatable optical fiber, the fiber configured for carrying
the data, wherein a chamber is located on a side of the rotatable coupling offset from the central axis, wherein the chamber
is configured to receive a cable bundle that includes the rotatable optical fiber and electrical lines, and wherein an electrical
junction is located on the coupling and configured to receive the electrical lines; and

a stationary housing coupled to said rotatable coupling, said stationary housing having an optical termination of a stationary
optical fiber for interfacing the rotatable optical termination to allow communication therebetween.

US Pat. No. 9,284,477

COMPOSITIONS AND METHODS FOR MAINTAINING ZONAL ISOLATION IN A SUBTERRANEAN WELL

Schlumberger Technology C...

1. A well cementing composition, comprising:
(i) water;
(ii) inorganic cement particles; and
(iii) flexible particles having an average density higher than 1.5 g/cm3.

US Pat. No. 9,284,834

DOWNHOLE DATA TRANSMISSION SYSTEM

Schlumberger Technology C...

1. A system for transmitting data within a borehole, comprising:
a first communication node disposed at a first location within the borehole, the first communication node including a first
transmitter configured to transmit a first signal; and

a second communication node disposed at a second location within the borehole remote from the first location, the second communication
node including a first receiver, a second receiver, a second transmitter, and a communication link to communicatively couple
the second transmitter, the first receiver, and the second receiver at the second location, wherein each of the first receiver
and the second receiver are configured to receive the first signal transmitted from the first transmitter, and wherein the
second transmitter communicates information associated with the first receiver to the second receiver at the second location
via the communication link.

US Pat. No. 9,273,541

COMPLIANT DART-STYLE REVERSE-FLOW CHECK VALVE

SCHLUMBERGER TECHNOLOGY C...

1. An assembly comprising:
a tubular housing;
an inlet housing that is operatively coupled to the tubular housing;
a venturi housing that comprises an inlet housing end proximate the inlet housing, a check valve end, a longitudinal axis
that extends between the inlet housing end and the check valve end, a venturi passageway disposed between the inlet housing
end and the check valve end and a valve seat at the check valve end wherein the venturi housing is at least partially received
by the tubular housing and at least partially received by the inlet housing;

a first spring that axially biases the venturi housing with respect to the inlet housing and the tubular housing;
a dart;
a second spring that biases the dart in a direction toward the valve seat of the venturi housing;
a check valve housing that houses the dart and the second spring and that is operatively coupled to the tubular housing.

US Pat. No. 9,309,748

POWER GENERATION VIA DRILLSTRING PIPE RECIPROCATION

Schlumberger Technology C...

1. A method, comprising:
conveying a wireline configurable toolstring within a wellbore extending into a subterranean formation via a tubular string
to which the wireline configurable tool string is coupled in a manner permitting relative reciprocation of the wireline configurable
toolstring and the tubular string;

anchoring the wireline configurable toolstring within the wellbore;
reciprocating the tubular string relative to the wireline configurable toolstring within the wellbore while the wireline configurable
toolstring is anchored within the wellbore; and

powering at least one wireline configurable instrument with electrical energy produced by converting fluid flow resulting
from the tubular string reciprocation into the electrical energy, wherein the fluid flow comprises at least one of:

fluid flow into an internal chamber of the wireline configurable toolstring in response to the axial reciprocation of the
tubular string relative to the wireline configurable toolstring; or

fluid flow out of the internal chamber of the wireline configurable toolstring in response to the axial reciprocation of the
tubular string relative to the wireline configurable toolstring; and

the at least one of fluid flow into the internal chamber and fluid flow out of the internal chamber imparts rotary motion
to an impeller of the wireline configurable toolstring, and wherein the rotary motion of the impeller at least indirectly
imparts rotary motion to an input of an alternator of the wireline configurable toolstring.

US Pat. No. 9,279,306

PERFORMING MULTI-STAGE WELL OPERATIONS

SCHLUMBERGER TECHNOLOGY C...

10. A system usable with a well, comprising:
a plurality of first plugs deployed in a wellbore, each of the first plugs comprising a first material being reactive with
a first agent and not being reactive with a second agent;

a plurality of second plugs deployed in the wellbore, each of the second plugs comprising a second material being reactive
with the second agent and not being reactive with the first agent;

wherein the first and second plugs form fluid barriers for a plurality of isolated stages in the well, each of the first and
second plugs defining a lower boundary of an associated stage.

US Pat. No. 9,392,681

BOREHOLE POWER AMPLIFIER

Schlumberger Technology C...

1. A borehole tool for analyzing an earth formation, the borehole tool comprising:
an RF particle accelerator comprising a plurality of accelerator waveguides for accelerating electrons; and
one or more power amplification circuits comprising a wide bandgap semiconductor material, wherein the one or more power amplification
circuits amplify an initial input RF signal and provides a driving RF output signal to drive acceleration of the electrons
within the plurality of accelerator waveguides in a standing wave mode, wherein the one or more power amplification circuits
are configured to introduce the driving RF signal at different locations along the RF particle accelerator.

US Pat. No. 9,320,128

WELL-LOGGING APPARATUS WITH RING-SHAPED RESISTORS AND RELATED METHODS

SCHLUMBERGER TECHNOLOGY C...

1. A well-logging apparatus comprising:
a charged particle source;
a target electrode; and
an accelerator column comprising
a housing extending between said charged particle source and said target electrode,
a series of spaced apart accelerator electrodes carried by said housing,
a series of ring-shaped resistors surrounding said housing, and
a respective connector coupling adjacent ones of said series of ring-shaped resistors together and to a corresponding one
of said series of spaced apart accelerator electrodes;

wherein each connector comprises:
an electrically conductive ring coupling the adjacent ones of said series of ring-shaped resistors and defining a resistor
tap point; and

at least one electrically conductive link coupling the corresponding one of said accelerator electrodes to a corresponding
tap point; and

wherein the adjacent ones of said series of ring-shaped resistors have recessed edges defining a channel to receive a corresponding
one of said electrically conductive rings.

US Pat. No. 9,081,121

METHOD FOR A MUD CAKE THICKNESS DETERMINATION

Schlumberger Technology C...

1. A method for a mud cake thickness determination comprising:
sending short-time high-frequency signals into a formation by at least one transducer from at least two positions located
at different distances from the mud cake,

measuring amplitudes of the signals sent from the at least two positions and reflected from a drilling mud/mud cake interface
by the at least one transducer,

recording of arrival times of the reflected echo-signals by the at least one transducer,
determining a mud cake impedance Zmc as


wherein Zm—a drilling mud impedance, ? is determined as


dm—a distance between the transducer and the drilling mud/mud cake interface,

Kmmc—reduction of the amplitude of signal when a distance between the at least one transducer and the drilling mud/mud cake interface
is dm,

dm1, dm2—distances between the positions from which the signals are sent and the drilling mud/mud cake interface,

Am1—the amplitude of the signal sent from the position located at the distance dm1 from the drilling mud/mud cake interface and reflected from the interface,

Am2—the amplitude of the signal sent from the position located at the distance dm2 dm1 from the drilling mud/mud cake interface and reflected from the interface,

determining a sound speed in the mud cake as
Vmc=Zmc/?mc.

where ?mc—is a density of the mud cake, and

determining the mud cake thickness hmc as

hmc=Vmct/2,

where t is a time of the signal propagation in the mud cake.

US Pat. No. 9,410,408

ELECTRICAL HEATING OF OIL SHALE AND HEAVY OIL FORMATIONS

SCHLUMBERGER TECHNOLOGY C...

1. A method of enhancing production of hydrocarbons from a subterranean formation having a plurality of intervals, the method
comprising:
identifying first and second distinct target intervals that straddle a pay interval, wherein the target intervals each have
an electrical resistance less than an electrical resistance of the pay interval;

positioning a plurality of electrodes spaced apart from one another and each disposed adjacent to at least one of the target
intervals, wherein a first electrode of the plurality of electrodes is disposed adjacent the first distinct target interval
and a second electrode of the plurality of electrodes is disposed adjacent the second distinct target interval;

injecting electrical current into the target interval by supplying electrical signals to the electrodes, wherein the electrical
current passes through a portion of the target intervals to heat the pay intervals; and

producing hydrocarbons from the pay interval.

US Pat. No. 9,304,226

SCINTILLATOR-BASED NEUTRON DETECTOR FOR OILFIELD APPLICATIONS

SCHLUMBERGER TECHNOLOGY C...

1. A borehole logging tool comprising:
a neutron source;
a scintillator positioned to interact with scattered source neutrons received from a target formation, the scintillator configured
to emit luminescence in response to interaction with the scattered neutrons, wherein the scintillator comprises an aluminofluoride
host material doped with europium; and

a luminescence detector configured to provide an output signal indicative of detected luminescence of the scintillator.

US Pat. No. 9,290,689

USE OF ENCAPSULATED TRACERS

Schlumberger Technology C...

1. A process of making observations of a subterranean reservoir penetrated by a wellbore, in the course of hydraulic fracturing
of the subterranean reservoir, using tracer particles, comprising steps of
transporting a plurality of sets of tracer particles concurrently down a wellbore and delivering the sets of particles to
respective subterranean locations via the wellbore, the particles in each set comprising a tracer substance which distinguishes
that set from the other sets and which is encapsulated by a carrier;

at least two of the sets of particles differing in median particle size so as to be delivered to different subterranean locations;
causing or allowing the tracer substances to flow out from the tracer particles whilst the particles are at the respective
subterranean locations;

causing or allowing production of fluid out of said reservoir via the wellbore to the surface; and
detecting the presence or absence of the individual tracer substances in the fluid produced to the surface and distinguishing
the detected tracer substances from each other to identify the subterranean location from which each detected tracer has come.

US Pat. No. 9,541,670

IN-SITU DOWNHOLE X-RAY CORE ANALYSIS SYSTEM

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus, comprising:
a coring tool to obtain a core sample from a geological formation;
an X-ray generator to emit an X-ray beam substantially perpendicular to a longitudinal axis of the core sample;
an X-ray detector to detect the X-ray beam through the core sample to determine a characteristic of the core sample, wherein
the X-ray generator, the X-ray detector, or both are configured to be moved to different angular positions with respect to
the longitudinal axis, azimuthally, or laterally to generate an image of the core sample in three dimensions;

a piston to convey the core sample through a passageway within the coring tool; and
a calibration plug affixed to a face of the piston to move through the passageway between the X-ray generator and the X-ray
detector as the piston advances, wherein the calibration plug does not comprise core samples from the geological formation.

US Pat. No. 9,671,520

DIELECTRIC LOADED PARTICLE ACCELERATOR

Euclid Techlabs, LLC, Ga...

1. A device for accelerating charged particles, the device comprising:
a dielectric loaded accelerator for accelerating charged particles along a longitudinal axis of the accelerator and towards
an outlet of the accelerator, said accelerator comprising;

an elongated body made from a conductive material; and
a dielectric material extending continuously along a length of the accelerator and extending radially inward from an interior
surface of the elongated body to a central cavity surrounding said longitudinal axis;

said central cavity being uniform in diameter throughout its length; and
said dielectric material and elongated body being varied in outer diameter along said length of the accelerator such that
an electromagnetic mode of the accelerator has a phase velocity that (i) increases towards the outlet of the accelerator and
(ii) matches a velocity of the charged particles accelerated along the longitudinal axis.

US Pat. No. 9,291,046

DUAL OR TWIN-WELL COMPLETION WITH WETTABILITY ALTERATION FOR SEGREGATED OIL AND WATER PRODUCTION

Schlumberger Technology C...

1. A method, comprising:
completing a wellbore located in a formation by isolating a first portion of the wellbore or extension thereof from a second
portion of the wellbore or extension thereof, said second portion of the wellbore or extension thereof being located within
twenty meters of the first portion of the wellbore or extension thereof, and said first portion of said wellbore or extension
thereof being located at a hydrocarbon producing location of the formation;

chemically treating a first portion of the formation adjacent said first portion of the wellbore or extension thereof to make
said first portion of the formation hydrophobic, wherein the chemical treatment of the first portion extends a radial depth
of between one and ten meters into the formation;

chemically treating a second portion of the formation adjacent said second portion of the wellbore or extension thereof to
make said second portion of the formation hydrophilic, wherein the chemical treatment of the second portion extends a radial
depth of between one and ten meters into the formation;

simultaneously and separately producing hydrocarbons from said first portion of the wellbore or extension thereof and water
from said second portion of the wellbore or extension thereof; and

separately bringing said hydrocarbons to a surface of the formation.

US Pat. No. 9,435,194

APPARATUS AND METHOD OF USING AN INLINE ELECTRICAL CONDUCTIVITY MONITOR

M-I L.L.C., Houston, TX ...

6. A method, comprising:
measuring a first electrical conductivity of a treatment fluid with a first conductivity sensor, positioned proximate to a
surface of a wellsite, prior to the treatment fluid flowing through a well;

measuring a second electrical conductivity of the treatment fluid flowing through the tubing within the well with a second
conductivity sensor;

generating one or more signals indicative of the first and second electrical conductivity of the treatment fluid; and
transmitting the one or more signals to a computer.

US Pat. No. 9,309,743

DEVICE USED IN THE FORM OF A PACKER OR A TEMPORARY PLUG

SCHLUMBERGER TECHNOLOGY C...

1. A device functioning as a packer or temporary plug including a case, and transformable into a device preventing oil-well
fluid passage in which the device and a liquid-passage preventing substance is located, wherein the liquid-passage preventing
substance is a pack of fibres made of organic or natural polymers and/or glass fibre, wherein the case is expanded in-well
by a spring or hinged umbrella mechanism, wherein the case is made of materials at least low-soluble in the oil-well fluid,
and wherein the case self-destructs or decomposes in a well environment during a wellbore activity.

US Pat. No. 9,279,323

DRILLING WELLS IN COMPARTMENTALIZED RESERVOIRS

Schlumberger Technology C...

1. A method of drilling a well, comprising:
conveying a downhole apparatus within a well penetrating a subterranean formation;
determining, via one or more imaging modules of the downhole apparatus, a first value indicative of a relative position of
a boundary of a geological bed with respect to a drilling assembly disposed on the downhole apparatus;

initiating drawing formation fluid into the downhole apparatus in response to determining that the boundary has been crossed
by the downhole apparatus;

drawing the formation fluid into the downhole apparatus via a fluid sampling module of the downhole apparatus;
analyzing the formation fluid within the downhole apparatus to determine a second value indicative of an optical property
of the formation fluid; and

adjusting a well trajectory based on the first value and the second value.

US Pat. No. 9,213,122

SINGLE WELL ANISOTROPY INVERSION USING VELOCITY MEASUREMENTS

Schlumberger Technology C...

1. A computer implemented method for determining an elastic parameter of a region of interest in a formation traversed by
a wellbore, comprising:
inputting into the computer actual group velocity measurements and actual directions acquired from running a sonic measurement
tool within the region of interest;

constructing a computer model of the elastic parameter of the region of interest;
computing predicted group velocity measurements and predicted directions based on the computer model;
constructing a look up table containing the predicted group velocity measurements and the predicted directions;
selecting a look up table predicted group velocity measurement for comparison to one of the actual group velocity measurements
based on proximity between a corresponding look up table predicted direction and corresponding one of the actual directions;
and

refining the computer model based on the look up table predicted group velocity measurement and the one of the actual group
velocity measurements such that an objective function is minimized, without relying on any other actual velocity measurements
acquired from another wellbore.

US Pat. No. 9,482,081

METHOD FOR PREHEATING AN OIL-SATURATED FORMATION

SCHLUMBERGER TECHNOLOGY C...

1. A method for preheating an oil reservoir, the method comprising:
injecting a saturated or a superheated steam at an initial injection pressure during an initial preheating stage of a steam
assisted gravity drainage (SAGD) process, wherein the steam is injected into a tubing disposed within a well traversing the
oil reservoir,

measuring temperature at an outlet of the tubing during the initial preheating stage of the steam assisted gravity drainage
process, the temperature is measured by at least one temperature sensor installed at the outlet of the tubing,

calculating a heat flow from the well to the oil reservoir using the temperature measured at the outlet of the tubing during
the preheating initial stage of the steam assisted gravity drainage process and reservoir thermal properties,

calculating an optimal steam injection rate corresponding to a moment when steam quality of the injected steam at the tubing
outlet becomes greater than zero, wherein the optimal steam infection rate W(t) is calculated according to:

where Q(t) is the calculated heat flow from the well to the oil reservoir, L is a specific heat of steam condensation, ?X=X0?X1, X0 is steam quality at an inlet of the tubing, and X1 is steam quality at the outlet of the tubing, and
decreasing a steam injection rate to the calculated optimal steam injection rate value by decreasing the initial injection
pressure to a value providing the calculated optimal steam injection rate value and constant temperature at the outlet of
the tubing.

US Pat. No. 9,303,509

SINGLE PUMP FOCUSED SAMPLING

Schlumberger Technology C...

1. An apparatus, comprising:
first and second intakes configured to receive formation fluid from a subterranean formation penetrated by a borehole;
a pump configured to:
draw formation fluid into the first and second intakes; and
discharge into the borehole at least a portion of the formation fluid drawn into the second intake;
a sample chamber in selective fluid communication with the first intake; and
a pilot relief valve coupled to the pump and the sample chamber via a second flow line, wherein the pilot relief valve comprises
a bypass mechanism actuated by a motor.

US Pat. No. 9,062,242

CROSS-LINKERS FOR HYDRAULIC FRACTURING FLUID

Schlumberger Technology C...

1. A method of treatment of a wellbore or a subterranean formation penetrated by a wellbore, the method comprising:
introducing a wellbore composition to the wellbore or the subterranean formation, the wellbore composition comprised of at
least a hydratable polymer and a crosslinker,

wherein the crosslinker is comprised of at least borosilicate, the crosslinker having a dimension of from about 5 nm to about
100 nm.

US Pat. No. 9,404,361

MULTIPHASE FLOW IN A WELLBORE AND CONNECTED HYDRAULIC FRACTURE

Schlumberger Technology C...

1. A method comprising:
providing a reservoir model of a reservoir wherein the reservoir model comprises a three-dimensional grid that defines grid
cells in a reservoir model space;

providing a well model of a well and a hydraulic fracture that intersects the well wherein the well model comprises segments
within the reservoir model space that comprise fracture connections to a number of the grid cells of the reservoir model without
a demand for finer grid cells of the reservoir model and wherein the well model comprises an associated system of equations
that accounts for multiphase flow between the hydraulic fracture and the well and between the reservoir and the hydraulic
fracture based at least in part on pressures of the reservoir model; and

solving, using a computing device, at least the system of equations for the well model to generate a solution.

US Pat. No. 9,187,981

WIRELINE TOOL CONFIGURATIONS HAVING IMPROVED RETRIEVABILITY

Schlumberger Technology C...

1. A downhole wireline tool comprising:
a rigid tool body;
a first standoff ring deployed about the tool body and engaging a first set of helical grooves in an outer surface of the
tool body such that relative axial motion of the tool body in a first direction with respect to the first standoff ring causes
the first standoff ring to rotate about the tool body in a clockwise direction; and

a second standoff ring deployed about the tool body and engaging a second set of helical grooves in the outer surface of the
tool body such that relative axial motion of the tool body in the first direction with respect to the second standoff ring
causes the second standoff ring to rotate about the tool body in a counterclockwise direction.

US Pat. No. 9,140,107

DOWNHOLE POLYMER FOAM APPLICATIONS

Schlumberger Technology C...

1. A method of treating a subterranean formation penetrated by a wellbore, the method comprising:
contacting an energized fluid with the subterranean formation; and
reducing a partial pressure of the energized fluid by an amount sufficient to form polymeric foam structure within the subterranean
formation.

US Pat. No. 9,057,793

FLUID ANALYZER WITH MIRROR AND METHOD OF USING SAME

Schlumberger Technology C...

1. A fluid analyzer of a downhole tool positionable in a wellbore penetrating a subterranean formation, the wellbore having
a downhole fluid thereabout, the downhole tool having a housing with a flowline therethrough for receiving the downhole fluid,
the fluid analyzer comprising:
at least one optical source to pass a light through an optical window and through the downhole fluid in the flowline;
at least one photodetector to measure the light passed through the downhole fluid in the flowline, an optical path of the
light extending from the at least one optical source to the at least one photodetector, an optical path length defined as
a length of a portion of the optical path within the flowline; and

at least one optical mirror positionable about the flowline, the at least one optical mirror having an optical layer selectively
passing the light from the at least one optical mirror to the at least one photodetector whereby the optical path length may
be varied.

US Pat. No. 9,377,556

SYSTEMS AND METHODS FOR ELECTROMAGNETIC DETECTION OF A FORMATION ANOMALY FROM A NEAR BIT LOCATION WHILE DRILLING

SCHLUMBERGER TECHNOLOGY C...

1. A while-drilling method, comprising:
a) providing an electromagnetic (EM) field source at an Earth surface location;
b) providing a near-bit electromagnetic (EM) field receiver on a drill string in a borehole at a location proximate a drill
bit;

c) generating an electromagnetic (EM) field at the source;
d) during drilling of the borehole, measuring a plurality of components of the EM field at the near-bit receiver;
e) during drilling of the borehole, analyzing in real-time the measured components of the EM field as representative of a
distance between the drill bit and a formation anomaly located ahead of the drill bit, the formation anomaly comprising a
salt entrance; and

f) adjusting at least one drilling parameter based on the measured components of the EM field prior to the drill bit reaching
the formation anomaly.

US Pat. No. 9,303,508

IN-SITU STRESS MEASUREMENTS IN HYDROCARBON BEARING SHALES

SCHLUMBERGER TECHNOLOGY C...

1. A method comprising:
lowering a downhole tool into a wellbore penetrating a subterranean shale formation;
logging via the downhole tool, a longitudinal portion of the wellbore adjacent the shale formation to generate logging results;
processing the logging results to select test intervals along the longitudinal portion of the wellbore having a relatively
low stress level, a relatively low breakdown pressure, or a relatively high horizontal stress anisotropy including determining
a test interval sequence to increase a life of the downhole tool, wherein determining the test interval sequence to increase
the life of the downhole tool comprises ordering the selected test intervals so that a first one of the selected test intervals
associated with a first differential pressure having a lower-stress test intervals across the downhole tool is tested prior
to a second one of the selected test intervals associated with a second differential pressure having a higher-stress test
intervals across the downhole tool greater than the first differential pressure;

performing a stress test at one or more of the selected test intervals to generate stress test results for the shale formation,
wherein performing the stress test comprises determining a closure stress of the shale formation; and

adjusting a model representing at least one property of the shale formation based on the stress test results.

US Pat. No. 9,266,754

SULFATE MOLECULE REMOVAL THROUGH INORGANIC OR DIVALENT ION NUCLEI SEEDING

Schlumberger Technology C...

1. A method for treating water, comprising:
contacting, with mixing, a liquid stream of water containing sulfate with a source comprising inorganic and/or divalent ions;
separating the stream into an effluent and a fluid comprising less sulfate than the stream; and
evaluating a concentration of sulfate in the fluid comprising less sulfate and, if the concentration of sulfate in the fluid
comprising less sulfate needs to be reduced, returning the fluid comprising less sulfate to again contact the source comprising
inorganic and/or divalent ions,

wherein the effluent comprises more sulfate and more inorganic and/or divalent ions than the stream, and
wherein the contacting and separating are performed in equipment with surfaces that comprise an anti-adhesion coating that
prevents formation of sulfate on a surface of the equipment.

US Pat. No. 9,222,308

DETECTING STICK-SLIP USING A GYRO WHILE DRILLING

Schlumberger Technology C...

1. A method for drilling operation in a subterranean formation, comprising:
calculating, by a hardware processor and in response to determining that an magnitude of gyro data representing rotations
of a drill bit in a bottom hole assembly (BHA) and a time derivative of the gyro data are within a pre-determined range, a
drift parameter of the gyro data;

analyzing, by the hardware processor, the gyro data based on the drift parameter to generate a stick-slip alert; and
presenting the stick-slip alert.

US Pat. No. 9,109,411

PRESSURE PULSE DRIVEN FRICTION REDUCTION

Schlumberger Technology C...

1. A method for reducing friction between a coiled tubing and a wellbore comprising:
generating a pressure wave at an inlet of the coiled tubing at an oilfield surface with surface equipment attached to the
coiled tubing;

introducing the pressure wave to the coiled tubing positioned in the wellbore, wherein said introducing comprises applying
the pressure wave to an annulus of the wellbore; and

propagating the pressure wave within the coiled tubing, wherein the pressure wave reduces a friction force between the coiled
tubing and the wellbore.

US Pat. No. 9,359,544

COMPOSITION AND METHOD FOR TREATING SUBTERRANEAN FORMATION

Schlumberger Technology C...

1. A composition for treatment of a subterranean formation, the composition comprising an emulsified acid system and a sulfobetaine
surfactant comprising a cationic surfactant comprising an ammonium chloride derivative and a linear alkylbenzenesulfonate.

US Pat. No. 9,359,883

ZONAL COMPOSITIONAL PRODUCTION RATES IN COMMINGLED GAS WELLS

Schlumberger Technology C...

1. A method, comprising:
conveying a tool within a tubing comprising a zonal fluid flow;
operating the tool to measure a flow rate of fluid flow at each of a plurality of depths, wherein each of the plurality of
depths is associated with a corresponding zone in the zonal fluid flow;

determining a flow rate of the zonal fluid flow from each of the zones based on the flow rates of the fluid flow measured
at each of the zone-associated depths;

operating the tool to measure proportions of compositional components of the fluid flow at each of the zone-associated depths;
determining a flow rate of each compositional component of the zonal fluid flow from each of the zones based on:
the determined flow rate of the zonal fluid flow from each of the zones; and
the proportions of compositional components of the fluid flow measured at each of the zone-associated depths;
operating the tool to measure pressure and temperature of the fluid flow at each of the zone-associated depths; and
determining a compression factor of the fluid flow at each of the zone-associated depths based on the pressure and temperature
of the fluid flow measured at each of the zone-associated depths;

wherein determining the flow rate of each compositional component of the zonal fluid flow from each of the zones is further
based on:

the pressure and temperature of the fluid flow measured at each of the zone-associated depths; and
the determined compression factor of the fluid at each of the zone-associated depths.

US Pat. No. 9,303,474

COMPOSITION FOR BOREHOLE TREATMENT

SCHLUMBERGER TECHNOLOGY C...

1. A composition for treating a formation surrounding a borehole, comprising:
a well treatment fluid including fibres, the fibres being present at a concentration between 1.4 g/L and 23 g/L;
at least one hot melt adhesive component;
and at least one solid particulate component;
wherein the hot melt adhesive is suitable to soften when the temperature in the region of the borehole is raised above the
transition temperature of said adhesive component, and wherein particles of the hot melt adhesive component are grafted onto
at least some of the fibres.

US Pat. No. 9,206,678

ZONAL CONTACT WITH CEMENTING AND FRACTURE TREATMENT IN ONE TRIP

Schlumberger Technology C...

1. A method for fracturing multiple zones in a wellbore, comprising:
running a work string into a liner that is positioned in the wellbore, wherein a first annulus is formed between the liner
and a wall of the wellbore;

pumping cement through the work string into the first annulus;
opening one or more first contact valves in the liner with the work string, wherein the one or more first contact valves are
disposed proximate a first zone of the wellbore;

flowing a fluid through the work string and the one or more first contact valves to fracture the first zone;
opening one or more second contact valves in the liner with the work string, wherein the one or more second contact valves
are disposed proximate a second zone of the wellbore; and

flowing the fluid through the work string and the one or more second contact valves to fracture the second zone,
wherein, in a single trip of the work string in the wellbore:
the cement is pumped into the first annulus,
the first zone is fractured, and
the second zone is fractured.

US Pat. No. 9,083,027

POINT CONTACT THERMAL ISOLATION

Schlumberger Technology C...

1. A battery assembly comprising:
a housing that encases a battery,
at least one thermal insulator disposed between the housing and the battery, the material that forms the thermal insulator
comprising zirconium dioxide, and the zirconium dioxide comprising an yttrium-stabilized zirconium dioxide ceramic topcoat
to chemically stabilize the zirconium dioxide at high temperatures; and

a thermal pathway is formed through a point contact in the at least one insulator between the housing and the battery cell.

US Pat. No. 9,057,794

METHOD FOR MEASURING SUBTERRANEAN FORMATION DENSITY USING A NEUTRON GENERATOR

Schlumberger Technology C...

1. A method for measuring a formation density of a subterranean formation, the method comprising:
(a) generating neutrons in a subterranean borehole using an accelerator based neutron generator, said generated neutrons being
emitted into a surrounding borehole environment;

(b) detecting secondary gamma rays in the subterranean borehole, the secondary gamma rays being generated by an interaction
between the neutrons generated in (a) and the surrounding borehole environment, and detecting neutrons in the subterranean
borehole, the neutrons returning after being emitted into the surrounding borehole environment and the neutrons representing
an azimuthally average neutron count;

(c) causing a processor to identify certain ones of the secondary gamma rays detected in (b) based upon predetermined selection
criteria identifying the secondary gamma rays as resulting from a neutron interacting with an azimuthally specific part of
the formation less than a 360 degree azimuthal angle around the formation; and

(d) causing a processor to process the gamma rays identified in (c) and the neutrons generated in (b) to compute a formation
density of the subterranean formation.

US Pat. No. 9,435,157

BOTTOM HOLE ASSEMBLY INCLUDING BI-STABLE VALVES

SCHLUMBERGER TECHNOLOGY C...

1. A down hole tool control system, comprising:
a plurality of bi-stable valves, each of the valves comprising:
a first chamber having a first aperture and a second aperture;
a second chamber having a first aperture and a second aperture;
a shaft having a first valve member adjacent a first end of the shaft and a second valve member adjacent an opposite second
end of the shaft, the shaft movable between a first position, in which the first valve member closes off the second aperture
of the first chamber and the second valve member closes off the second aperture of the second chamber to prevent fluid from
passing through the second apertures of the first and second chambers, and a second position, in which the first valve member
and the second valve member allow fluid to pass through the second aperture of the first chamber and the second aperture of
the second chamber;

a third chamber having a first aperture and a second aperture, the first aperture in fluid communication with the second aperture
of the first chamber;

a fourth chamber having a first aperture, a second aperture and a third aperture, the first aperture of the fourth chamber
in fluid communication with the second aperture of the second chamber,

wherein in the second position, the first chamber, the second chamber, the third chamber and the fourth chamber are fluidly
coupled; and

a common inlet conduit in fluid communication with the first aperture of the first chamber and the first aperture of the second
chamber of the plurality of bi-stable valves.

US Pat. No. 9,362,078

ION SOURCE USING FIELD EMITTER ARRAY CATHODE AND ELECTROMAGNETIC CONFINEMENT

SCHLUMBERGER TECHNOLOGY C...

1. An ion source for use in a radiation generator tube comprising:
a back passive cathode electrode;
a passive anode electrode downstream of the back passive cathode electrode;
a magnet adjacent the anode;
a front passive cathode electrode downstream of the passive anode electrode, the front passive cathode electrode and the back
passive cathode electrode defining an ionization region therebetween;

at least one field emitter array (FEA) cathode, spaced apart from the back passive cathode electrode, the passive anode electrode,
and the front passive cathode electrode, and configured to electrostatically discharge due to an electric field in the ion
source;

the back passive cathode electrode and the passive anode electrode, and the front passive cathode electrode and the passive
anode electrode, having respective voltage differences therebetween, and the magnet generating a magnetic field, such that
a Penning-type trap is produced to confine electrons from the electrostatic discharge to the ionization region;

at least some of the electrons in the ionization region interacting with an ionizable gas to create ions.

US Pat. No. 9,347,266

STATOR INSERTS, METHODS OF FABRICATING THE SAME, AND DOWNHOLE MOTORS INCORPORATING THE SAME

Schlumberger Technology C...

1. A method for fabricating a stator insert for a downhole motor, the method comprising:
providing a mandrel having an outer geometry that is complementary to a desired inner geometry for the stator;
applying a flexible sleeve over the mandrel;
placing the flexible sleeve and the mandrel in a mold;
introducing a reinforcing material into the mold to fill space between the flexible sleeve and the mold;
solidifying the reinforcing material to bond the reinforcing material and the flexible sleeve; and
removing the solidified reinforcing material and flexible sleeve from the mold;
thereby fabricating a stator insert.

US Pat. No. 9,316,083

ADJUSTABLE TESTING TOOL AND METHOD OF USE

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus, comprising:
a downhole tool comprising:
two inflatable packer elements spaced longitudinally apart relative to a longitudinal axis of the downhole tool; and
a first port operable to admit fluid into the downhole tool and disposed at a first longitudinal position between the two
inflatable packer elements; and

a snorkel assembly extending circumferentially around the downhole tool and comprising:
an annular groove fluidly connected to the first port;
a second port operable to admit fluid into the snorkel assembly and disposed at a second longitudinal position between the
two inflatable packer elements, wherein the first and second longitudinal positions are spaced longitudinally apart relative
to the longitudinal axis of the downhole tool, and wherein the annular groove and the second port are in fluid communication.

US Pat. No. 9,260,942

METHOD AND APPARATUS FOR OFF-RIG PROCESSING RIG SENSOR DATA

SCHLUMBERGER TECHNOLOGY C...

1. A method for monitoring a rig site system, comprising:
obtaining sensor data at a rig site;
compressing the sensor data to produce pre-processed sensor data having a reduced bandwidth for transmission;
transmitting the pre-processed sensor data pertaining to the sensor data from the rig site over a primary network link or
a backup network link to a monitoring site, wherein the primary network link automatically switches to the backup network
link when the primary network link is unavailable, and the backup network link automatically switches back to the primary
network link when the primary network link becomes available;

demodulating the pre-processed sensor data at the monitoring site to produce demodulated data;
demodulating the pre-processed sensor data at the rig site substantially simultaneously with respect to demodulating the pre-processed
sensor data at the monitoring site to produce redundantly demodulated pre-processed sensor data at the rig site;

generating a rig site display at a first user interface at the rig site, the rig site display comprising; the redundantly
demodulated pre-processed sensor data, wherein the first user interface is configured to receive one or more commands from
a user that adjusts a rig site parameter based on the user's command;

generating a monitor site display at a second user interface at the monitoring site, the monitor site, display comprising
demodulated pre-processed sensor data displayed at substantially the same time the redundantly demodulated pre-processed sensor
data is displayed on the first user interface, wherein the second user interface is configured to receive one or more off-rig
commands from an off-rig user that adjusts a rig site parameter based on the user's off-rig command; and

analyzing the demodulated data at the monitoring site.

US Pat. No. 9,238,963

SYSTEMS AND METHODS FOR DETECTING PHASES IN MULTIPHASE BOREHOLE FLUIDS

Schlumberger Technology C...

1. A method, comprising:
deploying a bottom hole assembly in a borehole on coiled tubing, the bottom hole assembly comprising a sensor, an imaging
electrode and a drill bit;

drilling the borehole with the coiled tubing deployed bottom hole assembly;
circulating a drilling fluid down the coil tubing and out through the drill bit and back to the surface via an annulus between
the borehole and the coil tubing;

acquiring with the sensor a first property measurement associated with a first radial portion of the borehole at a particular
axial point;

acquiring with the sensor a second property measurement associated with a second radial portion of the borehole at the particular
axial point;

determining based on the first and the second property measurements that the borehole comprises at the particular axial point
a gas phase separated from a liquid phase;

replacing, in response to the determining, the drilling fluid with a viscous conductive pill and circulating the viscous conductive
pill down the coil tubing and to the surface via the annulus to displace the gas phase from the particular axial point; and

acquiring with the imaging electrode an imaging measurement at the particular axial point as the viscous conductive pill moves
to a position directly in front of the imaging electrode.

US Pat. No. 9,176,251

ASPHALTENE EVALUATION BASED ON NMR MEASUREMENTS AND TEMPERATURE / PRESSURE CYCLING

Schlumberger Technology C...

1. A method of asphaltene evaluation of a hydrocarbon-bearing rock sample from a subterranean rock formation comprising:
making a first NMR measurement representative of the hydrocarbon-bearing rock sample at temperature and pressure conditions
prior to asphaltene precipitation onset;

lowering temperature and/or pressure of the hydrocarbon-bearing rock sample below an expected asphaltene precipitation onset
condition;

subsequently raising the temperature and/or pressure conditions above the expected asphaltene precipitation onset condition;
making a second NMR measurement on the hydrocarbon-bearing rock while at conditions above the expected asphaltene precipitation
onset condition; and

evaluating asphaltene content of oil in the hydrocarbon-bearing rock sample based at least in part on a comparison of the
first and second NMR measurements.

US Pat. No. 9,145,768

METHOD FOR REDUCING STICK-SLIP DURING WELLBORE DRILLING

Schlumberger Technology C...

1. A method for drilling a wellbore, comprising:
operating at least one motor coupled within a drill string to turn a drill bit at an end thereof;
operating an automatic drill string rotation controller to cause rotation of the drill string in a first direction until a
measured parameter related to torque on the drill string reaches a first selected value;

operating the automatic drill string rotation controller to cause rotation of the drill string in a second direction until
the measured parameter related to torque is reduced to a second selected value, wherein the second selected value is in a
same rotational direction as the first selected value; and

axially advancing the drill string to cause the drill bit to extend the wellbore.

US Pat. No. 9,382,764

CONTRACTION JOINT SYSTEM

SCHLUMBERGER TECHNOLOGY C...

1. A system for use in a well, comprising:
a conveyance;
a downhole tool; and
a contraction joint disposed between the downhole tool and the conveyance, the contraction joint comprising:
an outer housing;
a mandrel slidably received in the outer housing; and
a resettable locking member which selectively releases the mandrel with respect to the outer housing to contract the contraction
joint under sufficient axial loading, the resettable locking member relocking the mandrel with respect to the housing upon
sufficient expansion of the contraction joint, wherein the resettable locking member comprises a ball trapped in a recess
formed in the mandrel to lock the mandrel and the outer housing in an expanded position, the ball being forced out of the
recess when the contraction joint is under the sufficient axial loading, wherein the ball is held in the recess by a spring
member.

US Pat. No. 9,356,487

ROTOR BEARING ASSEMBLY

Schlumberger Technology C...

1. A bearing assembly for use with a shaft of a pump, comprising:
a carbide sleeve having an internal surface forming a bore that defines an axis and having a curved, contoured notch disposed
in a first end of the carbide sleeve; and

a metal sleeve disposed at least partially within the bore of the carbide sleeve, the metal sleeve having a protrusion with
a curved, contoured surface for engagement with the curved, contoured notch of the carbide sleeve wherein, in an engaged state
of the curved, contoured notch and the curved, contoured surface, rotation of the carbide sleeve and the metal sleeve relative
to one another generates an axial contact force.

US Pat. No. 9,273,537

SYSTEM AND METHOD FOR SAND AND INFLOW CONTROL

Schlumberger Technology C...

19. A sand control system, comprising:
a base pipe with an opening formed radially therethrough;
an inflow control device proximate the opening in the base pipe to control flow of fluid into an interior of the base pipe;
a drainage tube mounted along an exterior of the base pipe, the drainage tube comprising a mesh material disposed along a
length of the drainage tube such that the drainage tube is permeable to a fluid, and the drainage tube having a tube end coupled
to the base pipe to deliver the fluid from an interior of the drainage tube, through the inflow control device, and into the
interior of the base pipe; and

a protective shroud positioned around the base pipe, wherein the drainage tube is positioned between the base pipe and the
protective shroud.

US Pat. No. 9,260,943

TOOL HEALTH EVALUATION SYSTEM AND METHODOLOGY

Schlumberger Technology C...

1. A method for evaluating a well tool, comprising:
operating a tool in a drilling operation in a downhole environment;
accumulating tool data on the tool via a sensor located on the tool;
accumulating corresponding data via an additional sensor located downhole;
obtaining additional data related to the tool from a remote location and transmitting the additional data to a surface processor
system;

transmitting the tool data and the corresponding data uphole to the surface processor system prior to pulling the tool out
of hole, wherein the data is transmitted after completing drilling;

processing the tool data, the corresponding data, and the additional data in real time on the surface processor system as
the tool data and the corresponding data is transmitted uphole;

pulling the drilling tool out of the hole after transmitting tool data up hole; and
diagnosing whether the tool has sufficient health for use in a subsequent operation, the diagnosis being completed prior to
the tool reaching the surface location when pulled out of hole after drilling is complete and based on processing the transmitted
data.

US Pat. No. 9,206,684

ARTIFICIAL LIFT EQUIPMENT POWER LINE COMMUNICATION

Schlumberger Technology C...

1. A system comprising:
an electric submersible pump that comprises an electric motor having a wye point;
a power cable that comprises three conductors, each of the three conductors electrically connected to the electric motor;
a telemetry driver powered by DC power that comprises at least one electrical connection to the power cable;
a sensor;
a transformer that comprises two opposing windings wherein one of the windings passes DC power from the wye point to power
the telemetry driver and the other one of the windings provides stepped down AC power from the wye point for conversion to
DC power to power the telemetry driver; and

circuitry responsive to detection of a ground fault to selectively convert the stepped down AC power to DC power to power
the telemetry driver.

US Pat. No. 9,187,983

DOWNHOLE ELECTRICAL ENERGY CONVERSION AND GENERATION

Schlumberger Technology C...

1. A system for converting electrochemical energy to electrical energy downhole comprising:
an acidic fluid delivered downhole as part of a downhole wellbore treatment;
a first electrode;
a second electrode, the first and second electrodes being adapted and arranged to be deployed downhole and to form an anode
and a cathode respectively upon exposure to the acidic fluid in a downhole environment, thereby generating electrical energy;

a downhole device adapted and arranged to be energized by the generated electrical energy while in the downhole environment;
and

wherein the downhole device is arranged such that it is located between the first and second electrodes and is untethered
with the surface such that electrical power from the surface is unavailable to the downhole device.

US Pat. No. 9,181,784

METHOD AND APPARATUS FOR LOGGING A WELL BELOW A SUBMERSIBLE PUMP DEPLOYED ON COILED TUBING

Schlumberger Technology C...

1. A method for treating a well comprising the steps of:
lowering a logging tool on a cable into the well, the logging tool fitted with a plurality of sensors capable of characterizing
well effluents;

characterizing well effluents by utilizing the sensors on the logging tool;
subsequently lowering an artificial lift mechanism on coiled tubing disposed external to the cable of the logging tool, wherein
the cable of the logging tool is unenclosed by the coiled tubing, wherein the coiled tubing is capable of flowing well effluent
past said logging tool, wherein lowering the logging tool and lowering the artificial lift mechanism occurs independent of
the other, wherein the artificial lift mechanism and the coiled tubing are not affixed to the well while flowing well effluent
past the logging tool;

obtaining information from characterizing the well effluents;
selecting a treatment based on the obtained information;
injecting a treatment into a desired formation utilizing the artificial lift mechanism; and
further characterizing well effluents using the logging tool and the artificial lift mechanism.

US Pat. No. 9,074,465

METHODS FOR ALLOCATING COMMINGLED OIL PRODUCTION

Schlumberger Technology C...

1. A method for real-time wellsite production allocation analysis comprising:
obtaining, in-situ, an individual spectral analysis for each of a plurality of end member oils, each from a separate production
zone via a plurality of spectroscopic measurements, wherein the plurality of spectroscopic measurements comprise at least
two of electromagnetic absorption spectroscopic measurements, X-ray fluorescence spectroscopy measurements, electromagnetic
scattering spectroscopic measurements, Raman spectroscopy measurements, NMR spectroscopy measurements, or terahertz time-domain
spectroscopy measurements;

obtaining, in-situ, a commingled spectral analysis for a produced fluid that includes the plurality of end member oils in
a commingled state via the plurality of in-situ spectroscopic measurements;

assuming a linear relationship between the individual spectral analyses and the commingled spectral analysis;
determining, in real time with a processing system, a fractional amount of each of the plurality of end member oils in the
produced fluid, wherein the fractional amount is determined directly from the individual spectral analysis for each of the
end member oils and the linear relationship; and

wherein the processing system is programmed to determine which of the plurality of spectroscopic measurements to use in the
determination of the fractional amount of each of the plurality of end member oils in the produced fluid.

US Pat. No. 9,429,014

FORMATION FLUID SAMPLE CONTAINER APPARATUS

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus, comprising:
a downhole tool having a body including an opening and a cavity extending into the body from the opening; and
a sample container comprising: an elongated container for holding a formation fluid sample; and
a sheath abutting an outer longitudinal surface of the elongated container and at least partially surrounding the elongated
container, wherein the sample container is fixed in the cavity;

wherein the sample container is fixed in the cavity via a pin extending across the opening and perpendicularly to the longitudinal
surface of the elongated container through the sheath and into the body of the downhole tool.

US Pat. No. 9,389,334

RADIATION GENERATOR HAVING AN ACTIVELY EVACUATED ACCELERATION COLUMN

SCHLUMBERGER TECHNOLOGY C...

1. A radiation generator comprising:
an ion source region;
an acceleration column in fluid communication with the ion source region;
the ion source region and the acceleration column containing an ionizable gas; and
a vacuum pump to pump the ionizable gas from the acceleration column to the ion source region such that a gas pressure in
the acceleration column is less than a gas pressure in the ion source region, wherein the vacuum pump is contained within
a cooling structure.

US Pat. No. 9,366,089

CUTTING ELEMENT ATTACHED TO DOWNHOLE FIXED BLADED BIT AT A POSITIVE RAKE ANGLE

SCHLUMBERGER TECHNOLOGY C...

1. A downhole cutting tool for drilling a wellbore, comprising:
a tool body;
a plurality of blades extending from the tool body, at least one of the plurality of blades extending from adjacent a center
of the face of the tool body to a gauge portion;

an attachment end opposite the plurality of blades, the attachment end being coaxial with the tool body; and
a plurality of cutting elements disposed on the plurality of blades, a first cutting element on a first blade, the first cutting
element comprising a polycrystalline diamond material disposed on a carbide substrate, the polycrystalline diamond material
extending away from the carbide substrate to terminate in a substantially pointed geometry opposite the substrate, the first
cutting element having a central axis extending therethrough, the first cutting element being oriented to form a positive
rake angle ranging from 15 to 20 degrees between the central axis and a vertical line perpendicular to a surface to be engaged
by the first cutting element.

US Pat. No. 9,334,438

POLYMER DELIVERY IN WELL TREATMENT APPLICATIONS

Schlumberger Technology C...

1. A method of preparing a well treatment fluid, the method comprising:
a. mixing a rheological polymer, a partitioning agent and a first aqueous medium comprising water to form a heterogeneous
mixture comprising:

an aqueous partitioning agent-rich phase comprising water and at least a portion of the partitioning agent, wherein the partitioning
agent-rich phase is continuous, and

an aqueous rheological polymer-rich phase finely dispersed in the partitioning agent-rich phase, wherein the aqueous rheological
polymer-rich phase comprises water and at least a portion of the rheological polymer;

wherein the heterogeneous mixture is a liquid-liquid mixture, and
b. diluting the heterogeneous mixture with a second aqueous medium miscible with the first aqueous medium to mutually dissolve
the polymer-rich phase and the partitioning-agent rich phase and form the well treatment fluid comprising a continuous mixed
polymer-agent phase.

US Pat. No. 9,334,729

DETERMINING FLUID COMPOSITION DOWNHOLE FROM OPTICAL SPECTRA

SCHLUMBERGER TECHNOLOGY C...

1. A method, comprising:
obtaining in-situ optical spectral data associated with a formation fluid flowing through a downhole formation fluid sampling
apparatus;

predicting a parameter of the formation fluid flowing through the downhole formation fluid sampling apparatus using a processing
system based on projection of the obtained spectral data onto a matrix in the processing system that corresponds to a predominant
fluid type of the formation fluid; and

adjusting an operating parameter of the downhole formation fluid sampling apparatus based on the predicted parameter.

US Pat. No. 9,309,722

OIL OPERATED ROTARY STEERABLE SYSTEM

Schlumberger Technology C...

1. A system for drilling a borehole, comprising:
a drill bit;
a rotary steerable drilling system to which the drill bit is coupled in a bottom hole assembly, the rotary steerable drilling
system being configured to receive a flowing drilling mud and comprising a mechanism for rotating the drill bit to drill the
borehole, the rotary steerable drilling system also having a piston actuated mechanism which rotates with the rotary steerable
drilling system and which selectively controls at least one of the directional bias or the axial orientation of the drill
bit;

a turbine powered independently of the mechanism for rotating the drill bit, the turbine being powered by the flowing drilling
mud; and

a pressurized oil system connected to the piston actuated mechanism, the pressurized oil system providing pressurized oil
to pistons in the piston actuated mechanism, wherein the pressurized oil system comprises an oil pump driven by a shaft which,
in turn, is driven by the turbine powered via the flowing drilling mud, the pressurized oil system further comprising an internal
pressure relief valve positioned to maintain a constant pump pressure.

US Pat. No. 9,249,798

AUTOFRETTAGE PROCESS FOR A PUMP FLUID END

Schlumberger Technology C...

1. A two-step autofrettage process for enhancing the fatigue resistance of a multi-cylinder reciprocating pump fluid end used
to pump well stimulation fluids downhole, the process comprising:
arranging at least three fluid end cylinders in a linear fashion;
determining an optimal autofrettage pressure for a central cylinder of the at least three fluid end cylinders;
determining an optimal autofrettage pressure for the remaining at least two side fluid end cylinders;
autofrettaging the central cylinder separately from the remaining cylinders at the optimal central cylinder autofrettage pressure;
autofrettaging the remaining at least two side fluid end cylinders without autofrettaging said central cylinder at the optimal
side fluid end cylinder autofrettage pressure;

wherein said autofrettaging the remaining at least two side fluid end cylinders is performed concurrently, yet independently
of said autofrettaging of the central cylinder.

US Pat. No. 9,228,423

SYSTEM AND METHOD FOR CONTROLLING FLOW IN A WELLBORE

Schlumberger Technology C...

15. A method for controlling flow in a wellbore, comprising:
positioning a plurality of flow control valves along a well string located in a wellbore;
coupling a plurality of control modules to the plurality of flow control valves;
routing a pair of hydraulic lines and an electrical line along the wellbore to the plurality of control modules;
utilizing the pair of hydraulic lines and the electrical line to selectively actuate individual control modules of the plurality
of control modules and corresponding flow control valves of the plurality of flow control valves; and

providing each control module with a hydraulic override function which allows actuation of a corresponding flow control valve
of the plurality of flow control valves to a desired position via shifting of a normally open, hydraulically actuated valve
followed by only hydraulic input through at least one hydraulic line of the pair of hydraulic lines.

US Pat. No. 9,188,697

TRACKING NON-UNIFORM FLOODING FRONTS OF GAS INJECTION IN OIL RESERVOIRS

Schlumberger Technology C...

1. A system for monitoring gas introduced into a subterranean reservoir comprising:
a downhole gravity measurement tool adapted to be deployed in a borehole and to make gravity measurements at a downhole location;
a processing system adapted and programmed to receive data representing the gravity measurements including horizontal gravity
measurements from the downhole gravity measurement tool and based at least in part thereon to monitor parameters associated
with gas introduced into a subterranean reservoir; and

wherein the monitored parameters includes an inclination angle associated with the introduced gas and a reference plane and
wherein the inclination angle associated with the introduced gas is estimated based in part on the horizontal gravity measurements.

US Pat. No. 9,176,244

DATA SET INVERSION USING SOURCE-RECEIVER COMPRESSION

Schlumberger Technology C...

1. A method of processing formation survey data generated using an array of physical transmitters and an array of physical
receivers, the method comprising:
(i) producing excitations in the formation using the array of physical transmitters;
(ii) detecting the excitations using the array of physical receivers to generate survey data;
(iii) calculating a weighted sum for the array of physical transmitters, wherein the weighted sum comprises a weight for each
of the physical transmitters;

(iv) calculating a compressed data set for the survey data in which a number of physical transmitters is reduced by the weighted
sum to a number of representative transmitters in the compressed data set, wherein calculating the compressed data set comprises
constructing the compressed data set of L (L
wherein M is the number of physical transmitters, N is the number of physical receivers, L is the number of representative
transmitters in the compressed data set, Ji is the weighted sum for represents the M physical transmitters, and vk,i provides transmitter weights;
(v) performing an inversion using the compressed data set; and
(vi) outputting a result of the inversion in tangible form.

US Pat. No. 10,053,972

MONITORING OF STEAM CHAMBER GROWTH

SCHLUMBERGER TECHNOLOGY C...

1. A method for monitoring steam chamber growth, comprising:deploying sensors subsurface in a steam assisted gravity drainage region of a reservoir from which hydrocarbons are produced;
employing the sensors to measure data on the electrical and elastic properties of the steam assisted gravity drainage region;
processing the data received from the sensors at a computer processor located above the subsurface to predict a distribution of in situ bitumen, swept bitumen, and transition zone; and
tracking growth of a steam chamber on one or more displays by measuring and processing the data over time to facilitate production of a hydrocarbon from the reservoir.

US Pat. No. 9,461,469

ELECTRICAL POWER GRID FOR A DOWNHOLE BHA

SCHLUMBERGER TECHNOLOGY C...

1. A string of downhole tools comprising:
an electrical power grid electrically connecting at least a first power generating tool and a second power consuming tool
in the string; and

the power generating tool including a power generator, an electric load, and a power management controller, the power management
controller configured to automatically selectively electrically connect and disconnect the power generating tool to and from
the power grid,

wherein the power management controller is configured to connect a tool bus on the power generating tool to the power grid
when a DC voltage level on the tool bus is greater than a predetermined value;

wherein the power management controller comprises an integrated circuit switch configured to close when the DC voltage level
on the tool bus is greater than the predetermined value and open when the DC voltage level on the tool bus is less than the
predetermined value;

wherein the power management controller comprises an integrated circuit switch configured to repeatedly open and close at
a predetermined frequency when the DC voltage level on the tool bus is greater than the predetermined value and open when
the DC voltage level on the tool bus is less than the predetermined value, said repeated opening and closing operative to
provide AC power to the power grid.

US Pat. No. 9,394,473

METHODS AND COMPOSITIONS FOR SUSPENDING FLUIDS IN A WELLBORE

SCHLUMBERGER TECHNOLOGY C...

1. A method for preventing commingling of stationary process fluids in a subterranean borehole or in a tubular body installed
in a subterranean well, comprising:
i. selecting a fiber-laden support fluid having a supporting yield stress resulting from an entanglement of fibers contained
therein that are present at a chosen, concentration, length and diameter such that a crowding factor is achieved that exceeds
50;

ii. placing a first process fluid having a first yield stress into a wellbore or tubular body;
iii. placing a volume of the support fluid on top of the first process fluid;
iv. placing a second process fluid having a second yield stress on top of the support fluid;
v. allowing the first process fluid, the second process fluid and the support fluid to remain stationary after placement;
and

vi. allowing fiber entanglement to occur in the stationary support fluid, thereby causing the support fluid to develop the
supporting yield stress that prevents commingling of the first and second process fluids, wherein the supporting yield stress
is higher than the first yield stress.

US Pat. No. 9,394,745

ROTARY STEERABLE TOOL ACTUATOR TOOL FACE CONTROL

Schlumberger Technology C...

1. A method for controlling a drilling direction of a rotary steerable system having a rotatable collar and a sleeve pivoted
by bi-stable valve actuators to control the drilling direction, comprising:
determining an angular collar speed of a rotary steerable system;
establishing a transition angle interval for each bi-stable valve actuator as each bi-stable valve is switched between off
and on states; and

using the angular collar speed and the transition angle of each bi-stable valve actuator to control a desired dwell angle
interval for each bi-stable valve actuator.

US Pat. No. 9,371,717

ENHANCING WELL FLUID RECOVERY

SCHLUMBERGER TECHNOLOGY C...

1. A system, comprising:
a pump disposed downhole in a well to create a fluid flow of a pumped fluid through the pump between an Earth surface of the
well and a reservoir;

a variable speed drive to control a rotational speed of a motor of the pump;
a controller operatively connected to the variable speed drive for enhancing a fluid recovery from the reservoir;
a control logic in the controller to continually vary a rotational speed of the motor of the pump;
the control logic controlling the motor to create reflected cyclic pressure waves against at least one of the pump housing
and the production tubing;

at least one of the pump housing and the production tubing transmitting the pressure waves into the reservoir to enhance the
fluid recovery.

US Pat. No. 9,334,718

PROCESSING TIME SERIES DATA EMBEDDED IN HIGH NOISE

Schlumberger Technology C...

1. A method comprising:
acquiring from a plurality of sensors time series data corrupted by noise and including signals caused by microseismic events
in a subterranean formation;

processing discrete portions of the data using statistical analysis to determine, for each portion, whether an event of interest
is present, wherein the statistical analysis includes, for each portion, calculating a criterion using both a signal component
and noise information from the data and performing a hypothesis test to detect whether an event is present in the portion;

for each portion containing an event of interest, determining a first arrival time of the event and delay across the plurality
of sensors;

using the first arrival time and delay across the plurality of sensors to spatially map fractures in the subterranean formation;
and

controlling a fracture treatment of the subterranean formation using the spatially mapped fractures.

US Pat. No. 9,187,987

SYSTEM AND METHOD FOR CONTROLLING FLOW THROUGH A SAND SCREEN

Schlumberger Technology C...

1. A method of preventing component erosion in a well, comprising:
forming a base pipe with a plurality of flow restriction openings extending radially therethrough;
limiting the average diameter of each flow restriction opening to 8 mm or less;
placing a screen around the base pipe to filter particulates from an inflowing fluid stream;
spacing the plurality of flow restriction openings along the base pipe to reduce a peak flux through the screen and to create
a distributed inflow of fluid which maintains a flow rate of the inflowing fluid below an erosion flow rate across the screen;
and

varying perforation density along a length of the base pipe to optimize a flow distribution pattern by varying the sizes of
flow restriction openings along the base pipe, the varying perforation density providing a relatively greater restriction
of flow in sections of the screen otherwise exposed to the highest radial flow of fluid through the screen.

US Pat. No. 9,176,081

NMR ANALYSIS OF UNCONVENTIONAL RESERVOIR ROCK SAMPLES

Schlumberger Technology C...

1. A method of analyzing rock samples from a subterranean hydrocarbon reservoir comprising:
performing magic angle spinning nuclear magnetic resonance spectroscopy on a sample of rock from an unconventional hydrocarbon
reservoir wherein the magic angle spinning nuclear magnetic resonance spectroscopy includes pulse field gradient nuclear magnetic
resonance spectroscopy;

determining one or more characteristics associated with said sample of rock based at least in part on said magic angle spinning
nuclear magnetic resonance spectroscopy; and

wherein the one or more characteristics include measurements of one or more types selected from a group consisting of: total
organic carbon content, total organic carbon type, hydrocarbon saturation, water saturation, wettability, intralayer water,
interlayer water, hydraulic conductivity, hydraulic porosity, and gas type.

US Pat. No. 9,098,889

METHOD FOR QUANTITATIVE PREDICTION OF MATRIX ACIDIZING TREATMENT OUTCOMES

Schlumberger Technology C...

1. A method, comprising:
performing a computed tomography (CT) porosity scan on a core sample, the core sample comprising a portion of a formation
of interest;

in response to the CT porosity scan, interpreting a porosity profile of the core sample; and
in response to the porosity profile, modeling a response of a formation of interest to a predetermined treatment to determine
a reacted formation configuration, wherein the predetermined treatment comprises an acid fluid treatment schedule, and wherein
the modeling further comprises modeling acid fluid flow through the formation of interest having the porosity profile, and
wherein the modeling further comprises accounting for acid reaction products during the predetermined treatment and shut-in
period

wherein the modeling further comprises determining a micro-pore geometry, and accounting for the micro-pore geometry.

US Pat. No. 9,507,045

BASALT FIBER COMPOSITE FOR ANTENNA IN WELL-LOGGING

SCHLUMBERGER TECHNOLOGY C...

1. A well-logging tool for a geological formation having a borehole therein, comprising:
a housing to be positioned within the borehole;
an antenna assembly carried by the housing and comprising
an antenna housing having a recess therein,
a dielectric material layer comprising a basalt fiber composite within the recess;
at least one antenna coil supported by the dielectric material layer,
an electrical connector coupled to the at least one antenna coil,
wherein said dielectric material layer is configured to prevent fluid leakage to the antenna coil and/or electrical connector
when the well-logging tool is operated at a downhole temperature higher than 175° C.; and

resistivity processing circuitry coupled to the electrical connector to determine an electrical resistivity of the geological
formation based upon the at least one antenna coil.

US Pat. No. 9,322,246

SOLIDS DELIVERY APPARATUS AND METHOD FOR A WELL

SCHLUMBERGER TECHNOLOGY C...

1. A method usable with a well, comprising:
introducing solids into a hopper of an air blower assembly, thereby producing a solids-containing pneumatic stream at a first
location near or at the blower assembly;

communicating the solids-containing pneumatic stream via a conduit from the first location directly to a second location at
a hopper of a blender assembly at the second location to mix the solids with at least one other material, thereby producing
a flow; and

pumping the flow into the well.

US Pat. No. 9,316,754

SEISMIC ACQUISITION SYSTEM INCLUDING A DISTRIBUTED SENSOR HAVING AN OPTICAL FIBER

Schlumberger Technology C...

1. A seismic acquisition system, comprising:
a distributed optical sensor having an optical fiber for positioning outside a subterranean structure to be surveyed; and
an interrogation subsystem configured to:
generate a light signal to emit into the optical fiber;
receive, from the distributed optical sensor, backscattered light responsive to the emitted light signal, wherein the backscattered
light is affected by one or both of seismic signals reflected from the subterranean structure and noise; and

output data corresponding to the backscattered light to a processing subsystem to determine a characteristic of the subterranean
structure,

wherein the distributed optical sensor and interrogation subsystem are configured to provide a spatial resolution having a
predefined relationship to wavelength(s) of one or both of the seismic signals and the noise, and

wherein the spatial resolution is less than the wavelength of the seismic signals.

US Pat. No. 9,163,629

CONTROLLED THICKNESS RESILIENT MATERIAL LINED STATOR AND METHOD OF FORMING

Schlumberger Technology C...

1. A method of forming a resilient material lined stator comprising:
forming a resilient material tube with a profiled helical inner surface and a variable thickness;
disposing the resilient material tube within a longitudinal bore of a body;
filling a void between an outer surface of the resilient material tube and the longitudinal bore of the body with a cast material
in a fluid state; and

allowing the cast material to solidify.

US Pat. No. 9,109,431

REDUCING DIFFERENTIAL STICKING DURING SAMPLING

Schlumberger Technology C...

1. A method, comprising:
lowering a downhole tool via a pipe into a wellbore drilled through a formation via the pipe;
performing a sticking test;
estimating a maximum duration on station based on results of the sticking test and a sticking model;
establishing a fluid communication between the downhole tool and the formation at a location in the wellbore;
extracting from the formation a first fluid stream through the fluid communication and passing the first fluid stream through
the downhole tool for a first duration, wherein the first duration has a predetermined length based on the estimated maximum
duration on station;

breaking the fluid communication between the downhole tool and the formation;
moving the pipe in the wellbore, wherein moving the pipe in the wellbore comprises:
moving the downhole tool away from the location after breaking the fluid communication between the downhole tool and the formation;
and then

moving the downhole tool towards the location before reestablishing the fluid communication between the downhole tool and
the formation essentially at the location;

reestablishing the fluid communication between the downhole tool and the formation essentially at the location in the wellbore
subsequent to moving the pipe in the wellbore;

extracting, from the formation, a second fluid stream through the fluid communication and passing the second fluid stream
through the downhole tool for a second duration, wherein the second duration has a predetermined length based on the estimated
maximum duration on station; and

capturing, in the downhole tool, a fluid sample of the second fluid stream.

US Pat. No. 9,388,812

WIRELESS SENSOR SYSTEM FOR ELECTRIC SUBMERSIBLE PUMP

Schlumberger Technology C...

1. An electric submersible pump system comprising:
a shaft;
a power cable connector;
an electric motor configured to receive power via the power cable connector for rotatably driving the shaft;
a pump operatively coupled to the shaft;
a power unit for generating power via rotation of the shaft;
a remote unit that comprises at least one sensor for sensing information, wireless transmission circuitry for wireless transmission
of sensed information and a power interface to receive power generated by the power unit; and

a base unit that comprises wireless reception circuitry for receipt of wireless transmission of sensed information from the
remote unit and wired transmission circuitry operatively coupled to the power cable connector.

US Pat. No. 9,322,948

METHOD OF DETERMINING A FORMATION PARAMETER

Schlumberger Technology C...

1. A method of measuring a formation parameter of a rock formation in the process of drilling a well penetrating the rock
formation, comprising:
providing a section of the well with a drill string comprising a drilling bit at a distal end of the drill string;
circulating a first fluid through the drilling bit, said first fluid invading the rock formation surrounding the well;
using a formation evaluation tool mounted onto the drill string to measure the formation parameter;
selecting a time at which a second fluid is started to circulate through the drilling bit, such that the second fluid alters
a response of the rock formation to the formation evaluation tool;

circulating the second fluid through the drilling bit to start invading the formation surrounding the well; and
using the formation evaluation tool to re-measure said formation parameter while circulating said second fluid.

US Pat. No. 9,284,815

FLOW RESTRICTOR FOR USE IN A SERVICE TOOL

Schlumberger Technology C...

17. A method for gravel packing at least a portion of a wellbore, comprising:
setting a packer to isolate a distal annulus from a proximal annulus;
gravel packing at least a portion of the distal annulus using a service tool extending through the packer, wherein the service
tool includes a conduit in fluid communication with the proximal annulus and the distal annulus, wherein the service tool
includes a flow restrictor disposed in the conduit, wherein the flow restrictor includes a primary flowpath extending therethrough
and a secondary flowpath extending therethrough, and wherein fluid flows through the primary flowpath and the secondary flowpath
in a first direction as the at least a portion of the distal annulus is gravel packed; and

after gravel packing, circulating a cleaning fluid, using the service tool, through at least a portion of the proximal annulus,
wherein the cleaning fluid flows through the secondary flowpath in a second, opposing direction, but is substantially blocked
from flowing through the primary flowpath in the second, opposing direction, as the cleaning fluid is circulated.

US Pat. No. 9,223,056

DETERMINING BOREHOLE CORRECTED FORMATION PROPERTIES

Schlumberger Technology C...

1. A method for correcting formation properties due to effects of a borehole comprising:
obtaining voltage measurements using a logging tool disposed in a borehole penetrating a subsurface formation;
using a processor to:
determine a tensor for the formation using the voltage measurements;
for a given set of parameters, determine, based upon the voltage measurements, a parameter value for each parameter in a subset
of the set of parameters;

compute a borehole-inclusive modeled tensor that includes the effects of the borehole using the parameter values;
optimize the parameter values using the determined tensor and the borehole-inclusive tensor;
compute an optimized tensor using the optimized parameter values;
compute a borehole corrected tensor using the optimized tensor; and
determine at least one borehole corrected formation property using at least one of the borehole corrected tensor or the optimized
parameter values.

US Pat. No. 9,069,098

THREE OR MORE MULTIPLE FIGURE-EIGHT COILS FOR NMR WELL-LOGGING MEASUREMENTS WITH AZIMUTHAL DIRECTIONAL SENSITIVITY

Schlumberger Technology C...

1. An NMR method, comprising:
providing an NMR apparatus disposed in a wellbore and having an array of three or more figure-eight coil NMR sensors, wherein
the NMR apparatus has an axial length aligned with a wellbore trajectory and the figure-eight coil NMR sensors are located
at substantially the same axial length position along the axial length of the NMR apparatus and having different azimuthally
directional sensitivities, and wherein a first figure-eight coil of the three or more figure-eight coil NMR sensors overlaps
a second figure-eight coil of the three or more figure-eight coil NMR sensors at a first axial length position of the NMR
apparatus and wherein the second figure-eight coil of the three or more figure-eight coil NMR sensors overlaps a third figure-eight
coil of the three or more figure-eight coil NMR sensors at the first axial length position of the NMR apparatus; acquiring
an NMR signal from at least three of the three or more figure-eight coil NMR sensors; and combining the NMR signals in order
to obtain an azimuthal image of the borehole.

US Pat. No. 9,394,763

MULTILATERAL LOCATION AND ORIENTATION ASSEMBLY

Schlumberger Technology C...

1. An apparatus for a multi-lateral wellbore comprising: a locating and orientation assembly, the assembly further comprising:
a coupling portion comprising a landing profile disposed on an inner surface of the coupling portion;
an upper muleshoe;
a muleshoe spacer;
a bottom muleshoe, wherein the bottom muleshoe connects to the coupling portion through a threaded connection;
an orienting profile formed by the upper muleshoe, the muleshoe spacer, and the bottom muleshoe, disposed on the interior
of the assembly to azimuthally orient a tool passing through the assembly, wherein the muleshoe spacer has an at least partially
helical cross-sectional shape suitable to align the upper muleshoe with the bottom muleshoe in order to form the orienting
profile.

US Pat. No. 9,388,335

PICKERING EMULSION TREATMENT FLUID

Schlumberger Technology C...

1. A treatment fluid, comprising:
a plurality of particles comprising an Apollonianistic particle size distribution comprising particles of a Pickering emulsion
comprising a first liquid phase dispersed in a continuous second liquid phase and a plurality of colloidal particles adsorbed
to a liquid-liquid interface between the first liquid phase and the second liquid phase.

US Pat. No. 9,371,730

SYSTEM AND METHOD RELATED TO A SAMPLING PACKER

SCHLUMBERGER TECHNOLOGY C...

1. A system for collecting fluid from a specific region of a wellbore, comprising:
a packer comprising:
an outer bladder expandable in a wellbore across an expansion zone to contact and fluidly separate a first portion of the
wellbore from a second portion of the wellbore, wherein the outer bladder having a plurality of drains for receiving formation
fluid into the packer, and wherein the plurality of drains comprises a first drain and a second drain both spaced around a
circumference of the packer;

an inflatable bladder disposed within the outer bladder; and
a plate positioned along the circumference between the first drain and the second drain of the plurality of drains to limit
sealing in the circumferential space between the first drain and the second drain.

US Pat. No. 9,309,745

INTERVENTIONLESS OPERATION OF DOWNHOLE TOOL

SCHLUMBERGER TECHNOLOGY C...

10. A method of downhole actuation, comprising:
providing an actuation component with a compensating piston acting against a liquid in a liquid chamber;
forming a trip saver component with a rupture member and a pressure isolation piston slidably positioned in a pressure isolation
piston chamber;

exposing the compensating piston to a first wellbore region subjected to pressure and exposing the rupture member to a second
wellbore region subjected to pressure;

providing a flow path through the pressure isolation piston chamber between the liquid chamber and an actuator of a downhole
tool; and

using the pressure isolation piston to selectively block flow of the liquid or enable flow of the liquid along the flow path
through the pressure isolation piston chamber and against the actuator of the downhole tool.

US Pat. No. 9,273,686

PRE-CHARGING PUMP CHAMBER BY PREEMPTIVELY OPENING A VALVE

Schlumberger Technology C...

1. An apparatus, comprising:
a pump for a well fluid;
a reciprocating mover in the pump to alternately inflate and deflate a diaphragm within the pump;
an inlet valve to allow the well fluid to enter the pump when the diaphragm deflates;
a discharge valve to allow the well fluid to exit the pump when the diaphragm inflates;
an intermittent mechanical linkage between the reciprocating mover and the discharge valve;
wherein the intermittent mechanical linkage causes a pressure backflow of a well fluid from outside the pump into the pump
via the discharge valve;

wherein the mechanical linkage causes the pressure backflow from outside the pump during a maximum extension of the reciprocating
mover; and

wherein the increased pressure from outside the pump and an inflation of the diaphragm and resulting from the maximum extension
of the reciprocating mover charges a pumping chamber of the pump during a reciprocation of the reciprocating mover.

US Pat. No. 9,110,094

MEASUREMENT OF SURFACE ENERGY COMPONENTS AND WETTABILITY OF RESERVOIR ROCK UTILIZING ATOMIC FORCE MICROSCOPY

Schlumberger Technology C...

1. A method of characterizing properties of a sample of reservoir rock comprising:
i) configuring an Atomic Force Microscopy (AFM) instrument to have a probe with a tip realized from reservoir rock that corresponds
to the reservoir rock of the sample;

ii) using the AFM instrument as configured in i) to derive and store data representing adhesion forces between the tip and
the sample at one or more scan locations in the presence of a number of different fluids disposed between the tip and the
sample; and

iii) performing computational operations that process the data as derived and stored in ii) for a given scan location in order
to characterize at least one property of the rock sample at the given scan location.

US Pat. No. 9,334,719

EXPLOSIVE PELLET

Schlumberger Technology C...

12. A method for characterizing a fracture in a subterranean formation, comprising:
introducing a fluid having a plurality of pellets disposed therein into a wellbore, each pellet comprising:
a casing having an opening disposed at an end thereof and a cap covering the opening;
a detonation material disposed within the casing;
an explosive material disposed within the casing; and
a nonexplosive material moveably disposed within the casing, wherein movement of the nonexplosive material generates a predetermined
amount of energy in the form of friction-generated heat sufficient to detonate the explosive material, wherein the nonexplosive
material has an internal volume and an ignition material disposed within the internal volume;

increasing a pressure of the fluid to form the fracture in the subterranean formation, wherein at least a portion of the pellets
are disposed within the fracture;

exploding at least a portion of the pellets;
receiving one or more signals from the exploded pellets,
degradeing at least a portion of a first end of the cap;
moving the cap within the casing and toward the detonation material; and
striking the detonation material with a protrusion disposed on a second end of the cap.

US Pat. No. 9,238,961

OILFIELD OPERATION USING A DRILL STRING

SCHLUMBERGER TECHNOLOGY C...

1. A method, comprising:
collecting temperature data at a plurality of locations along a wellbore extending into a subterranean formation;
performing thermo-mechanical simulations of a drill string in response to mud circulation, wherein the drill string comprises
a tool string suspended in the wellbore from a pipe string;

determining changes in length of the drill string due to temperature changes;
positionally fixing the tool string at one of the locations; and
adjusting the length of the drill string based on the determined change in length of the drill string.

US Pat. No. 9,217,328

AUTOMATED SIDEWALL CORING

Schlumberger Technology C...

1. A method, comprising:
positioning a downhole tool in a wellbore extending into a subterranean formation;
commencing coring operations by rotating a coring bit of the downhole tool and extending the rotating coring bit into a sidewall
of the wellbore;

measuring a rotating speed of the coring bit using a bit rotating speed sensor;
measuring a rotating speed of a bit rotation motor using a bit rotation motor speed sensor;
computing via a controller a ratio of the measured rotating speed of the coring to the measured rotating speed of the bit
rotation motor;

comparing via the controller the computed ratio to a target ratio of the measured rotating speed of the coring to the measured
rotating speed of the bit rotation motor; and

automatically adjusting via the controller a rotating speed of a weight on bit (WOB) motor based on the comparison of the
computed ratio to the target ratio.

US Pat. No. 9,140,115

METHODS OF USING ENHANCED WELLBORE ELECTRICAL CABLES

Schlumberger Technology C...

1. A method of deploying a cable into a wellbore penetrating a subterranean formation, the method comprising:
a. providing a cable, wherein the cable comprises:
(i) an insulated conductor;
(ii) an armor wire layer surrounding the insulated conductor, wherein the armor wires forming the armor wire layer comprise:
a central filament,
at least three (3) filaments helically disposed adjacent the central filament, and
a polymer jacket encasing the central filament and filaments disposed adjacent the central filament; and
(iii) a polymeric material disposed in interstitial spaces formed between the armor wires forming the armor wire layer, and
in interstitial spaces formed between the armor wire layer and the insulated conductor;

b. introducing the cable into a wellbore; and
c. performing at least one operation in the wellbore utilizing the cable.

US Pat. No. 9,483,607

DOWNHOLE DYNAMICS MEASUREMENTS USING ROTATING NAVIGATION SENSORS

SCHLUMBERGER TECHNOLOGY C...

1. A method for making downhole dynamics measurements in a drill string, the method comprising:
(a) rotating a downhole navigational sensor set in a borehole, the navigational sensor set deployed in the drill string and
including at least first, second, and third tri-axial accelerometers;

(b) causing the navigational sensor set to obtain a string of accelerometer measurements, the string of accelerometer measurements
including a plurality of tri-axial accelerometer measurements made at a predetermined measurement interval;

(c) differentiating the string of accelerometer measurements obtained in (b) to obtain a corresponding string of differentiated
accelerometer measurements;

(d) causing a downhole processor to process the differentiated accelerometer measurements obtained in (c) to obtain a drill
string vibration parameter;

(e) causing the downhole processor to further process the drill string vibration parameter obtained in (d) so as to remove
at least one of a gravitational acceleration component, a tangential acceleration component, and a centripetal acceleration
component to obtain a corrected drill string vibration parameter; and

(f) implementing one or more corrective measures based on the corrected drill string vibration parameter, wherein the corrective
measures comprise the step of adjusting a dynamic drilling condition, the dynamic drilling condition comprising axial vibration,
lateral shock, lateral vibration, torsional vibration and/or stick/slip.

US Pat. No. 9,206,667

HYDRAULIC SYSTEM AND METHOD OF MONITORING

Schlumberger Technology C...

19. A system deployed on a surface of a well site, comprising:
a hydraulic pump;
a hydraulic motor coupled to the hydraulic pump via a hydraulic line;
a plurality of sensors positioned to monitor parameters related to operation of the hydraulic pump and the hydraulic motor;
and

a processor system coupled to the plurality of sensors to obtain data from the sensors, the processor system having a processor
unit to analyze the data for failure signatures in frequency and time domains and indicate a failure condition of one of the
hydraulic pump, the hydraulic motor and the hydraulic line.

US Pat. No. 9,164,185

NEAR-SIMULTANEOUS ACQUISITION FOR BOREHOLE SEISMIC

Schlumberger Technology C...

1. A system of performing three-dimensional vertical seismic profiling comprising:
a vessel comprising:
two or more source arrays configured to generate acoustic source signals;
a downhole acquisition system comprising acoustic receivers configured to receive the source signals and to generate data
streams;

a navigation system to determine a real time speed, position, and direction of the vessel and to estimate an initial shot
time;

a source controller to control firing of acoustic source signals in which timing of an additional shot time is based on the
initial shot time plus an offset and a dither value;

a synchronization unit to coordinate the firing of dithered acoustic signals with recording by the downhole acquisition system;
and

a processor to separate a data stream of the initial shot and a data stream of the additional shot via a coherency filter.

US Pat. No. 9,062,535

WIRELESS NETWORK DISCOVERY ALGORITHM AND SYSTEM

Schlumberger Technology C...

1. A wireless modem for communication in a network of wireless modems via a communication channel in a downhole environment,
the wireless modem comprising:
a transceiver assembly;
transceiver electronics, comprising:
transmitter electronics to cause the transceiver assembly to send wireless signals into the communication channel;
receiver electronics to decode signals from a plurality of other wireless modems received by the transceiver assembly;
at least one processor executing instructions to (1) enable the transmitter electronics to transmit an identification signal
into the communication channel, (2) receive data from at least one other wireless modem via the receiver electronics indicative
of a unique identifier identifying the at least one other wireless modem, and data representative of at least one first local
sensor measurement made by at least one first local sensor associated with the at least one other wireless modem of a parameter
that is related to a depth of the at least one other wireless modem below a surface of the Earth, and (3) determine a relative
order and a position of the at least one other wireless modem in the network of wireless modems along the communication channel
using a comparison between the data representative of the at least one first local sensor measurement of the parameter that
is related to the depth of the at least one other wireless modem and data representative of a second local sensor measurement
made by a second local sensor associated with the wireless modem, wherein the data representative of the at least one first
local sensor measurement includes a time slot, and wherein the relative order and the position of the at least one other wireless
modem is determined in part based on which available time slot of a plurality of available time slots contains the data representative
of the at least one first local sensor measurement received from the at least one other wireless modem; and

a power supply supplying power to the transceiver assembly and the transceiver electronics.

US Pat. No. 9,507,889

DECOMPOSITION OF THE SEISMIC MOMENT TENSOR

SCHLUMBERGER TECHNOLOGY C...

1. A method of analysing an underground seismic event comprising:
performing a hydraulic fracturing which causes a seismic event;
receiving and measuring seismic waves emitted by the seismic event using one or more seismic data recording devices;
converting the measurements of the seismic waves using a digital computer into
a value for magnitude of explosion or implosion,
a value for magnitude of displacement discontinuity at a plane,
the direction of a normal to that plane, and
a direction of displacement;
where the two said values and the two said directions compose a whole moment tensor describing the seismic event;
outputting the two said values and the two said directions; and
analyzing the underground seismic event caused by the hydraulic fracturing.

US Pat. No. 9,448,189

APPARATUS AND METHOD FOR FLUID PHASE FRACTION DETERMINATION USING X-RAYS

SCHLUMBERGER TECHNOLOGY C...

1. An apparatus for determining fluid phase fraction of a multiphase fluid mixture, the apparatus comprising:
an x-ray generator arranged to emit an x-ray radiation spectrum comprising a Bremsstrahlung spectrum including a low energy
region and a high energy region;

a pipe section through which the multiphase fluid mixture flows comprising a measurement section, said measurement section
being coupled to said x-ray generator;

a multichannel analyzer;
a detector coupled to said measurement section and arranged to detect an x-ray radiation spectrum that has passed through
said multiphase fluid mixture, the detector being coupled to the multichannel analyzer producing a measurement output comprising
a low energy measurement count (LE) and a high energy measurement count (HE) and a low energy control count (LV) and a high
energy control count (HV), the low energy control count (LV) and the high energy control count (HV) determined from a low
energy control window and a high energy control window, wherein each control window is located along an edge of the Bremsstrahlung
spectrum, respectively; and

an electrical parameter control arrangement coupled to the x-ray generator and the detector, the electrical parameter control
arrangement being arranged to calculate a first ratio (RV) of the high energy control count (HV) relative to the low energy control count (LV) (RV=HV/LV) and a second ratio (RE) of the high energy measurement count (HE) relative to the low energy measurement count (LE) (RE=HE/LE), and to adjust an electrical operation of the x-ray generator based on an electrical parameter control function (FC(V)) of said ratios that minimizes a dependence on the fluid phase fraction of the multiphase fluid mixture flowing in the
measurement section.

US Pat. No. 9,394,781

LOGGING-WHILE-DRILLING TOOL INCORPORATING ELECTRONIC RADIATION GENERATOR AND METHOD FOR USING SAME

SCHLUMBERGER TECHNOLOGY C...

1. A logging-while-drilling tool comprising:
a circumferential drill collar;
a circumferential stabilizer radially exterior to the drill collar;
a circumferential mud channel radially interior to the circumference of the drill collar;
a mandrel chassis radially interior to the mud channel;
a plurality of X-ray permissive mandrel supports disposed within the mud channel between the mandrel chassis and drill collar;
an electronic X-ray generator disposed within the mandrel chassis, wherein the electronic X-ray generator is configured to
emit X-rays through a first collimation channel and at least one of the plurality of X-ray permissive mandrel supports to
exit the logging-while-drilling tool into a subterranean formation at a first azimuthal angle; and

a first X-ray detector configured to detect X-rays that return to the logging-while-drilling tool after scattering in the
subterranean formation.

US Pat. No. 9,238,959

METHODS FOR IMPROVED ACTIVE RANGING AND TARGET WELL MAGNETIZATION

Schlumberger Technology C...

1. An electromagnetic array configured for use in a subterranean borehole, the array comprising:
a substantially cylindrical non-magnetic housing configured to be deployed in a subterranean borehole;
at least first, second, third, and fourth, electromagnets deployed in the housing, the electromagnets being axially spaced
apart and substantially co-axial with one another;

a first subset of the electromagnets configured to generate magnetic flux in a first axial direction when connected with an
electrical power source and a second subset of the electromagnets configured to generate magnetic flux in a second opposing
axial direction when connected with the electrical power source such that a magnetic field pattern having at least first and
second pairs of magnetically opposing poles is generated; and

each of the first and second subsets includes at least two of the electromagnets;
wherein at least the first electromagnets is electrically connected with a diode bridge which is configured to be connected
with the electrical power source, the diode bridge being configured to provide an electrical current having a fixed polarity
to the first electromagnet, irrespective of a polarity of the electrical power source;

wherein at least the second electromagnet is configured to be connected directly with the electrical current source such that
a polarity of electrical current provided to the second electromagnet is identical to a polarity of the electrical power source;
and

wherein the magnetic field pattern generated by the electromagnetic array (i) has a first non-zero number of the magnetically
opposing poles when the electrical power source has a first polarity and (ii) has a second different non-zero number of the
magnetically opposing poles when the electrical power source has a second opposite polarity, and wherein the magnetically
opposing poles have the same magnetic polarity.

US Pat. No. 9,238,962

PORE PRESSURE FROM SPECTROSCOPY AND SONIC DATA

Schlumberger Technology C...

1. A method, comprising:
obtaining a plurality of spectroscopy measurements on a formation using a spectroscopy sensor on a logging tool;
obtaining a plurality of acoustic measurements on the formation using an acoustic sensor on the logging tool;
determining, using a processor, an upper velocity limit and a lower velocity limit for sonic waves traveling through the formation
using the spectroscopy measurements;

determining, using the processor, Biot's constant using the spectroscopy measurements;
determining, using the processor, an effective stress using the acoustic measurements and the upper and lower velocity limits;
determining, using the processor, a total stress using the effective stress; and
determining, using the processor, a pore pressure using the total stress, the effective stress, and the Biot's constant.

US Pat. No. 9,222,902

ESTIMATIONS OF NUCLEAR MAGNETIC RESONANCE MEASUREMENT DISTRIBUTIONS

Schlumberger Technology C...

1. A method of investigating a sample, comprising:
performing nuclear magnetic resonance (NMR) measurements on the sample using an NMR tool to obtain NMR data;
conducting integral transforms on the NMR data to obtain linear functionals associated with said sample;
utilizing said linear functionals as constraints in a cost function which includes said NMR data, said linear functionals,
and Laplace transform elements;

minimizing said cost function with respect to an NMR-related distribution to obtain a distribution estimation relating to
the sample; and

using said distribution estimation to find values of at least one parameter of the sample.

US Pat. No. 9,164,192

STRESS AND FRACTURE MODELING USING THE PRINCIPLE OF SUPERPOSITION

Schlumberger Technology C...

1. A method comprising:
receiving values of a perturbed stress field associated with a fractured region of earth, the values calculated via at least
three linearly independent numerical simulations;

receiving values of at least three far field stress vectors, the values used as boundary conditions for the numerical simulations;
based on the values of the at least three far field stress vectors, building and inverting a stress matrix that comprises
columns representing the far field stress vectors to generate an inverted stress matrix;

based at least in part on the values of the perturbed stress field and the inverted stress matrix, minimizing a cost function
to compute values of a parameter vector;

based at least in part on the values of the parameter vector, computing values of a paleostress vector associated with the
fractured region of earth;

determining a tectonic regime based at least in part on the values of the paleostress vector; and
associating the tectonic regime with at least one fault of the fractured region of earth.

US Pat. No. 9,910,173

SATURATION END-POINT ADJUSTMENT

Schlumberger Technology C...

1. A computing system implemented method comprising:
receiving, in a computing system, fluid saturation data for fluid saturation parameters associated with permeabilities of
a multidimensional spatial model of a geologic environment wherein the multidimensional spatial model comprises a grid cell
model that comprises a plurality of grid cells;

identifying, using the computing system, grid cells of the grid cell model that violate at least one criterion that depends
on at least two different fluid saturation parameters;

adjusting, using the computing system, at least a portion of the fluid saturation data for at least a portion of the identified
grid cells to provide adjusted fluid saturation data by optimizing a quadratic function of different fluid saturation parameters
subject to linear constraints wherein at least one of the linear constraints depends on at least two different fluid saturation
parameters; and

simulating, using the computing system, flow of fluid using the adjusted fluid saturation data for fluid saturation parameters
associated with permeabilities and the multidimensional spatial model of the geologic environment.