US Pat. No. 9,222,343

IN SITU RF HEATING OF STACKED PAY ZONES

ConocoPhillips Company, ...

1. A method of enhancing production of hydrocarbons in a hydrocarbon formation beneath an overburden and having a plurality
of stacked pay zones separated by a plurality of steam-impermeable structures, comprising:
a) providing producer wells within the hydrocarbon formation;
b) measuring electric conductivity in the stacked pay zones and the steam-impermeable structures to determine areas having
the highest electric conductivity;

c) providing a radio frequency (RF) antenna array within the hydrocarbon formation at said areas having the highest electric
conductivity, wherein the RF antenna array having a plurality of antenna elements is connected to an alternating electrical
current source oscillating at radio frequencies and wherein adjacent antennas in said RF antenna array are staggered, and
wherein said antenna elements are linear dipole elements;

d) generating a time varying electromagnetic field at said antennas, so as to create eddy currents in the stacked pay zones
and heat at least a portion of the hydrocarbons predominantly by joule heating; and

e) producing the hydrocarbons through the producer wells,
wherein the connection between the RF antenna array and the alternating electrical current source is shielded to avoid undesired
heating at the overburden.

US Pat. No. 9,322,254

METHOD FOR HYDROCARBON RECOVERY USING HEATED LIQUID WATER INJECTION WITH RF HEATING

HARRIS CORPORATION, Melb...

1. A method for hydrocarbon resource recovery in a subterranean formation comprising:
forming a laterally extending injector well in the subterranean formation;
forming a laterally extending producer well spaced below the injector well;
radio frequency (RF) heating the subterranean formation to establish hydraulic communication between the injector well and
the producer well;

injecting at least one of an inert gas, propane, and methane into the injector well to assist with the hydraulic communication
between the injector well and the producer well by at least displacing hydrocarbon resources from the injector well to the
producer well;

determining whether hydraulic communication has been established between the injector well and the producer well; and
when hydraulic communication has been established between the injector well and the producer well, injecting heated liquid
water into the injector well to recover the hydrocarbon resources from the producer well based upon the hydraulic communication
therebetween.

US Pat. No. 9,139,762

SWELLABLE POLYMER WITH CATIONIC SITES

ConocoPhillips Company, ...

1. A method of increasing the recovery of hydrocarbon fluids in a subterranean formation comprising injecting into a subterranean
formation a composition comprising water, and a highly crosslinked expandable hydrophilic polymeric particle having at least
0.5 mole percent cationic sites, wherein:
i) said polymeric particle has an unexpanded volume average particle size diameter of 0.05-10 microns and a crosslinker content
of about 1,000-200,000 ppm of labile crosslinker and about greater than 0 to 300 ppm of stable crosslinker,

ii) said polymeric particle has a smaller diameter than the pore throats of the subterranean formation,
iii) said labile crosslinkers break under the conditions of temperature and suitable pH in the subterranean formation to allow
the polymeric particle to expand, and

iv) said cationic sites adsorb to said subterranean formation thus making said particle resistant to washout.
US Pat. No. 9,267,075

SWELLABLE POLYMER WITH ANIONIC SITES

ConocoPhillips Company, ...

1. A method of increasing the recovery of hydrocarbon fluids from a subterranean formation comprising injecting into the subterranean
formation a composition comprising water, a cationic crosslinker, and a highly crosslinked expandable hydrophilic polymeric
particle having anionic sites, wherein:
i) said polymeric particle has an unexpanded volume average particle size diameter of 0.05-10 microns and a crosslinker content
of about 1,000-200,000 ppm of labile crosslinker and greater than 0 to about 300 ppm of stable crosslinker,

ii) said polymeric particle has a smaller diameter than the pore throats of the subterranean formation,
iii) said labile crosslinkers break under the conditions of temperature and suitable pH in the subterranean formation to allow
the polymeric particle to expand, and

iv) said cationic crosslinker then reacts with said expanded polymer to form a gel.
US Pat. No. 9,796,909

NANOGELS FOR DELAYED GELATION

ConocoPhillips Company, ...

1. A degradable composition comprising a polymer having releasable carboxylate groups bound to a multivalent metal ion, said
degradable composition lasting at least 5 days at 85° C. in a brine solution having 23 g/l NaCl, and thereafter degrading
and releasing said multivalent metal ion, wherein said composition is in the form of a nanogel, wherein said polymer is polyvinyl
alcohol succinate (PVAS) or polyaspartate (PAsp) and said multivalent metal ion comprises chromium or zirconium, wherein said
composition comprises:
a) 135 mg PVAS-25 kDA and 1500 ppm Cr;
b) 101 mg PVAS-25 kDA and 1500 ppm Cr;
c) 68 mg PVAS-25 kDA and 1500 ppm Cr
d) 143 mg PVAS-6 kDA and 1500 ppm Cr
e) 794 mg PVAS-6 kDA and 3600 ppm Cr;
f) 368 mg PVAS-25 kDA and 3600 ppm Cr;
g) 328 ppm PVAS-6 kDA and 4463 ppm Zr; or
h) 921 ppm PAsp and 6837 ppm Cr.

US Pat. No. 9,644,136

LOW PH CROSSLINKING OF POLYMERS

ConocoPhillips Company, ...

1. A method of improving sweep efficiency of a CO2 flood of a reservoir, said method comprising:
a) injecting a composition into said reservoir, said composition comprising a polymer with one or more acrylamide based monomers
in the repeat unit, wherein one of said acrylamide based monomers has pendant hydroxyl groups, a fluid, and an optional phenolic
crosslinker, wherein said polymer has a first viscosity at pH 8 and a second higher viscosity to form a gel when aged at a
pH less than 5;

b) aging the composition to increase its viscosity or form a gel;
c) injecting a slug of CO2 into said reservoir, wherein said CO2 reduces a viscosity of oil; and producing said reduced viscosity oil,

wherein said CO2 is co-injected with said composition.

US Pat. No. 9,297,240

CYCLIC RADIO FREQUENCY STIMULATION

ConocoPhillips Company, ...

1. A method for enhanced oil recovery using cyclic radio frequency (RF) in a hydrocarbon reservoir, said method comprising:
i) providing RF energy at a first power level in a hydrocarbon reservoir to create a dessication region in said hydrocarbon
reservoir,

ii) allowing a soak period during which RF energy is reduced by 75-100% of said first power level, and
iii) repeating steps i-ii) one or more times; and
iv) subsequently collecting hydrocarbon from said hydrocarbon reservoir at one or more times.

US Pat. No. 9,453,400

ENHANCED RECOVERY AND IN SITU UPGRADING USING RF

ConocoPhillips Company, ...

1. A method of obtaining heavy oil from a subsurface reservoir, comprising:
a) injecting at least three different activators into a producing stratum of a steam assisted gravity drainage (SAGD) system
in a subsurface reservoir containing heavy oil at a first temperature, wherein said at least three different activators are
metal-containing asymmetric molecules that absorb different RF radiation and have different peak excitation levels;

b) exciting the activators with a generated RF radiation having a frequency between 0.1 MHz to 300 MHz to generate at least
three excited activators and raising said temperature of said heavy oil to above 260° C. with said excited activators to produce
a heated heavy oil; and

c) pumping said heated heavy oil out of said subsurface reservoir,
wherein said at least three excited activators increase the oil production more than a SAGD process without said at least
three excited activators, and

wherein said at least three excited activators decrease the Steam Oil Ratio (SOR) by 50% to 80% compared to a SAGD process
without said at least three excited activators.

US Pat. No. 9,353,683

METHOD FOR STORING COMPRESSED AIR IN POROUS SUBSURFACE LOCATIONS

ConocoPhillips Company, ...

1. A process for storing compressed air in a porous subterranean formation, the process comprising:
without injecting air into the porous subterranean formation, pumping water from the porous subterranean formation having
a single porosity or a variety of porosities to an earthen surface and simultaneously lowering an internal pressure of the
porous subterranean formation to a first predetermined pressure;

simultaneously injecting air into and pumping water from the porous subterranean. formation;
ramping-up air injection into the porous subterranean formation; and
creating a volume of compressed air at the peak of the porous subterranean formation.

US Pat. No. 9,170,342

ACTIVE ISOLATION APPARATUS

ConocoPhillips Company, ...

1. A vibratory seismic source for delivering acoustic energy into the ground for seismic prospecting, the source comprising:
a) a chassis;
b) a generator for creating electric power mounted to the chassis;
c) about 100 to 5,000 linear motors arranged in a grid, carried by a frame, and positioned to depend from the chassis and
wherein each linear motor includes a rod that is arranged to move generally vertically to contact the ground with a lower
end of the rod;

d) a control system for controlling movement of the rods such that the rods vibrate the ground and deliver acoustic energy
into the ground; and

e) an active isolation system arranged between the grid of linear motors and the chassis for absorbing at least a portion
of the acoustic energy that is created by the linear motors and preventing the acoustic energy from conveying excessive vibration
to the chassis and other portions of the seismic source.

US Pat. No. 9,458,709

HEAVY OIL PRODUCTION WITH EM PREHEAT AND GAS INJECTION

ConocoPhillips Company, ...

1. An improved gas injection oil recovery process comprising one or more producer wells and one or more gas injector wells,
wherein injection of a gas into said gas injector wells drives oil towards said one or more producer wells for production
of said oil, the improvement comprising preheating said oil with electromagnetic radiation so as to provide fluid communication
between said producer well and said injection well before said gas injection; wherein said electromagnetic energy is provided
by RF generator coupled via transmission lines to one or more antennae placed downhole in an oil reservoir, wherein at least
one of said one or more antennae is located between wells, and wherein said gas is selected from the group consisting of air,
CO2, N2, methane, ethane, propane, butane, flue gas and combinations thereof, and wherein said injected gas remains in the reservoir
for the duration of the oil recovery process.

US Pat. No. 9,255,446

PRE-POSITIONED CAPPING DEVICE FOR SOURCE CONTROL WITH INDEPENDENT MANAGEMENT SYSTEM

ConocoPhillips Company, ...

1. A system with a pre-positioned capping device attached to a wellhead for a drilling rig, comprising:
at least one blind shear ram;
an independent power source to operate the ram without relying on rig power;
an independent management system offsite of the rig and that receives wellbore data from an independent control system and
sends command signals to the independent control system in order to actuate the ram without use of the rig; and

a first transducer connected to the pre-positioned capping device by a cable and disposed to facilitate communication between
the independent management system and the independent control system should access to the rig be restricted, wherein placement
of the first transducer is at a greater distance away from the pre-positioned capping device than a second transducer in communication
with a rig control system.

US Pat. No. 9,458,701

VOCAL DRILLING ALARM NOTIFICATION

ConocoPhillips Company, ...

1. An automated system for controlling operations within an oil and gas wellbore, said system comprising:
a. a processor at or near a wellpad, said processor operably connected to a speaker;
b. a wellbore at said wellpad, said wellbore equipped with a plurality of sensors;
c. said sensors operably connected to said processor;
d. said processor analyzing data from said sensors and predicting when a hazard is about to occur;
e. said speaker providing a speech based warning when said hazard is predicted.

US Pat. No. 9,121,636

CONTAMINANT REMOVAL SYSTEM FOR CLOSED-LOOP REFRIGERATION CYCLES OF AN LNG FACILITY

ConocoPhillips Company, ...

1. A process for removing a contaminant from a refrigerant employed in a closed-loop refrigeration cycle of a liquefied natural
gas facility, the process comprising:
withdrawing a first portion of the refrigerant following at least one expansion of the refrigerant in the closed-loop refrigeration
cycle;

withdrawing a second portion of the refrigerant in a predominantly liquid phase and upstream of the at least one expansion
of the first portion of the refrigerant in the closed-loop refrigeration cycle;

separating via a distillation column the first portion of the refrigerant into a contaminant-rich bottom stream and a contaminant-depleted
overhead stream, wherein the distillation column includes a first indirect heat exchanger for heating liquids of the first
portion of the refrigerant in a lower area of the distillation column using the second portion of the refrigerant and a second
indirect heat exchanger for cooling vapors of the first portion of the refrigerant in an upper area of the distillation column
using a cooled stream formed by expansion of the second portion of the refrigerant upon exiting the first indirect heat exchanger;

expanding the overhead stream to form a cooled contaminant-depleted stream; and
introducing the cooled stream upon exiting the second indirect heat exchanger and the cooled contaminant-depleted stream back
into the closed-loop refrigeration cycle.

US Pat. No. 9,518,463

CORE CAPTURE AND RECOVERY FROM UNCONSOLIDATED OR FRIABLE FORMATIONS AND METHODS OF USE

ConocoPhillips Company, ...

1. A method for obtaining a core sample from a friable or unconsolidated formation comprising the steps of:
drilling a core sample from a borehole that intersects the friable or unconsolidated formation;
circulating a drilling fluid in the borehole while drilling the core sample, wherein the drilling fluid comprises a solid
particulate loss prevention material having an average size range from 100 mesh (about 150 microns) to 18 mesh (about 1,000
microns); maintaining an overpressure of at least about 200 psi to about 1200 psi; capturing and recovering the core sample
from the unconsolidated formation; wherein the step of maintaining the overpressure is performed during the steps of drilling
the core sample, circulating the drilling fluid, and recovering the core sample; wherein the step of drilling is limited to
a rate of penetration of a rate less than that which would fluidize the core sample at the overpressure; and wherein the step
of circulating further comprises the step of circulating a drilling fluid in the borehole at a flow rate of less than about
150 gpm.

US Pat. No. 9,158,016

MULTI-DIMENSIONAL DATA RECONSTRUCTION CONSTRAINED BY A REGULARLY INTERPOLATED MODEL

ConocoPhillips Company, ...

1. A process for overcoming aliasing in a minimum weighted norm interpolation (MWNI) technique, the process comprising:
computing, by a processor, an initial, regularly interpolated model;
computing a plurality of initial spectral weights using the initial, regularly interpolated model;
converting the initial, regularly interpolated model into a frequency domain, and, unknown spectral weights Pk in x?=|(THT+?F?1|Pk|?2F)?1THd, a from frequency data at each frequency slice of the initial, regularly interpolated model using Fourier transform, wherein
? is a weighing factor controlling tradeoff between model norm and misfit of observations, H is a conjugate transpose operator,
xH is a conjugate transpose of x, F is a multi-dimensional forward Fourier transform, F?1 is a multi-dimensional inverse Fourier transform, and x? is a least-squared solution with a minimum weighted norm (MWNI) to
recover missing data; wherein the process results in reducing aliasing artifacts and improving reconstruction of multi-dimensional
data regularization from otherwise irregular data.

US Pat. No. 9,850,425

DELAYED GELLING AGENTS

ConocoPhillips Company, ...

1. A delayed gelation composition, comprising a degradable polymeric cage, and having within said cage a gelation agent, wherein
said polymer comprises one or more monomers and is crosslinked with a labile crosslinker to form said degradable polymeric
cage, wherein the monomer comprises sodium AMPS and the labile crosslinker comprises a polyethylene glycol diacrylate and
the gelation agent comprises chromium and polyethyleneimine.
US Pat. No. 9,612,204

MEASUREMENT OF SCALE INHIBITOR IN WATER SYSTEMS

ConocoPhillips Company, ...

1. A method for determining a concentration of a scale inhibitor in a water system, the method comprising:
contacting a sample of water containing scale inhibitor with a dye in a capillary channel to form a complex effective to generate
fluorescence;

measuring a fluorescence signal generated by the complex; and
determining a concentration of the scale inhibitor based on the fluorescence signal.

US Pat. No. 9,447,336

REMOVING MERCURY FROM CRUDE OIL USING A STABILIZER COLUMN

ConocoPhillips Company, ...

1. A method of removing mercury from crude oil having various forms of mercury, comprising
a) feeding a crude oil comprising various forms of mercury into a stabilization column at a predetermined flow rate;
b) heating said crude oil comprising mercury for a first time period in said stabilization column to at least 100° C. and
less than 350° C. until at least 70 wt % of the various forms of mercury are converted to elemental mercury;

c) converting the elemental mercury to gaseous elemental mercury; and
d) removing the gaseous elemental mercury.

US Pat. No. 9,316,081

WELL CAPPING ASSEMBLY AND METHOD OF CAPPING UNDERWATER WELL

ConocoPhillips Company, ...

1. A method of capping an underwater well comprising:
deploying a capping structure into a body of water at an offset position from the underwater well;
floating the capping structure with at least one buoyancy tank;
submerging the capping structure;
positioning the capping structure over the underwater well after the submerging, wherein the deploying and the positioning
utilize first and second vessels attached to the capping structure with a plurality of mooring lines and the vessels remain
on opposing sides offset from directly over the well to avoid placement of the mooring lines, the vessels and the capping
structure at a surface of the body of water directly above the well throughout the deploying and the positioning;

rigidly anchoring the capping structure to a sea floor surface;
maneuvering a well cap structure in at least one direction with a capping frame that is operatively coupled to the capping
structure; and

capping a fluid flow from the underwater well upon operatively coupling the well cap structure to a wellhead structure.

US Pat. No. 9,644,137

METHOD OF CRYOGENIC ACID FRACKING

ConocoPhillips Company, ...

12. An improved method of acid fracturing a carbonate-rich reservoir, wherein acid is injected into a partially fractured
reservoir and etches and enlarges said partial fractures, thus stimulating production of a fluid from said reservoir, the
improvement comprising injecting a cryogenic liquid and an at least 15% acid in water into said partially fractured reservoir,
such that the cryogenic liquid reduces the reaction rate of said acid, allowing said acid and said cryogenic liquid to penetrate
deeper into said reservoir than 15% acid without said cryogenic liquid could penetrate, thus enlarging said partial fractures
deeper in said reservoir, thus stimulating increased production of said fluid from said reservoir.

US Pat. No. 9,254,893

SUBSEA PLATFORM TRANSPORTER (SPT)

ConocoPhillips Company, ...

15. A method of transporting and submerging a fully integrated and tested subsea system, the method comprising:
assembling a plurality of sub-systems on a platform to form a fully integrated subsea system on shore;
testing the fully integrated subsea system on shore;
towing the fully integrated subsea system across a body of water to a location above the sea floor;
submerging a subsea system transporter coupled to the fully integrated subsea system;
depositing the fully integrated subsea system on the sea floor;
releasing the subsea system transporter from the fully integrated subsea system deposited on the sea floor; and
returning the subsea system transporter to a semi-submerged state for towing.

US Pat. No. 9,164,184

RECIPROCAL METHOD TWO-WAY WAVE EQUATION TARGETED DATA SELECTION FOR SEISMIC ACQUISITION OF COMPLEX GEOLOGIC STRUCTURES

ConocoPhillips Company, ...

1. A process for selecting source and receiver locations in a seismic survey to provide information about a prospect that
exists within or near structures that obscure or complicate seismic imaging, where the process comprises:
a) constructing a first geologic model including information about the size, shape and depth of the obscuring or complicating
structure along with a prospect location for further understanding;

b) identifying the potential seismic acquisition geometry, source and receiver locations, to be evaluated with the geologic
model;

c) selecting a target on a geologic body for evaluation wherein the target may comprise a portion or an entirety of the prospect
location;

d) selecting parameters appropriate for a two-way wave equation propagation of energy;
e) computing two-way wave equation modeling for the wave propagation from the target point sources to the acquisition source
and receiver locations;

f) from e) computing, using reciprocity, the energy arriving at the target from a selected acquisition source location and
the associated attributes of the arriving energy at the target;

g) from e) computing, using reciprocity, the wavefield from the target to the receivers associated with the selected acquisition
source by a specific acquisition geometry;

h) from g) computing the energy and the associated attributes received by the receivers associated with the selected source
by a specific receiver geometry;

i) repeat steps f) through h) for other sources in a specific acquisition geometry;
j) from the energy and attributes recorded in step f) create attribute displays that provide visual perspective of one or
more attributes of the energy propagated to the target from one or more acquisition sources;

k) from the energy and attributes computed in step h) create attribute displays that provide visual perspective of one or
more attributes of the energy associated with one or more acquisition sources propagated from the target to the receivers;

l) analyze the attribute displays in step j) and step k) to determine the acquisition source-receiver pair information that
will provide better imaging of the target; and

m) acquiring seismic data with sources and receivers located using the acquisition source/receiver pair data identified in
step l).

US Pat. No. 9,139,760

CROSSLINKED SWELLABLE POLYMER

ConocoPhillips Company, ...

1. A method of increasing the recovery of hydrocarbon fluids in a subterranean formation comprising injecting into the subterranean
formation a composition comprising water, an unreacted tertiary crosslinker, and a highly cross linked expandable hydrophilic
polymer particle, wherein:
i) said polymer particle has an unexpanded volume average particle size diameter of 0.05-10 microns and a crosslinker content
of about 9,000-200,000 ppm of labile crosslinker and about greater than 0 to 300 ppm of stable crosslinker,

ii) said polymer particle has a smaller diameter than the pores of the subterranean formation, and
iii) said labile crosslinkers break under the conditions of temperature and pH in the subterranean formation to allow the
polymer particle to expand and said tertiary crosslinker then reacts with said polymer to form a stable gel.

US Pat. No. 9,377,239

DUAL-REFLUXED HEAVIES REMOVAL COLUMN IN AN LNG FACILITY

ConocoPhillips Company, ...

1. A method comprising:
cooling a predominantly methane stream in a refrigeration cycle to form a cooled predominantly methane stream;
separating the cooled predominantly methane stream in a first distillation column to produce a first bottoms stream, a first
overhead stream, and a predominately liquid bottoms stream, wherein the first bottoms stream, the first overhead stream and
the predominantly liquid bottoms stream are separate streams upon expulsion from the first distillation column, wherein the
first bottoms stream and the predominantly liquid bottoms stream are each routed from the first distillation column to a heat
exchanger;

introducing a first reflux stream comprising at least about 85 mole percent methane into the first distillation column; and
heating the predominantly liquid bottoms stream in the heat exchanger to provide an at least partially vaporized stream, which
is introduced into the first distillation column;

heating the first bottoms stream in the heat exchanger before being introduced into a second distillation column;
separating the first bottoms stream in the second distillation column to withdrawal a natural gas liquids stream and produce
a second overhead stream;

dividing the second overhead stream into first and second portions;
cooling the second portion of the second overhead stream in the heat exchanger via indirect heat exchange with the first bottoms
stream and the predominantly liquid bottoms stream to produce a two-phase stream;

separating vapor and liquids of the two-phase stream in a separator;
introducing the liquids from the separator as a second reflux stream into the first distillation column at a lower elevation
than the first reflux stream; wherein the second reflux stream is introduced into the first distillation column at a lower
elevation than the cooled predominantly methane stream;

combining the vapor from the separator with the first portion of the second overhead stream to provide a heavies removal zone
exit stream; and

combining the heavies removal zone exit stream with a methane-rich vapor stream to provide a combined methane compressor inlet
stream, which is routed to a methane compressor.

US Pat. No. 9,335,091

NITROGEN REJECTION UNIT

ConocoPhillips Company, ...

1. A method of removing nitrogen from a natural gas stream comprising:
(a) routing the natural gas stream from a methane cold box of a main liquefaction process to a nitrogen rejection unit comprising:
a first distillation column, a second distillation column, a third distillation column, and a condenser, wherein the main
liquefaction process comprises: one or more refrigeration cycles external to the nitrogen rejection unit;

(b) at least partially condensing the natural gas stream via the condenser, wherein the condenser utilizes a refrigerant used
to transfer heat in the one or more refrigeration cycles to form a condensed natural gas stream, wherein the refrigerant is
taken from the refrigeration cycle routed into a core-in-shell exchanger forming the condenser and returned to the refrigeration
cycle without passing through the first distillation column; and

(c) routing at least a portion of the condensed natural gas stream to the third distillation column to separate the at least
a portion of the condensed natural gas stream into a third top fraction and a third bottom fraction, wherein the third top
fraction comprises a predominantly nitrogen gas stream.

US Pat. No. 9,279,314

HEAT FRONT CAPTURE IN THERMAL RECOVERY SIMULATIONS OF HYDROCARBON RESERVOIRS

ConocoPhillips Company, ...

1. A method of dynamic reservoir simulation comprising:
a) partitioning, via a computing processor, a reservoir geometry into one or more grid-blocks in 1D, 2D or 3D space;
b) assigning fluid and rock properties to one or more grid-blocks;
c) assigning boundary conditions and well properties to one or more grid-blocks;
d) solving pressure, material balance, and energy balance equations wherein the pressure equation and material balance equation
are solved by finite difference (FD) method and the energy balance equation is solved by discontinuous Galerkin (DG) method
to determine temperature of the one or more grid-blocks; and

e) simulating fluid flow across one or more grid-blocks by using results from the solved pressure, material balance, and energy
balance equations.

US Pat. No. 9,244,183

FRACTURE CHARACTERIZATION FROM REFRACTION TRAVEL TIME DATA

ConocoPhillips Company, ...

1. A method to identify fractures in a hydrocarbon reservoir comprising:
transmitting one or more seismic source signals into the earth;
receiving one or more seismic signals at two or more geophones;
recording source-receiver records to a computer processor comprising a user interface and a storage medium;
pre-processing each pair of source-receiver records for each azimuth around one or more common source signals, including:
applying linear move-out,
removing dipping signals,
extracting refraction travel time, and
removing linear move-out;
deriving anisotropic parameters from refraction travel time; and
correlating changes in anisotropic parameters to one or more reservoir models.

US Pat. No. 9,091,158

PROCESSING OIL FROM STEAM ASSISTED PRODUCTION

ConocoPhillips Company, ...

12. A method, comprising:
mixing a polymeric flocculant with products recovered from a wellbore and while still above 100° C., wherein particles suspended
in hydrocarbons of the products agglomerate due to the flocculant and are transferred to an aqueous phase of the products
and wherein the products are recovered without relying on emulsification of the hydrocarbons and the aqueous phase; and

separating the aqueous phase from the hydrocarbons, which have the particles removed to facilitate further processing of the
hydrocarbons.

US Pat. No. 9,303,867

DUAL-PRESSURE FIXED BED CHEMICAL LOOPING PROCESS FOR ENHANCED OIL RECOVERY

ConocoPhillips Company, ...

1. A fixed-bed chemical looping combustion process for generating heat and carbon dioxide for enhanced oil recovery from a
subterranean formation comprising the steps of:
(a) providing a plurality of reactors, wherein each of the plurality of reactors comprises an oxygen carrier agent in a fixed
bed, wherein the plurality of reactors comprise a first reactor and a second reactor, wherein the oxygen carrier agent of
the first reactor is substantially depleted of oxygen, wherein the oxygen carrier agent of the second reactor is substantially
enriched in oxygen;

(b) introducing a gas mixture to the first reactor, wherein the gas mixture comprises oxygen;
(c) allowing the oxygen carrier agent of the first reactor to oxidize and preferentially retain oxygen from the gas mixture
to form an oxygen-depleted gas mixture;

(d) allowing the oxygen-depleted gas mixture to exit the first reactor;
(e) introducing the oxygen-depleted gas mixture to a heat recovery device;
(f) introducing a hydrocarbon fuel to the second reactor;
(g) allowing the hydrocarbon fuel to be oxidized by oxygen from the oxygen carrier agent of the second reactor to form a combusted
output stream, wherein the combusted output stream comprises carbon dioxide and steam;

(h) allowing the combusted output stream to exit the second reactor;
(i) separating the steam from the combusted output stream to form a substantially dry combusted output stream;
(j) allowing the oxygen carrier agent of the first reactor to become enriched with oxygen while allowing the oxygen carrier
agent of the second reactor to become depleted with oxygen;

(k) repeating steps (b)-(j) with the first reactor substituted in place of the second reactor and the second reactor substituted
in place of the first reactor;

(l) repeating steps (b)-(j);
(m) repeating steps (k) and (l) a plurality of times; and
wherein the first reactor is operated at a pressure above at least about 700 psi when the first reactor is used to oxidize
the hydrocarbon fuel and wherein the second reactor is operated at a pressure above at least about 700 psi when the second
reactor is used to oxidize the hydrocarbon fuel.

US Pat. No. 9,291,728

CONTINUOUS SEISMIC ACQUISITION

ConocoPhillips Company, ...

1. A process for acquiring seismic data in a seismic survey comprising a large plurality of shot points and a large plurality
of receiver points wherein multiple sweep-style seismic sources are arranged such that each source is positioned at a separate
shot point and the sources are delivering seismic energy into the earth concurrently while receivers are arranged to record
seismic signals reflected back from the earth to the surface to create a composite data record of energy from the sources
and wherein the process includes the sources delivering at each shot point at least the number of sweeps of seismic energy
as there are sources that are commonly delivering seismic energy into the earth used in the survey where the sweeps are delivered
continuously with no listen time between each sweep, and further wherein a pseudo listen time is created in the composite
data record using a frequency band pass filter based method, where a frequency band pass filter is designed to attenuate the
frequencies of the next activated sources activated during the pseudo listen time and said band pass filter is applied to
the pseudo listen time to attenuate the contaminating energy.

US Pat. No. 9,134,456

ELECTRICAL METHODS SEISMIC INTERFACE BOX

ConocoPhillips Company, ...

1. An apparatus for mapping the geometry of a fracture comprising:
a. a housing;
b. at least one input connector forming part of the housing coupled to at least one sensor that measures data selected from
the group consisting of: electrical, gravimetric, magnetic, and any combination thereof;

c. a data output connector forming part of the housing coupled to a seismic data recorder; and
d. a circuit disposed in the housing for convening the data from the sensor to be recorded by the seismic data recorder, wherein
the circuit converts an electrical signal to a voltage based signal, wherein impedance and reactance balance the voltage based
signal such that the voltage based signal is within sensitivity range of the sensor.

US Pat. No. 10,113,946

ROCK WETTABILITY DETERMINATIONS

CONOCOPHILLIPS COMPANY, ...

1. A method of assessing wettability of a reservoir rock, comprising:a) obtaining a first sample of a reservoir rock from a reservoir and cleaning said first sample;
b) saturating said first sample with a mineral oil or alkane and performing a first imbibition experiment;
c) plotting a first oil recovery plot against dimensionless time or square root of time;
d) obtaining a second sample of said reservoir rock that contains oil and water in a natural state and performing a second imbibition experiment;
e) plotting a second oil recovery plot against dimensionless time or square root of time;
f) obtaining a third sample of said reservoir rock and cleaning said third sample;
g) saturating said third sample with the crude oil of said reservoir and performing a third imbibition experiment;
h) plotting a third oil recovery plot against dimensionless time or square root of time;
i) adjusting said first, second and third oil recovery plots to a y intercept of zero; and
j) estimating the slopes of the adjusted first (m1), second (m2) and third (m3) oil recovery plots;
k) calculating a wettability index using:
wettability index=mx/(mvsww+mow)
 where mx is the slope of the imbibition curve from the core sample of interest m1, m2, or m3, mvsww is the slope of the imbibition curve of a Very Strongly Water-Wet (VSWW) core sample and mow is the slope of the imbibition curve of an oil-wet (ow) core sample.

US Pat. No. 9,846,248

SEISMIC DATA ACQUISITION USING DESIGNED NON-UNIFORM RECEIVER SPACING

ConocoPhillips Company, ...

1. A method of acquiring seismic data comprising the steps of:
a. deploying receivers in a survey area wherein each receiver is laterally spaced from one another in two horizontal directions
wherein the lateral spacing in at least one horizontal direction is deliberately non-uniform, wherein the receivers are not
aligned in at least one of the two horizontal directions and wherein the spacing between any two seismic receivers in the
deliberately non-uniform direction varies by a distance of at least five percent between the largest spacing and smallest
spacing;

b. identifying seismic source points within the survey area;
c. directing seismic energy into the ground at the source points and recording reflected and/or refracted seismic data with
the deployed seismic receivers;

d. recovering the measured data from the deployed seismic receivers; and
e. reconstructing the wavefield from the recovered data.

US Pat. No. 9,817,145

DOWNHOLE INERTIAL MASS SYSTEM

ConocoPhillips Company, ...

1. A downhole inertial mass seismic-source system for use within a wellbore to provide seismic signal energy at a wellbore
location, the system comprising:
a first inertial mass apparatus with a fluid plunger that is in contact with a first wellbore fluid chamber and a second wellbore
fluid chamber;

a second inertial mass apparatus with a fluid plunger in contact with the first well bore fluid chamber;
a third inertial mass apparatus with a fluid plunger in contact with the second well bore fluid chamber, wherein the first
or second well bore fluid chamber is a waveguide for generation of pressure waves;

an Inertial Mass Control System (IMCS) connected to the first inertial mass apparatus, and
a power source providing power to the Inertial Mass Control System.

US Pat. No. 9,347,270

PRE-POSITIONED CAPPING DEVICE AND DIVERTER

ConocoPhillips Company, ...

1. A pre-positioned capping and diverter assembly, comprising:
at least one blind shear ram disposed between a wellhead and a blowout preventer stack;
a control system that sends wellbore data offsite of a platform with a rig coupled for drilling through the wellhead and actuates
the ram without use of the platform and rig upon receiving command signals from offsite of the platform and rig;

a conduit coupled to receive flow from the wellhead and output the flow to a location offset in a lateral direction from the
platform and rig with the ram actuated to close a fluid pathway to the platform and rig; and

a first transducer connected to the control system by a cable and disposed to facilitate receiving the command signals from
offsite of the platform and rig should access to the rig be restricted, wherein placement of the first transducer is at a
greater distance away from the control system than a second transducer connected to the control system and in communication
with a rig controller.

US Pat. No. 9,366,091

DECOMMISSIONING OFFSHORE OIL AND GAS WELLS

ConocoPhillips Company, ...

1. A method for decommissioning an offshore oil or gas platform, comprising the steps of:
a) providing a jack up rig, the jack up rig being equipped with one or more of an accommodation block, drilling mud supply
and power supply, wherein the jack up rig has a cantilever structure extending over a side of the jack up rig, on which structure
is mounted a first decommissioning rig tower;

b) maneuvering the jack up rig alongside the platform such that the cantilever and first decommissioning rig tower overlie
a first well within a well bay of the platform;

c) installing on the platform a second decommissioning rig tower overlying a second well in the well bay of the platform;
and

d) operating simultaneously the first and second decommissioning rig towers and associated equipment with one or more of power,
drilling mud and operator personnel from or housed on the jack up rig.

US Pat. No. 9,279,896

RECIPROCAL METHOD TWO-WAY WAVE EQUATION TARGETED DATA SELECTION FOR IMPROVED IMAGING OF COMPLEX GEOLOGIC STRUCTURES

ConocoPhillips Company, ...

1. A process for imaging seismic data for a prospect that exists within or near structures that obscure or complicate seismic
imaging, where the process comprises:
a) constructing a first geologic model including information about the size, shape and depth of the obscuring or complicating
structure along with a prospect location for further understanding;

b) identifying a set of seismic source locations within the seismic data along with seismic acquisition geometry for associated
seismic receiver locations to be evaluated with the geologic model;

c) selecting a target on a geologic body for evaluation wherein the target may comprise a portion or an entirety of the prospect
location;

d) selecting parameters appropriate for a two-way wave equation propagation of energy;
e) computing two-way wave equation for the wave propagation from the target point sources to the acquisition source and receiver
locations;

f) from e) computing, using reciprocity, the energy arriving at the target from a selected acquisition source location and
the associated attributes of the arriving energy at the target from the selected acquisition source location;

g) from e) computing, using reciprocity, the wavefield from the target to the receivers associated with the selected acquisition
source by the acquisition geometry;

h) from g) computing the energy and the associated attributes received by the receivers associated with the selected source
by the acquisition geometry;

i) repeating steps f) through h) for other sources in the selected acquisition geometry;
j) from the energy and attributes recorded in step f) creating attribute displays that provide visual perspective of one or
more attributes of the energy propagated to the target from one or more acquisition sources;

k) from the energy and attributes computed in step h) creating attribute displays that provide visual perspective of one or
more attributes of the energy associated with one or more acquisition sources propagated from the target to the receivers;

l) analyzing the attribute displays in step j) and step k) to determine the acquisition source/receiver pair information that
will provide better imaging of the target; and

m) creating one or more geological images of the substructure using the acquisition source/receiver pair data identified in
step l).

US Pat. No. 9,267,367

METHOD FOR STEAM ASSISTED GRAVITY DRAINAGE WITH PRESSURE DIFFERENTIAL INJECTION

ConocoPhillips Company, ...

5. A method for producing hydrocarbons in a subterranean formation having at least two well pairs comprising:
a. installing a highest pressure well pair in the subterranean formation, wherein the highest pressure well pair includes
a first injection well and a first production well;

b. installing a lowest pressure well pair in the subterranean formation, wherein the lowest pressure well pair includes a
final injection well and a final production well;

c. applying a considerable pressure differential across the highest pressure well pair and the lowest pressure well pair;
d. injecting steam into the first injection well to form a first steam chamber;
e. injecting steam into the final injection well to form a final steam chamber;
f. monitoring the steam chambers until they merge into a final steam chamber;
g. ceasing the flow of steam into the first injection well; and
h. injecting steam into the final injection well to maintain a final steam chamber.

US Pat. No. 9,574,140

REMOVING MERCURY FROM CRUDE OIL

ConocoPhillips Company, ...

1. A method of removing mercury from crude oil, consisting of:
a) heating crude oil comprising mercury in various forms to at least 100° C. and less than 350° C. until at least 95 wt %
of the mercury in various forms is converted to elemental mercury;

b) converting the elemental mercury to gaseous elemental mercury; and
c) removing the gaseous elemental mercury.

US Pat. No. 9,121,155

ICE RESISTANT JACKUP LEG

ConocoPhillips Company

1. An ice resistant jackup leg for being employed in a jackup offshore platform, comprising:
a plurality of chords;
a plurality of outer plate structures, wherein the chords and outer plate structures are alternatively positioned so that
the outer plate structures connect the chords to form an enclosed structure of the ice resistant jackup leg throughout the
portion of the leg in contact with water and ice;

a plurality of longitudinal stiffeners, wherein the longitudinal stiffeners are disposed onto the inner surface of the outer
plate structures for stiffening the outer plate structures; and

a plurality of traverse web frames or girders, wherein the traverse web frames or girders are disposed onto the inner surface
of the outer plate structures for supporting the plurality of longitudinal stiffeners.

US Pat. No. 9,921,322

SEGMENTED BASE PLATE SEISMIC SWEEPS

CONOCOPHILLIPS COMPANY, ...

1. A method of generating waves for a seismic survey, said method comprising:
a) providing a vibrator having a segmented baseplate, said segmented baseplate having an array of independently controllable
base plate segments; and

b) differentially activating said base plates segments in a pattern across said array, so as to generate waves reflecting
said pattern.

US Pat. No. 9,170,343

QUASI-IMPULSIVE DISPLACEMENT SOURCE

ConocoPhillips Company, ...

1. A process for delivering a quasi-impulsive impact of band limited spectrum for a seismic prospecting operation, the process
comprising:
a) providing an electrically powered seismic source having about 100 to 5,000 linear electric motors carried by a frame, wherein
a ground contact element of the linear electric motor is provided in proximity with the ground; and

b) driving the ground contact elements of linear electric motors in a coordinated impulse against the ground to deliver a
single impulse against the ground and convey seismic energy into the earth that include a broad frequency spectrum for seismically
illuminating geophysical structures.

US Pat. No. 9,291,727

MULTIPLE FREQUENCY GEOPHONE STRINGS

ConocoPhillips Company, ...

1. A process for acquiring seismic data for prospecting for hydrocarbons comprising:
a) creating an array of receiver locations in the field where each receiver location includes a node;
b) providing at least a first and a second geophone connected to each node of the array of receiver locations where the first
and second geophones provide a composite signal of the vibrations sensed from the ground where the first geophone is configured
to have a first vibrational frequency sensitivity range and the second geophone is configured to have a second and different
vibrational frequency sensitivity range;

c) providing a third geophone at each node wherein the third geophone is configured to have a third and different vibrational
frequency sensitivity range; and

d) delivering seismic energy into the ground to create an upcoming seismic wave field to be sensed by the geophones at the
various receiver locations of the array.

US Pat. No. 9,217,796

SIMULTANEOUS COMPOSITE LAND SEISMIC SWEEP

ConocoPhillips Company, ...

1. A process for delivering a distinctive seismic signal or signature from a seismic source for a seismic prospecting operation,
the process comprising:
a) providing an electrically powered seismic source having about 100 to 5,000 linear electric motors carried by a frame, wherein
a ground contact element of each linear electric motor is provided in contact with the ground; and

b) driving the ground contact elements of the linear electric motors such that at least two of the plurality of linear motors
are deliberately and concurrently delivering different seismic signals against the ground thereby creating a composition of
all of the various signals where composition defines a distinctive composite signature of seismic energy conveyed into the
earth.

US Pat. No. 9,719,337

ACCELERATION OF HEAVY OIL RECOVERY THROUGH DOWNHOLE RADIO FREQUENCY RADIATION HEATING

ConocoPhillips Company, ...

1. A method for enhancing heavy oil recovery by accelerating downhole fluid communication through radio frequency radiation
heating comprising the steps of:
a) introducing a steam assisted gravity drainage (SAGD) well pair into a subterranean formation, wherein the SAGD well pair
comprises a producing well and a steam injection well, wherein the subterranean formation comprises a hydrocarbon reservoir
wherein the hydrocarbon reservoir comprises hydrocarbons;

b) introducing an infill producer well in proximity to the SAGD well pair, wherein an antenna extends along at least a portion
of the infill producer well, wherein the antenna is operably connected to an energy source;

c) inducing radio frequency radiation in the antenna by way of the energy source;
d) introducing steam into the steam injection well to establish a steam chamber in the hydrocarbon reservoir and allowing
the steam to continuously condense to form water;

e) using a horizontal cross well to extend at least one antenna in proximity to the toe of the at least one infill producer
well, wherein the horizontal cross well is substantially transverse to the infill producer well;

f) allowing the radio frequency radiation to propagate into the hydrocarbon reservoir to heat the water therein to accelerate
fluid communication between the steam chamber and the infill producer well; and

g) producing the hydrocarbons from the hydrocarbon reservoir through the infill producer well.

US Pat. No. 9,213,119

MARINE SEISMIC ACQUISITION

ConocoPhillips Company, ...

1. A method of acquiring and processing marine seismic data, said method comprising:
a) moving multiple seismic receivers through a body of water;
b) simultaneously with step (a), performing a series of periodic seismic sweeps including an initial seismic sweep and a subsequent
seismic sweep by simultaneously energizing at least two seismic sources and acquiring source seismic data and reflected seismic
data using multiple receivers, wherein the acquiring from the initial seismic sweep is collected by a first set of receivers
while the acquiring from the subsequent seismic sweep is collected by a second set of receivers, wherein the first set is
different from the second set;

c) reorganizing said source seismic data and/or said reflected seismic data based on common source-receiver centerpoints from
different seismic sweeps, thereby generating reorganized seismic data; and

d) source separating said reorganized seismic data.

US Pat. No. 9,371,694

PERMANENT BYPASS WHIPSTOCK ASSEMBLY FOR DRILLING AND COMPLETING A SIDETRACK WELL AND PRESERVING ACCESS TO THE ORIGINAL WELLBORE

ConocoPhillips Company, ...

1. A process for drilling a sidetrack wellbore from a tailpipe through a liner pipe and into a desired formation, wherein
the process comprises:
a. incorporating a permanent bypass whipstock assembly into a section of a length of a tailpipe, wherein said permanent bypass
whipstock assembly has an elongated generally cylindrical body, and within a middle section of said permanent bypass whipstock
assembly, a primary path and a deviating sidetrack path, wherein said primary path extends from a first end and a second end
and allowing complete access to production below the permanent bypass whipstock assembly; wherein said deviating sidetrack
path has a downhole end along a peripheral side of said permanent bypass whipstock assembly and a uphole end closer to the
first end of and open to said primary path of said permanent bypass whipstock assembly, wherein said tailpipe is releasably
connected to the first and second ends of the primary path; wherein said permanent bypass whipstock assembly has a larger
diameter than said tailpipe;

b. installing said permanent bypass whipstock and tailpipe into a production assembly;
c. introducing said production assembly inside a liner in a wellbore wherein said permanent bypass whipstock assembly is in
proximity to said liner eliminating the need for cement, wherein said primary path of said permanent bypass whipstock assembly
is slightly offset from an axis of said liner to create the larger diameter of the permanent bypass whipstock assembly as
compared to the tailpipe, wherein said deviating sidetrack path diverges from said primary path at an incline to ultimately
form the sidetrack wellbore, wherein the permanent bypass whipstock assembly reduces the clearance to no more than is necessary
to run an additional permanent bypass whipstock assembly, a packer assembly or combinations thereof into the liner;

d. positioning said production assembly into a wellbore with the deviating sidetrack path of the permanent bypass whipstock
assembly aligned in a predetermined direction for forming the sidetrack well which may later be drilled;

e. sealing said wellbore with said production assembly;
f. installing a diverter, wherein the diverter closes said primary path below the desired location of said sidetrack well,
wherein the diverter is installed independent of the permanent bypass whipstock assembly, wherein said diverter directs tools
from the primary path to said deviating sidetrack path, wherein the diverter is retrievable;

g. installing a milling system, wherein the milling system includes a milling bit at the downhole end of a drill string whereby
when the milling system reaches the diverter the milling system is deflected onto said deviating sidetrack path and continues
along the deviating sidetrack path whereby the milling system forms a window in the liner;

h. removing the milling system;
i. installing a drill system, wherein the drill system includes a drillbit located at the downhole end of a drill string,
wherein the drill system runs through the primary path and through the permanent bypass whipstock assembly whereby the drill
system is diverted onto the deviating sidetrack path by the diverter whereby the drill system reaches the window formed in
the liner by the milling system;

j. drilling a sidetrack wellbore with the drill system;
k. removing the drill system; and
l. installing a liner pipe casing into the sidetrack wellbore, wherein the liner pipe is run down said primary path and through
said permanent bypass whipstock assembly whereby said liner pipe is diverted onto the deviating sidetrack path by the diverter,
wherein the liner pipe casing substantially supports the formation exposed by the window,

wherein said permanent bypass whipstock assembly is permanently installed in said wellbore.
US Pat. No. 9,291,051

RESERVOIR PRESSURE TESTING TO DETERMINE HYDRATE COMPOSITION

ConocoPhillips Company, ...

1. An in-situ method for determining composition of a hydrate in a subterranean reservoir, the method comprising:
a. introducing a formation testing tool into the subterranean formation, wherein the formation testing tool controls pressure
around the tool and detects presence of fluids;

b. determining an initial fluid pressure at a point or interval within the subterranean reservoir, wherein the hydrate is
stable;

c. incrementally reducing the pressure at the point or interval within the subterranean reservoir until the reduction in pressure
leads to dissociation of the hydrate composition;

d. determining the pressure and temperature of the dissociation; and
e. determining the composition of the hydrate based on pressure temperature stability curves of hydrates.

US Pat. No. 9,239,220

DETERMINATION OF NEAR SURFACE GEOPHYSCIAL PROPERTIES BY IMPULSIVE DISPLACEMENT EVENTS

ConocoPhillips Company, ...

1. A process for measuring near surface properties of the ground for use in seismic prospecting, the process comprising:
a) providing a grid of linear motors arranged in a frame and oriented generally vertically such that each linear electric
motor includes a rod that in operation extends down to contact the ground with a lower end of the rod;

b) extending the rods with a constant force against the ground for a period of time and measuring electrical feedback at one
of more linear electric motor to create a feedback circuit;

c) measuring the rate of penetration for each rod into the ground;
d) measuring the overall deformation of the ground made by each rod; and
e) computing a viscosity and stiffness of the ground based on the rate of penetration and overall deformation measured.

US Pat. No. 9,115,575

INDIRECT DOWNHOLE STEAM GENERATOR WITH CARBON DIOXIDE CAPTURE

ConocoPhillips Company, ...

1. A method for enhancing heavy oil recovery from a subterranean formation comprising the steps of:
providing a first heat exchanger;
providing a combustion device;
providing a second heat exchanger;
situating the first heat exchanger, the combustion device, and the second heat exchanger downhole in a wellbore in the subterranean
formation at a depth below a permafrost zone wherein the depth is a sufficient distance from the permafrost zone to avoid
substantially thermally affecting the permafrost zone;

introducing water, a fuel, and an oxidant downhole to the combustion device;
combusting the fuel with the oxidant in the combustion device to form an exhaust gas, the exhaust gas comprising carbon dioxide;
introducing the exhaust gas and the water into the second heat exchanger;
allowing the exhaust gas to heat the water in the second heat exchanger to form steam;
allowing the exhaust gas to exit the second heat exchanger and to be introduced into the first heat exchanger;
allowing additional quantities of the water, the fuel, and the oxidant to enter the first heat exchanger and allowing the
additional quantities of the water, the fuel, and the oxidant to be preheated by the exhaust gas in the first heat exchanger;

allowing the steam to exit the second heat exchanger into the subterranean formation to heat any in-situ heavy oil to form
heated heavy oil;

recovering the heated heavy oil from the subterranean formation;
recovering the exhaust gas from the first exchanger to the surface without the exhaust gas being introduced into the subterranean
formation and introducing the exhaust gas into a carbon dioxide capture system;

separating a substantial portion of the carbon dioxide from the exhaust gas in the carbon dioxide capture system to form an
enriched carbon dioxide stream and a CO2-depleted stream; and

introducing a portion of the enriched carbon dioxide stream into the subterranean formation.

US Pat. No. 9,845,659

FUSIBLE ALLOY PLUG IN FLOW CONTROL DEVICE

ConocoPhillips Company, ...

1. A method for isolating flow within a wellbore comprising:
a) obtaining a plurality of flow control devices, wherein each flow control device includes at least one aperture formed therein,
wherein the aperture restricts hydraulic flow of fluids and wherein each flow control device includes an exclusion media to
exclude formation particulates,

b) inserting a temporary fusible alloy plug securely into said at least one aperture, wherein the temporary fusible alloy
plug temporarily prevents flow through said at least one aperture, wherein the temporary fusible alloy plug is fabricated
from any low melting temperature composition that is meltable at a melt temperature (Tm), such that a first type of flow control device has a plug that melts at Tm1 and a second type of flow control device has a plug that melts at Tm2, which is higher than Tm1;

c) installing the plurality of flow control devices into the well; and
d) increasing the reservoir temperature to Tm1 to selectively remove said temporary fusible alloy plug from said first type of flow control device when inflow through said
aperture is desired; and

e) increasing the reservoir temperature to Tm2 to selectively remove said temporary fusible alloy plug from said second type of flow control device when inflow through said
aperture is desired.

US Pat. No. 9,726,770

MULTIPLE ACTUATOR VIBRATOR

ConocoPhillips Company, ...

1. A seismic vibrator truck, having a baseplate comprising:
a) a plate body that is substantially planar and having a bottom surface and a top surface;
b) an array of load cells mounted near said bottom surface of the plate body so that the load cells can measure a plurality
of forces the baseplate applies to the ground;

c) a plurality of actuators mounted above the top surface of the plate body and capable of reversibly contacting said top
surface of said plate body;

d) a central processing unit (CPU) operably coupled to said actuators and said load cells;
wherein when a flexure in said plate body is detected by uneven forces measured by said load cells and said CPU controls the
actuation of said plurality of actuators to compensate for said flexure.

US Pat. No. 9,229,129

RESERVOIR GEOBODY CALCULATION

ConocoPhillips Company, ...

1. A method for calculating at least one theoretically connected region within a 3-d model, wherein the model comprises a
plurality of cells, each cell associated with a value of at least one property, the method comprising the steps of:
a) For each cell of the model, determining, using a computer, whether the value of the at least one property meets at least
one threshold criterion and flagging the cell as met if the cell meets the threshold criterion;

a1) Assigning, using the computer, one of the flagged cells to a geobody by assigning it a geobody identifier value of 1;
a2) For the assigned cell having the assigned geobody identifier value, creating in the computer, a temporary data store to
store all potential neighboring flagged cells;

a3) Identifying, using the computer, each neighboring cell of the assigned cell through a specified neighborhood window and
for each identified neighboring cell:

determining if the neighboring cell has been flagged as met and if so and if the neighboring cell has not yet been assigned
a geobody identifier value:

identifying it as connected to the geobody of the assigned cell and setting its geobody identifier value same as that of the
assigned cell;

adding the neighboring cell to the end of the temporary data store;
a4) Removing the top flagged cell from the temporary data store and treating it as the assigned cell;
a5) Repeating step a2) to a4) for each flagged cell that remains in the temporary data store until the temporary data store
is empty;

b) Checking, using the computer, each flagged cell of the model to determine if it has not yet been assigned a geobody identifier
value and if so, assigning a geobody by assigning a next geobody identifier value to the unassigned cell and performing steps
a2), a3), a4) and a5); and

e) Repeating step b) until all flagged cells in the model have been assigned a geobody identifier value.

US Pat. No. 10,508,515

METHOD AND APPARATUS FOR FILLING AN ANNULUS BETWEEN CASING AND ROCK IN AN OIL OR GAS WELL

CONOCOPHILLIPS COMPANY, ...

1. A process for plugging an annulus between casing and formation in a hydrocarbon wellbore, comprising:substantially equalizing pressure between the annulus and the interior of the casing;
placing the well in an underbalanced state without cycling;artificially promoting or inducing creep in the formation surrounding the casing; and plugging the annulus between casing and formation in a hydrocarbon wellbore.

US Pat. No. 10,093,848

DELAYED GELLING AGENTS

ConocoPhillips Company, ...

1. A composition comprising a polyelectrolyte complex nanoparticle comprising a polyalkylenimine of less than 2000 Da and a polyanion, said nanoparticle having a size of less than one micron, and wherein said polyelectrolyte complex nanoparticle is intimately associated with a multivalent cation crosslinker.

US Pat. No. 9,841,231

LNG FACILITY WITH INTEGRATED NGL RECOVERY FOR ENHANCED LIQUID RECOVERY AND PRODUCT FLEXIBILITY

ConocoPhillips Company, ...

1. A natural gas handling facility comprising:
a first distillation column comprising a first fluid inlet, a first vapor outlet, and a first liquid outlet;
a first heat exchanger defining a first heating pass and a first cooling pass, wherein said first heating pass defines a first
cool fluid inlet and a first warm fluid outlet, wherein said first cooling pass defines a first warm fluid inlet and a first
cool fluid outlet, wherein said first cool fluid inlet of said first heating pass is in fluid flow communication with said
first liquid outlet of said first distillation column;

a second heat exchanger defining a second heating pass and a second cooling pass, wherein said second heating pass defines
a second cool fluid inlet and a second warm fluid outlet, wherein said second cooling pass defines a second warm fluid inlet
and a second cool fluid outlet, wherein said first warm fluid outlet of said first heating pass is in fluid flow communication
with said second cool fluid inlet of said second heating pass;

an intermediate stage flash drum comprising a third fluid inlet, a third vapor outlet, and a third liquid outlet, wherein
said third fluid inlet is in fluid flow communication with said first liquid outlet of said first distillation column;

a second distillation column comprising a second fluid inlet, a second vapor outlet, and a second liquid outlet, wherein said
second fluid inlet of said second distillation column is in fluid flow communication with a composite stream formed from said
second warm fluid outlet of said second heating pass and said third liquid outlet of said intermediate stage flash drum,

wherein said second vapor outlet of said second distillation column is in fluid flow communication with said second warm fluid
inlet of said second cooling pass, and

wherein said first warm fluid outlet of said first heating pass is not in fluid flow communication with said first distillation
column.

US Pat. No. 9,488,047

RESERVOIR CALIBRATION PARAMETERIZATION METHOD

ConocoPhillips Company, ...

1. A method for creating an amended realization of a geostatistical model of a subterranean hydrocarbon reservoir, wherein:
a) said amended realization is based on a current realization of the model;
b) said current realization comprises at least one petrophysical parameter value for each of a plurality of volume cells;
and

c) a covariance matrix is associated with the model, wherein the covariance matrix contains information about variance and
statistical inter-dependence of estimated parameter value or values of the model; wherein the method comprises the steps of:

d) creating a plurality of further model realizations from random seeds;
e) creating an approximation matrix containing modified parameter values from said plurality of further model realizations,
wherein the approximation matrix comprises series of column vectors, each column vector corresponding to one realization,
wherein dimension of the approximation matrix is smaller than dimension of a true covariance matrix, wherein an updated parameter
value is calculated by subtracting an average value of the parameter from the parameter value;

f) deriving from the approximation matrix approximate eigenvectors and approximate eigen values which are approximations of
the eigenvectors and eigen values of the covariance matrix by performing singular value decomposition on the approximation
matrix;

g) using the approximate eigenvectors and approximate eigen values in a Karhunen-Loève expansion to derive one or more amended
realizations.

US Pat. No. 9,229,120

DISCRETE ELECTRIC SEISMIC SOURCE UNIT

ConocoPhillips Company, ...

1. A vibratory seismic source for delivering acoustic energy into the ground for seismic prospecting, the source comprising:
a) a chassis;
b) a generator for creating electric power mounted to the chassis;
c) about 100 to 5,000 linear motors arranged in a grid and carried by a frame wherein each linear motor includes a rod that
is arranged to move generally vertically to contact the ground with a lower end of the rod;

d) a control system for directing electricity from the generator and concurrently from the electric power accumulator to electrically
power movement and for controlling movement of the rods such that the rods vibrate the ground and deliver acoustic energy
into the ground;

e) a plurality of wheels on which to convey the source from location to location;
f) an active isolation system arranged between the grid of linear motors and the chassis for absorbing at least a portion
of the acoustic energy that is created by the linear motors and preventing the acoustic energy from conveying excessive vibration
to the chassis and other portions of the seismic source; and

g) at least one electrically powered motor to raise and lower the wheels for transiting around the survey area and adjust
for delivering acoustic energy into the ground.

US Pat. No. 9,164,186

ALTERNATIVE VIBRATOR ACTUATOR SOURCE

ConocoPhillips Company, ...

1. A vibratory seismic source for delivering acoustic energy into the earth for seismic prospecting, the source comprising:
a) a generator for creating electric power;
b) about 100 to 5,000 linear motors arranged in a grid and carried by a frame, wherein each linear motor includes a rod that
is arranged to move generally vertically to contact the ground with a lower end of the rod; and

c) a control system for controlling movement of the rods such that the rods vibrate the ground and deliver acoustic energy
into the ground.

US Pat. No. 9,637,978

DOWNHOLE STINGER GEOTECHNICAL SAMPLING AND IN SITU TESTING TOOL

ConocoPhillips Company, ...

1. An offshore system for in situ testing of soil comprising:
a) a carrier tube comprising an upper end and a lower end, wherein the carrier tube is characterized by an outer diameter
and an inner diameter and wherein the inner diameter of the carrier tube defines a hydraulic cylinder;

b) a landing sub shaped or installed at or near the upper end of the carrier tube, wherein an inner diameter of the landing
sub is smaller than the inner diameter of the carrier tube;

c) a drill bit shaped or installed at or near the lower end of the carrier tube;
d) a series of extension tubes extending upward from the upper end of the carrier tube;
e) an upward seal that seals a top portion of the extension tubes;
f) a compression system for introducing compressed fluid under the upward seal;
g) a fixed rod that runs through the hydraulic cylinder;
h) a hydraulic piston disposed in the hydraulic cylinder, wherein the hydraulic piston is moveable along the fixed rod;
i) one or more shear pins configured to restrict displacement of the hydraulic piston until a sufficient fluid pressure is
built up; and

j) an inner tube disposed between the carrier tube and the fixed rod, wherein a lower portion of the inner tube includes a
cone penetrometer that is ballistically inserted into the soil during downward displacement of the hydraulic piston.

US Pat. No. 9,254,894

FLOTABLE SUBSEA PLATFORM (FSP)

ConocoPhillips Company, ...

1. A method of installing a floatable subsea platform on a sea floor, comprising:
providing a subplatform base, a plurality of connectable modules with subsea equipment positioned on each module, and a buoyancy
system with at least one buoyancy tank operably connected to a buoyancy control assembly;

latching the plurality of connectable modules to the subplatform base;
towing the subplatform base with the plurality of connectable modules by a barge to a sea bottom oil site, wherein the buoyancy
system floats the subplatform in water during the towing after the latching;

wherein the subplatform base is placed in a moon pool of the barge and is hence disposed in water and surrounded by the barge
while being towed;

mooring a template to the sea floor at the sea bottom oil site;
lowering the subplatform base to the template using the buoyancy system; and
latching the subplatform base to the template.

US Pat. No. 9,249,652

CONTROLLED FRACTURE INITIATION STRESS PACKER

ConocoPhillips Company, ...

1. A method of selectively fracturing an underground formation traversed by a borehole, the method comprising:
a. inserting a suspended packer assembly into the borehole and setting the packer assembly in an open hole of the borehole;
b. setting the packer assembly in the borehole at a predetermined location so as to position the packer assembly adjacent
to the underground formation to be fractured by selectively anchoring said packer assembly so as to counteract stress cages
and to isolate a predetermined interval within the borehole by sealing an annulus in the borehole; and

c. introducing a fluid to the packer assembly to increase the pressure on the packer assembly until a fracture is initiated
adjacent to said packer assembly at said predetermined location, thus inducing a hydraulic fracture at an interface between
the packer assembly and the open hole.

US Pat. No. 9,133,699

ELECTRICAL METHODS FRACTURE DETECTION VIA 4D TECHNIQUES

ConocoPhillips Company, ...

1. A method for acquiring and evaluating geometry of a well comprising:
a. deploying at least one grid of geophysical sensors, wherein the at least one grid of the sensors is deployed in a 2D or
3D configuration;

b. acquiring a baseline geophysical survey of geophysical parameters of the well;
c. fracturing the well to create a fracture;
d. injecting an electrically active proppant into the fracture, wherein the electrically active proppant is characterized
by self-potential upon contact with an activating subterranean fluid;

e. introducing an activating subterranean fluid into the fracture to activate the self-potential of the electrically active
proppant;

f. continuously acquiring a geophysical survey of the self-potential of the electrically active proppant during the fracturing;
and

g. acquiring a final geophysical survey of geophysical parameters of the fracture upon completion of the fracturing.

US Pat. No. 10,386,516

TIME-LAPSE 4D SCATTERING FOR IMAGING HYDRAULICALLY INDUCED FRACTURES

CONOCOPHILLIPS COMPANY, ...

1. A computer-implemented method for characterizing an induced fracture in a subterranean formation comprising:obtaining scattered wavefield data corresponding to a first seismic survey and a second seismic survey, the scattered wavefield data detected using at least one sensor;
obtaining azimuth stacks on the first seismic survey and the second seismic survey;
creating time-lapse azimuth stacks between corresponding azimuth stacks in the first seismic survey and the second seismic survey;
creating new traces with root mean square energy in a moving time window on the time-lapse azimuth stacks;
for each of one or more time samples on the new traces, identifying a lowest root mean square energy and a highest root mean square energy for the time-lapse azimuth stacks;
determining a threshold for a difference between the highest root mean square energy and the lowest root mean square energy;
identifying any of the one or more time samples that exceeds the threshold;
for each of the one or more time samples that exceeds the threshold, recording an azimuth with a largest overall root mean square energy; and
determining a direction of the induced fracture, wherein the azimuth with the largest overall root mean square energy identifies the direction of the induced fracture.

US Pat. No. 10,287,864

NON-CONDENSABLE GAS COINJECTION WITH FISHBONE LATERAL WELLS

CONOCOPHILLIPS COMPANY, ...

1. A process for producing hydrocarbons where the process comprises:a) a reservoir having interbedded layers;
b) a horizontal wellpair comprising an injection well and a wellpair production well;
c) one or more infill production wells comprising two or more fishbone ribs drilled laterally from the infill production well to the wellpair production well;
d) initially injecting steam through said injection well;
e) establishing thermal communication between the thermal chamber and one or more infill production wells;
f) switching to non-condensable gas (NCG) and steam injection; and
g) producing hydrocarbons.

US Pat. No. 9,970,275

EM AND COMBUSTION STIMULATION OF HEAVY OIL

ConocoPhillips Company, ...

1. A method of producing heavy oil, comprising:a. providing an air injection borehole and a production borehole in a reservoir comprising heavy oil;
b. providing an antenna operably connected to a power source in said air injection borehole or said production borehole or both boreholes;
c. heating said heavy oil with electromagnetic (EM) radiation via said antenna until said air injection borehole and said production borehole are in fluid communication;
d. injecting air into said air injection borehole;
e. igniting and allowing a combustion front to mobilize said heavy oil; and
f. producing said mobilized heavy oil from said production borehole.

US Pat. No. 9,926,776

CHARACTERIZATION OF WHIRL DRILLING DYSFUNCTION

CONOCOPHILLIPS COMPANY, ...

1. A method of determining a whirl attribute of a drill string, comprising:estimating centers of rotation on the drill string based on acceleration sensed per revolution for each of the centers being estimated, wherein the estimating of the centers includes transforming the acceleration sensed to drill sting motions through a numerical optimization utilizing an iterative search to find a drill string position that minimizes an objective function for the drill string position; and
determining the whirl attribute from information provided by the centers of rotation to output the whirl attribute selected from at least one of magnitude, orientation, velocity and type of whirl.

US Pat. No. 9,915,746

MARINE SEISMIC SURVEYING INCLUDING DIRECT FAR FIELD MEASUREMENTS

CONOCOPHILLIPS COMPANY, ...

1. A method of measuring seismic signals generated by marine acoustic sources, the method comprising:
deploying at least one variable depth sensor assembly on a floor of the body of water within a survey area, the at least one
variable depth sensor assembly including a float, a seismic sensor unit, one or more seismic sensors deployed at different
depths, a directional sensing device that allows seismic energy from different directions to be separated or individually
recorded, and a recording device configured to receive and store seismic data;

recording, by the recording device, seismic signals detected by the seismic sensor over a selected time period, the seismic
signals including a real measured far field signature generated by a seismic source during a marine seismic survey;

performing the marine seismic survey, the marine seismic survey including generating a seismic signal by the seismic source
at a plurality of locations above one or more shot points in the survey area and receiving a return signal reflected from
an earth formation at one or more seismic receivers located above the survey area;

automatically actuating a retrieval device disposed at the at least one seismic sensor unit to cause the at least one seismic
sensor unit to rise to the surface, in response to one of: expiration of the selected time period and an actuation signal
from the surface;

retrieving the at least one seismic sensor unit from the surface; and
processing seismic data collected from the return signal, the processing including identifying a far field signature of the
seismic source for each of the plurality of locations based on the seismic signals detected by the seismic sensor, and designaturing
the seismic data based on the far field signature to appropriately relate the far field signature to the correct shot point
and time.

US Pat. No. 9,835,373

INTEGRATED CASCADE PROCESS FOR VAPORIZATION AND RECOVERY OF RESIDUAL LNG IN A FLOATING TANK APPLICATION

ConocoPhillips Company, ...

1. A method for vaporizing liquefied natural gas (LNG) produced from a main liquefaction process and stored in an LNG storage
tank comprising:
a) heating via a warm predominantly methane stream at least a portion of the LNG to provide a boil-off gas stream and a liquid
quench stream;

b) routing the boil-off gas stream and the liquid quench stream to a quench system, wherein the quench system cools the boil-off
gas stream to provide a quenched stream;

c) compressing the quenched stream to provide a compressed quenched stream, wherein a first part of the compressed quenched
stream is routed to the main liquefaction process; and

d) heating a second part of the compressed quenched stream to provide a warm compressed quenched stream wherein the warm compressed
quenched stream is the warm predominantly methane stream used to heat the LNG; wherein the warm predominantly methane stream
is used as a refrigerant in a refrigeration cycle of the main liquefaction process.

US Pat. No. 9,784,082

LATERAL WELLBORE CONFIGURATIONS WITH INTERBEDDED LAYER

ConocoPhillips Company, ...

17. A method of producing hydrocarbons, comprising:
forming an injection well in a formation and having an injector section that extends in a horizontal direction through a hydrocarbon
bearing first reservoir below and separated from a hydrocarbon bearing second reservoir by a stratum having lower permeability
than the reservoirs;

forming a production well in the formation and having a producer section extending aligned with the injector section, wherein
open-hole laterals extend upward from the injector and producer sections with the laterals of the injector section each passing
through the stratum closer to the injector section relative to where a closest one of the laterals of the producer section
passes through the stratum;

introducing steam into the formation through the injection well and into contact with the first reservoir and the second reservoir
via the laterals of the injector section; and

producing the hydrocarbons from the first reservoir and the second reservoir via the laterals of the producer section, wherein
laterals on both the injection well and the production well limit counter-current flow through the laterals.

US Pat. No. 9,528,759

ENHANCED NITROGEN REMOVAL IN AN LNG FACILITY

ConocoPhillips Company, ...

1. A process for liquefying a natural gas stream in an LNG facility, the process comprising:
(a) cooling at least a portion of the natural gas stream in a plurality of upstream mechanical refrigeration cycles to form
a predominantly natural gas stream wherein each upstream mechanical refrigeration cycle comprises a heat exchanger for providing
indirect heat exchange with a pure component refrigerant for cooling the natural gas stream;

(b) introducing the predominantly natural gas stream to a heavies removal unit to remove a portion of the heavies from the
predominantly natural gas stream to form a predominantly methane stream;

(c) after step (b) and downstream of the heavies removal unit, introducing the predominantly methane stream to an open-loop
methane refrigeration cycle wherein the open-loop methane refrigeration cycle comprises an open-loop methatne refrigeration
cycle heat exchanger, a refrigeration compressor, and a refrigerant chiller downstream of the refrigerant compressor;

(d) after (c) and downstream of the heavies removal unit, cooling the predominantly methane stream in the open-loop methane
refrigeration heat exchanger;

(e) after (d) and downstream of the open-loop methane refrigeration cycle heat exchanger, separating at least a portion of
the predominantly methane stream in a multistage separation vessel, wherein the multistage separation vessel comprises a plurality
of mass transfer surfaces and a reboiler, to provide a predominantly vapor stream and a predominantly liquid stream, wherein
at least a portion of the predominantly vapor stream is routed to a nitrogen removal unit; and

(f) using the predominantly vapor stream as a refrigerant in the open-loop methane refrigeration cycle by introducing the
predominantly vapor stream to a warming pass of the open-loop methane refrigeration cycle heat exchanger for cooling the predominantly
methane stream in step (d);

(g) after step (f)and downstream of the warming pass of the open-loop methane
refrigeration cycle heat exchanger, compressing the refrigerant in the refrigeration compressor; (h) cooling the refrigerant
in the refrigeration chiller;

(i) after step (h), introducing the refrigerant to a cooling pass of at least one of the plurality of heat exchangers of the
upstream mechanical refrigeration cycles to form a reboiler duty stream;

(j) introducing the reboiler duty stream to a warming pass of the reboiler to provide a reboiler duty for the multistage separation
vessel to form a cold reflux stream;

(k) introducing the cold reflux stream to the multistage separation vessel to provide reflux to the multi stage separation
vessel; and

(l) withdrawing at least a portion of the predominantly liquid product stream as a liquefied natural gas product.

US Pat. No. 9,395,460

CONTINUOUS COMPOSITE RELATIVELY ADJUSTED PULSE

ConocoPhillips Company, ...

1. A process for acquiring seismic data and providing information about geologic structures in the earth, wherein the process
comprises:
a) providing a plurality of seismic receivers to receive seismic energy;
b) providing at least one pulse-type seismic source to emit pulses of seismic energy into the earth;
c) firing a distinctive non-orthogonal series of pulses of seismic energy into the earth to create a seismic energy wavefield
response from geologic structures in the earth where the distinctive series of pulses of seismic energy are delivered in a
loop from said at least one pulse-type seismic source in a planned order where the loop is of sufficient length to provide
listening time to receive the wave field response from the geologic structures in the earth from a portion of the loop defined
as a composite pulse before the distinctive series of pulses of the loop end and are restarted and wherein the series of pulses
within the loop are sufficiently distinctive so as not to confuse parts of the loop with other parts of the loop and sufficiently
distinctive so as to distinguish the wavefield caused by the loop from seismic energy in the environment that arises from
other sources;

d) receiving seismic energy with the plurality of seismic receivers including the seismic energy wavefield response from the
geologic structures in the earth;

e) recording the seismic energy wavefield response received by the seismic receivers to form data traces; and
f) processing the data traces of recorded seismic energy to separately identify within the data traces the composite pulses
of the pulse-type seismic source when the composite pulses were fired.

US Pat. No. 9,249,760

METHOD FOR REMOVING TRACE LEVELS OF OXYGEN FROM DIRECT COMBUSTION DEVICE COMBUSTION PRODUCTS

ConocoPhillips Company, ...

1. A method comprising:
a) supplying fuel, oxidant and water into a direct combustion device;
b) combusting the fuel, oxidant and water in the direct combustion device to produce a combustion products stream, wherein
the combustion products stream includes steam with oxygen; and

c) delivering the combustion products stream to a scrubber for removal of oxygen, wherein the scrubber includes a material
capable of reacting with the oxygen and is in a separator for splitting a liquid effluent from gases in the combustion products
stream.

US Pat. No. 9,176,242

PRACTICAL AUTONOMOUS SEISMIC RECORDER IMPLEMENTATION AND USE

ConocoPhillips Company, ...

1. A seismic recording system comprising:
a) a seismic energy source,
b) an autonomous data recorder with a field timer that records field time,
c) a standard timer that records standard time,
c1) a control timer that records control time,
d) a processor that corrects the field time from the field timer (b) by using a regional drift, wherein the regional drift
is a correction factor calculated using recorded control time and standard time,

e) calculating a regression-based model of the regional drift; and
f) modifying the field time using the calculated regional drift.

US Pat. No. 10,161,216

WELL ABANDONMENT SYSTEM AND METHOD

ConocoPhillips Company, ...

15. A method of capping a hydrocarbon well consisting of:(a) cutting a well casing string such that an internal production casing of the well casing string is cut lower than an external surface casing of the well casing string;
(b) inserting a first plate under a cut level of said surface casing and over a cut level of said production casing, said first plate having a hole with a threaded pipe therein, and a coupler section attached to said threaded pipe, and a stopper inserted into said coupler;
(c) welding said first plate to said surface casing to cover the production casing;
(d) welding a second plate to a top of the surface casing to provide a vented seal, such that said second plate rests above said stopper at a distance to only allow partial ejection of said stopper.
US Pat. No. 10,131,551

SEPARATION OF KINETIC HYDRATE INHIBITORS FROM AN AQUEOUS SOLUTION

CONOCOPHILLIPS COMPANY, ...

1. A process for treating an aqueous solution from a subterranean formation, the process comprising:removing an aqueous solution containing one or more kinetic hydrate inhibitors from a subterranean formation;
introducing the aqueous solution into a heated centrifugal separator;
separating a high molecular weight portion of a kinetic hydrate inhibitor from the aqueous solution in the separator by centrifuging the aqueous solution to force the high molecular weight portion of the kinetic hydrate inhibitor to drop out of the aqueous solution;
treating the aqueous solution with activated carbon to remove remaining kinetic hydrate inhibitor from the aqueous solution; and
reintroducing the aqueous solution into the subterranean formation.

US Pat. No. 9,822,624

VAPOR BLOW THROUGH AVOIDANCE IN OIL PRODUCTION

ConocoPhillips Company, ...

1. A method of preventing vapor blow through in a production well, said method comprising:
a. providing a vapor blow through avoidance system for an oil well, said system comprising:
i. a casing gas remover (CGR);
ii. a dynamic fluid level detector (DFLD) for detecting a dynamic fluid level (DFL);
iii. a downhole pump (DHP);
iv. a control processor operatively connected to said CGR, DFLD and DHP;
b. said DFLD determining said DFL;
c. said control processor comparing said DFL against a target DFL (DFLt) and:
i. increasing a rate of said CGR or reducing a rate of said DHP if DFL ii. maintaining said rate of said CGR and said rate of said DHP if DFL=DFLt;
iii. decreasing said rate of said CGR or increasing said rate of said DHP if DFL>DFLt.

US Pat. No. 9,695,680

PLUNGER LIFT OPTIMIZATION

ConocoPhillips Company, ...

1. An improved method of optimizing a ON and OFF cycle of a plunger lift system for a well, the plunger lift system having
a cased well, a plunger in the cased well moveable from a stop at the bottom of the cased well to a top of the cased well,
a control valve in functional connection with the cased well, a plunger arrival sensor capable of measuring a plunger arrival
velocity, a flow valve sensor capable of measuring time flow valve is open or closed, a controller in operational connection
with the control valve and functional connection with the sensors for receiving signals from the sensors, wherein the improvement
comprises said controller optimizing for Minimum-OFF time for said plunger, or optimizing for Minimum-ON time for said plunger,
or both based on current cycle parameters wherein a logic for making decisions based on receiving signals compares current
cycle parameters with target parameter limits and adjusts the ON and OFF cycle by an auto-tune increment or decrement according
to said evaluations.

US Pat. No. 9,316,096

ENHANCED OIL RECOVERY SCREENING MODEL

ConocoPhillips Company, ...

1. A process for enhancing hydrocarbon production where the process comprises:
a) mechanistic modeling of one or more enhanced oil recovery process (EOR) in two or more hydrocarbon reservoirs,
b) identifying parameter ranges including a maximum, minimum and median value for one or more available screening parameters,
c) generating one or more three dimensional reservoir models using experimental design methods with the parameter ranges identified,
d) simulating the process for each hydrocarbon reservoir,
e) developing a response surface to correlate oil recovery at different times of EOR with one or more available screening
parameters, wherein the response surface consists of:

Y=A+B1X1+B2X2. . .+C1X1X2+C2X1X3+. . .+D1X12+D2X22+. . .
wherein X1, X2 through Xn are available screening parameter, wherein Xn represents the final available screening parameter, wherein A, Bi, Ci, Di, through Ni are calculated coefficients for each available screening parameter, wherein i represents the available screening parameter,
wherein N represents the final coefficients and wherein Y is projected oil recovery during EOR, and
f) testing the response surface for each EOR with multiple random simulations.

US Pat. No. 9,123,134

METHOD FOR TRACKING AND FORECASTING MARINE ICE BODIES

ConocoPhillips Company, ...

1. A method for tracking and forecasting a marine ice body comprising:
a. capturing an image and metocean data of an area of interest with a synthetic aperture radar (SAR), wherein the image includes
a plurality of pixels;

b. detecting any marine ice bodies in the area of interest with the synthetic aperture radar (SAR);
c. classifying the plurality of pixels in the image to define a shape and position of the marine ice body;
d. repeating steps (a)-(c) at least once to obtain an additional image;
e. comparing sequential images, wherein a background trend for motion between images and a shape characteristic are utilized
to compare the sequential images, wherein the background trend is determined by establishing a correlation between the sequential
images, wherein an ITSARI algorithm is utilized to determine the shape characteristic of the marine ice body;

f. solving a trajectory of each ice floe beyond its current position, wherein the metocean data is utilized to solve the trajectory
for each of the marine ice bodies beyond its current position; and

g. updating Gaussian uncertainty parameters with cumulative observations of error from incoming SAR to provide a cone of uncertainty
for the forecasted trajectory.

US Pat. No. 9,075,161

CRITICAL REFLECTION ILLUMINATIONS ANALYSIS

ConocoPhillips Company, ...

1. A method for evaluating the illumination of a subsurface geological formation of interest that is located beneath a velocity
boundary or interface with a material having high velocity seismic propagating properties above it and a subjacent material
having relatively slower velocity seismic propagating properties; the method comprising:
a) creating a theorized target horizon representing the subsurface zone of interest;
b) creating a theorized velocity contrast horizon representing the subsurface velocity boundary;
c) creating a velocity model representing the speeds at which seismic energy is expected to travel from the theorized target
horizon up to and through the theorized velocity contrast horizon;

d) selecting a plurality of locations along the theorized target horizon for critical reflection analysis;
e) calculating the propagation of seismic energy from each of the plurality of locations along at least one pair of respective
trajectories satisfying Snell's law for arriving and departing wave paths to determine incidence angles for each path of the
pair of trajectories at the theorized velocity contrast horizon;

f) comparing the incidence angles for each trajectory of the pair of trajectories to one or more critical angles, wherein
the velocity contrast refracts the seismic energy to progress along the velocity contrast horizon such that the seismic energy
intersecting the velocity contrast horizon at the critical angle is unlikely to progress to the earth's surface in a lateral
range or at a strength to be meaningful for seismic prospecting;

g) tabulating the number of pairs of trajectories at each selected location where both trajectories are pre-critical, or less
than the critical angle, in comparison to the number of pairs of trajectories where either or both of the trajectories of
the pair are critical or post-critical, or equal to or greater than at least one critical angle wherein a pair is deemed pre-critical
if each trajectory of the pair is pre-critical and wherein a pair is deemed post-critical if either trajectory or both trajectories
are post-critical; and

h) creating a display, critical reflection illumination map, that identifies areas of the target horizon for which selected
locations have more pairs of pre-critical trajectories and therefore fewer pairs of post-critical trajectories and also identifies
areas of the target horizon for which selected locations have fewer pairs of pre-critical trajectories and therefore more
pairs of post-critical trajectories, wherein the areas that have more pairs of pre-critical trajectories are likely to yield
useful seismic data and areas that have fewer pairs of pre-critical trajectories are less likely to yield useful seismic data
when recorded above the velocity contrast.

US Pat. No. 9,052,410

MULTIPLE SEISMIC SIGNAL INVERSION

ConocoPhillips Company, ...

1. A method of recording multiple marine seismic signals comprising:
a) deploying two or more independent phase encoded vibrational seismic sources, and three or more seismic receivers spaced
the same substantially common distance from one another into the water to be towed by a boat;

b) while in motion, transmitting multiple simultaneous sweep signals from the independent phase encoded seismic sources;
c) while in motion, recording multiple simultaneous phase encoded seismic signals (b);
d) inverting the recorded seismic signals in (c);
e) separating signals at each receiver into separate source specific signals; and
f) taking the source-receiver pair signals and stacking them based on a substantially common location of the respective sources
and receivers at the time of the respective sweep so as to correct for the motion of the sources, receivers and common mid
points.

US Pat. No. 10,345,771

BIG DRILLING DATA ANALYTICS ENGINE

CONOCOPHILLIPS COMPANY, ...

1. A system for rig-state determination, the system comprising:a plurality of surface sensors on a surface of the earth and associated with a wellbore drilling operation, the plurality of surface sensors acquiring time series data, the time series data being formatted for sample and bandwidth regularization and time-corrected to provide time-synchronized data;
a processing graph of data-stream networked mathematical operators that applies continuous analytics to the time-synchronized data at least as rapidly as the time series data is acquired by the plurality of surface sensors to determine downhole dynamic conditions of a plurality of rig conditions associated with the wellbore drilling operation, a drilling dysfunction detectable from the downhole dynamic conditions of the plurality of rig conditions; and
a drilling rig having a rig-state determined from the plurality of rig conditions.

US Pat. No. 10,161,224

HOT WATER RECYCLE FOR PARAFFIN CLEANOUT

ConocoPhillips Company, ...

7. An apparatus for producing oil or gas from an oil well, comprising:a) a first or inner tubing string extending in a well from a surface of said well to an oil producing zone in a reservoir;
b) a second tubing string of larger diameter surrounding said first tubing string in spaced relationship therewith and extending into said well to a depth below that of an area in which paraffin is deposited, said second string being shorter than said first string;
c) an annulus being between said first and second tubing strings;
d) a closure device within the lower end of said second tubing string for closing the annular space between said first and second tubing strings;
e) one or more fluid ports through the wall of said first tubing above said closure device,
f) a pump at a lower end of said first or inner tubing string;
g) a string of sucker rods secured to said pump and extending to said surface within said first tubing string for reciprocating said pump;
h) a hot water line for supplying to said annulus a clean deoxygenated hot water for melting paraffin;
i) a recycle line fluidly connected to said well and said hot water line for removing water and melted paraffin from said first tubing string; and
j) said recycle line comprising a paraffin removal unit fluidly connected to a reheating unit.

US Pat. No. 9,845,668

SIDE-WELL INJECTION AND GRAVITY THERMAL RECOVERY PROCESSES

ConocoPhillips Company, ...

1. A method of producing hydrocarbons, comprising:
forming a single well pair comprising:
a single horizontal injection well in a formation, wherein the injection well comprises an injector section that extends lengthwise
towards horizontal; and

a single production well comprising a producer section that extends lengthwise towards horizontal laterally offset and in
horizontal alignment with the injector section;

introducing steam and a non-condensable gas under reservoir conditions into the formation through the injection well to form
a steam-assisted gravity drainage chamber above the injector section; and

producing the hydrocarbons through the production well by combined steam-assisted gravity drainage and pressure drive from
the gas;

wherein the injector section and the producer section are within 5 meters of a bottom of a heavy oil or bitumen reservoir
that contains the hydrocarbons which have an initial API gravity less than 25° and the reservoir is less than 15 meters thick;
and

wherein the injection well and the production well are separated from any other wells by more than 100 meters.

US Pat. No. 9,841,230

SYSTEM FOR ENHANCED GAS TURBINE PERFORMANCE IN A LIQUEFIED NATURAL GAS FACILITY

ConocoPhillips Company, ...

1. A process for liquefying a natural gas stream, the process comprising:
(a) cooling at least a portion of the natural gas stream via indirect heat exchange with a first refrigerant in a first refrigeration
cycle to produce a cooled natural gas stream;

(b) further cooling at least a portion of the cooled natural gas stream via indirect heat exchange with a second refrigerant
in a second refrigeration cycle to provide a further cooled natural gas stream; and

(c) partially compressing an air stream with a low compression stage to provide a partially compressed air stream;
(d) cooling the air stream and the partially compressed air stream via indirect heat exchanger with a primary coolant selected
from the group consisting of: the first refrigerant, the second refrigerant, and any combination thereof, to provide a cooled
inlet air stream and a cooled partially compressed air stream, wherein the partially compressed air stream is withdrawn from
an intermediate compression stage of a gas turbine used to drive at least one refrigerant compressor associated with the first
or the second refrigeration cycle, or both; and

(e) introducing the cooled inlet air stream into an inlet of the gas turbine.

US Pat. No. 9,217,799

DISTINCTIVE LAND SEISMIC SWEEP

ConocoPhillips Company, ...

1. A process for delivering a distinctive seismic sweep for a seismic prospecting operation, the process comprising:
a) providing an electrically powered seismic source having about 100 to 5,000 linear electric motors carried by a frame, wherein
a ground contact element of the linear electric motor is provided in contact with the ground; and

b) driving the ground contact elements of linear electric motors to deliver multiple impulses against the ground in a manner
to create a distinctive series of impulses to convey seismic energy into the earth.

US Pat. No. 10,384,242

SLUDGE MANAGEMENT SYSTEM FOR CRUDE OIL STORAGE TANKS

ConocoPhillips Company, ...

1. A multi-stage method of reducing sludge deposition in a storage tank, said storage tank comprising a) a bottom wall, b) a peripheral wall, and c) a top wall that collectively define a storage volume, d) a first nozzle arranged at a first inlet through said peripheral wall at a first height, the first nozzle being configured to selectively rotate between a first position and a second position to direct a first stream of fluid into the storage volume, and e) a second nozzle arranged at a second inlet through said peripheral wall at said first height, the second nozzle being configured to selectively rotate between a first position and a second position to direct a second stream of fluid into the storage volume;said method comprising:
during a first stage, directing first and second streams of fluid into said storage volume along a radius of said storage tank to dislodge sludge that lies centrally;
during a second stage, directing first and second streams of fluid into said storage volume at first and second angles to induce a rotational flow in storage tank to dislodge sludge that lies on said bottom wall;
during a third stage, directing first and second streams of fluid into said storage volume storage volume at third and fourth angles, opposite said first and second angles respectively, to induce a counter-rotational flow in said storage tank to further dislodge sludge that lies on said bottom wall; and
removing dislodged sludge from said storage tank.

US Pat. No. 10,087,716

METHOD AND APPARATUS FOR FILLING AN ANNULUS BETWEEN CASING AND ROCK IN AN OIL OR GAS WELL

CONOCOPHILLIPS COMPANY, ...

1. A plug and abandonment process for plugging and sealing an annulus between casing and formation in a hydrocarbon wellbore, comprising:repeatedly increasing and reducing the pressure in the annulus via holes or perforations in the casing, or via casing outlets in the wellhead, thereby artificially promoting or inducing creep in the formation surrounding the casing;
plugging and sealing the annulus with the artificially promoted or induced creep in the formation surrounding the casing; and
abandoning the hydrocarbon wellbore.

US Pat. No. 9,989,304

METHOD FOR UTILIZATION OF LEAN BOIL-OFF GAS STREAM AS A REFRIGERANT SOURCE

CONOCOPHILLIPS COMPANY, ...

1. A process for liquefying natural gas, said process comprising the steps of:a. cooling a natural gas stream in a first refrigeration cycle employing a first refrigerant, wherein the first refrigerant cycle includes a plurality of first refrigerant cooling stages, wherein the natural gas stream comprises a plurality of heavy components;
b. downstream of the first refrigerant cycle, further cooling the natural gas stream in a final refrigeration cycle employing a final refrigerant, wherein the final refrigeration cycle is a closed loop methane final refrigerant cycle, wherein the final refrigerant predominately comprises less than 10 mole percent nitrogen, wherein the final refrigeration cycle includes a plurality of final refrigerant cooling stages, wherein the plurality of final refrigerant cooling stages includes a first cooling stage and a final cooling stage, wherein the temperature of the final refrigeration cycle operates at a lower temperature than the temperature of the first refrigeration cycle;
c. delivering the natural gas stream to a natural gas product storage tank, wherein evaporation of a portion of the natural gas stream occurs within the natural gas product storage tank resulting in boil-off gas;
d. compressing as least a portion of the boil-off gas; and
e. delivering at least a portion of the compressed boil-off gas from the natural gas product storage tank to the final cooling stage of the closed loop methane final refrigeration cycle, wherein at least a portion of the compressed boil-off gas serves as the final refrigerant in the final cooling stage of the closed loop methane refrigerant final refrigerant cycle.

US Pat. No. 9,957,775

WELL PLUG AND ABANDONMENT CHOKE INSERT

ConocoPhillips Company, ...

1. A process for plugging a wellbore, wherein the process comprises the steps of:a) installing a choke device into a wellbore tubular, the choke device having a through bore with a predetermined diameter;
b) determining a volume inside said wellbore tubular plus a volume of perforations in said wellbore tubular;
c) injecting a settable medium into the wellbore, wherein a volume of the settable medium injected into the wellbore is controlled based upon the determined volume inside said wellbore tubulars plus the volume of the perforations; and,
d) plugging said wellbore.

US Pat. No. 9,695,679

DOWNHOLE ZONE FLOW CONTROL SYSTEM

ConocoPhillips Company, ...

1. A method of actuating a well tool, comprising:
applying a first hydraulic pressure through a first control line to a set input of a manifold thereby opening a first communication
path for a fire input of the manifold;

then applying a second hydraulic pressure through a second control line to the fire input while holding the first hydraulic
pressure on the set input to maintain the open first communication path thereby establishing flow pathways for a third control
line to a first side of a hydraulic operated element and a fourth control line to a second side of the hydraulic operated
element; and

then applying a third hydraulic pressure through at least one of the third and fourth control lines for actuation of the well
tool

wherein each manifold includes a first piston having a passage through which fluid from one of the control lines passes to
an operator for a second piston configured to open a communication path for another one of the control lines coupled to operate
the first piston and upon pressurization block the passage through the first piston.

US Pat. No. 9,476,295

PLUNGER FALL TIME IDENTIFICATION METHOD AND USAGE

ConocoPhillips Company, ...

1. A method for identifying when a plunger reaches the bottom of a well with a plunger lift system, comprising:
a. shutting in the well, wherein by shutting in the well the plunger is allowed to fall to the bottom the well and to build
up energy;

b. obtaining data as the plunger falls to the bottom of the well, wherein the data includes surface pressure measurement and
a corresponding time measurement;

c. establishing a relationship between a change in surface pressure and a change in time, wherein the relationship provides

in which m is the rate of change, P1 is the pressure at a corresponding time T1 and P2 is the well pressure at a corresponding time T2;

d. calculating rate of change for each data point obtained while the well is shut in;
e. plotting the rate of change versus time;
f. identifying the maximum rate of change during the energy build up while filtering out anomalies not associated with the
plunger reaching bottom, wherein said maximum rate of change occurs when the plunger reaches the bottom of said well; and

g. opening said well when said plunger reaches the bottom of said well, thereby producing oil.

US Pat. No. 9,250,336

SIMULTANEOUS CONVENTIONAL AND PHASE-ENCODED SEISMIC ACQUISITION

ConocoPhillips Company, ...

1. A process for conducting two adjacent seismic surveys in close proximity and concurrently where each survey utilizes multiple
sweep-type seismic vibrators and where one survey is conducted with the seismic vibrators using sweeps of about twice the
length of time or longer as the sweeps of the seismic vibrators of the other survey.

US Pat. No. 10,095,828

PRODUCTION LOGS FROM DISTRIBUTED ACOUSTIC SENSORS

CONOCOPHILLIPS COMPANY, ...

1. A method of monitoring oil flow rates along a hydrocarbon reservoir comprising:a) installing one or more fiber optic cables along a wellbore in a hydrocarbon formation;
b) installing one or more interrogators on at least one of said fiber optic cables;
c) interrogating at least one of said fiber optic cables with an interrogation signal during production;
d) obtaining one or more datasets of data from at least one of said interrogators;
e) converting one or more of said datasets from at least one of said interrogators into a continuous record;
f) transforming the continuous record with a low-pass filter to 1-100 milliHz while down sampling the data into a transformed well signal;
g) approximating flow velocities at a given depth by calculating the slope of temperature variation as a function of depth from the transformed well signal; and
h) estimating from the slope of temperature variation as a function of depth a cumulative production rate of hydrocarbons from said hydrocarbon formation.

US Pat. No. 9,791,209

SYSTEM AND PROCESS FOR LIQUEFYING NATURAL GAS

ConocoPhillips Company, ...

1. A process of liquefying a natural gas stream in a liquefied natural gas (LNG) facility, the process comprising:
cooling the natural gas stream in a first refrigeration cycle to produce a cooled natural gas stream;
cooling the cooled natural gas stream in a first chiller of a second refrigeration cycle, the cooled natural gas stream exiting
the first chiller at a first pressure;

cooling the cooled natural gas stream in a first core of a second chiller of the second refrigeration cycle; and
cooling a refrigerant of a refrigerant recycle stream separate from the cooled natural gas stream in a second core of the
second chiller of the second refrigeration cycle, wherein the refrigerant recycle stream enters the second chiller at a second
pressure that is lower than the first pressure of the cooled natural gas stream; routing the cooled natural gas stream from
the second refrigerant cycle to a heat exchanger for cooling therein; reducing the pressure of the cooled natural gas stream
in a first expansion component disposed downstream of the heat exchanger; routing the cooled natural gas stream to a first
flash drum configured to separate the cooled natural gas stream into a natural gas vapor portion and a natural gas liquid
portion; routing the natural gas vapor portion to the heat exchanger for heating therein; routing the natural gas vapor portion
from the heat exchanger to an inlet port of a compressor; routing the refrigerant recycle stream from the second chiller of
the second refrigeration cycle to a methane recycle flash drum configured to separate the refrigerant recycle stream into
a refrigerant vapor portion and a refrigerant liquid portion; routing the refrigerant liquid portion to the heat exchanger
for cooling therein; reducing the pressure of the refrigerant liquid portion in a second expansion component disposed downstream
of the heat exchanger; and routing the refrigerant liquid portion to a second flash drum configured to separate the refrigerant
liquid portion into a refrigeration recycle vapor portion and a refrigeration recycle liquid portion.

US Pat. No. 9,644,889

SYSTEM FOR INCONDENSABLE COMPONENT SEPARATION IN A LIQUEFIED NATURAL GAS FACILITY

ConocoPhillips Company, ...

1. A process for liquefying a natural gas stream, the process comprising:
(a) cooling said natural gas stream via indirect heat exchange with a first refrigerant in a first closed-loop refrigeration
cycle to provide a cooled natural gas stream;

(b) further cooling at least a portion of the cooled natural gas stream via indirect heat exchange with a predominantly methane
refrigerant in an open-loop refrigeration cycle to provide a further cooled natural gas stream, wherein the open-loop refrigeration
cycle comprises a refrigerant compressor;

(c) separating an incondensable material from at least a portion of the further cooled natural gas stream in a first separation
vessel to provide an incondensables-depleted predominantly liquid bottoms fraction and an incondensables-rich predominantly
vapor overhead fraction, wherein at least a portion of said further cooled natural gas stream introduced into said first separation
vessel has passed through said refrigerant compressor;

(d) routing the incondensables-rich predominantly vapor overhead fraction to a fuel gas system for use as a fuel gas; and
(e) recovering the incondensables-depleted predominantly liquid bottoms fraction back into the predominantly methane refrigerant
of the open-loop refrigeration cycle, wherein the incondensables-depleted predominantly liquid bottoms fraction is controllably
routed from the first separation vessel routed directly to an inlet of a main heat exchanger of the open-loop refrigeration
cycle along a first path and from the first separation vessel to an outlet of the main heat exchanger of the open-loop refrigeration
cycle along a bypass path.

US Pat. No. 10,385,666

OIL RECOVERY WITH FISHBONE WELLS AND STEAM

ConocoPhillips Company, ...

1. A method of producing heavy oils from a reservoir by steam drive, comprising:a) providing a plurality of horizontal production wells at a first depth at or near the bottom of a hydrocarbon play;
b) providing a plurality of horizontal injection wells, each injection well laterally spaced at a distance D from an adjacent production well;
c) providing a plurality of open hole ribs originating from said plurality of horizontal production wells or said plurality of horizontal injection wells or both, wherein said plurality of open hole ribs cover at least 95% of said distance D;
d) cycling between injecting steam and producing through the laterals before injecting steam into said injection wells and steam driving heated heavy oils towards said production wells for production;
e) providing an open hole horizontal ghost hole above at least one injection well, wherein one or more open hole ribs slants towards said open hole horizontal ghost hole, and commencing a steam assisted gravity drainage process once a steam chamber encompasses said open hole horizontal ghost hole;
f) wherein said reservoir contains bitumen or heavy oil immobile for steam drive without the use of said plurality of lateral wells.

US Pat. No. 10,145,208

ANNULUS INSTALLED 6 ZONE CONTROL MANIFOLD

CONOCOPHILLIPS COMPANY, ...

1. A method of hydraulically controlling multiple well tools in a well, comprising the steps of:a) providing a set of first hydraulic lines;
b) providing a closing hydraulic line;
c) wherein each of said first hydraulic lines and said closing hydraulic line is fluidly connected to a plurality of addressable control devices, each connected to a plurality of actuators controlling a plurality of tools;
d) selecting a tool for actuation by generating a first code on the first hydraulic lines by applying a first hydraulic pressure to one of the first hydraulic lines;
e) activating the selected tool by generating a second code on the first hydraulic lines by applying the first hydraulic pressure to one or more of the first hydraulic lines that are not used in the selecting step d); and
f) terminating the activation of said tool by applying the first hydraulic pressure to said closing hydraulic line.

US Pat. No. 9,926,774

METHODS OF PRODUCING WITH MULTI-SIDETRACKED MOTHER WELLBORES

CONOCOPHILLIPS COMPANY, ...

1. A method for producing hydrocarbon from a subsurface formation having a plurality of stacked horizontal pay zones, comprising:a) drilling and casing a first mother wellbore in a subsurface formation having a plurality of stacked horizontal pay zones containing hydrocarbons;
b) drilling a first horizontal lateral well from said first mother wellbore into a first horizontal payzone;
c) lining said first horizontal lateral well;
d) stimulating said first horizontal lateral well;
e) producing hydrocarbon from said first horizontal lateral well until a first pre-selected production criterion is achieved;
f) closing said first horizontal lateral well;
g) sequentially repeating steps b)-f) for a sequential plurality of the lateral wells;
h) opening said plurality of lateral wells when production of hydrocarbons from a last payzone slows; and
i) producing from a combined plurality of the lateral wells,
wherein a second mother wellbore is drilled on a same pad as said first mother wellbore, and drilling and production from horizontal laterals alternate between said first and second mother wellbores, such that one mother wellbore is undergoing drilling and completion while the other mother wellbore is in production.

US Pat. No. 9,822,623

MULTILATERAL OBSERVATION WELLS

ConocoPhillips Company, ...

1. A method of monitoring conditions in a hydrocarbon reservoir, comprising:
injecting steam into the reservoir;
producing a mixture of hydrocarbons and condensate of the steam from the reservoir; and
detecting vertical development of a resulting steam chamber in the reservoir with a multilateral observation well having temperature
sensors disposed in branched bores of the observation well,

wherein junctions along the observation well where the bores originate are in a formation above the reservoir such that the
bores enter the reservoir at spaced locations and traverse downward through the reservoir.

US Pat. No. 9,727,057

VESSEL POSITIONING SYSTEM FOR MAINTAINING RELATIVE POSITION BETWEEN VESSELS OPERATIVELY COUPLED AND METHOD

ConocoPhillips Company, ...

1. A method of maintaining positioning between vessels comprising:
monitoring a relative position between a storage tank vessel and a shuttle tanker with a control system in operative communication
with the storage tank vessel and the shuttle tanker, wherein the control system controls thrusters of the storage tank vessel
or the shuttle tanker or both and the storage tank vessel fixed about a storage tank vessel bow region and operatively coupled
to the shuttle tanker with an offload hose extending from a storage tank vessel stern region to a shuttle tanker bow region;

inputting physical property data relating to the storage tank vessel and the shuttle tanker to the control system;
processing one or more environmental condition data related to wind or water with the control system;
controlling at least one positioning action to be taken by the storage tank vessel and the shuttle tanker via the control
system utilizing the thrusters of the storage tank vessel or the shuttle tanker or both based on the physical property data
and the one or more environmental condition data; and

maintaining an angular differential between the storage tank vessel and the shuttle tanker within a predetermined limit with
the at least one positioning action.

US Pat. No. 9,116,255

TWO-WAY WAVE EQUATION TARGETED DATA SELECTION FOR IMPROVED IMAGING OF PROSPECTS AMONG COMPLEX GEOLOGIC STRUCTURES

ConocoPhillips Company, ...

1. A process for imaging seismic data for a prospect that exists within or near structures that obscure or complicate seismic
imaging, where the process comprises:
a) constructing a first geologic model including information about the size, shape and depth of the obscuring or complicating
structure along with a prospect location for further understanding;

b) identifying a set of seismic source locations within the seismic data along with seismic acquisition geometry for associated
seismic receiver locations to be evaluated with the geologic model;

c) selecting a target on a geologic body for evaluation wherein the target may comprise a portion or an entirety of the prospect
location;

d) selecting parameters appropriate for a two-way wave equation propagation of energy;
e) computing a two-way wave equation for the wave propagation from a selected source to the target;
f) computing the energy arriving at the target and the associated attributes of the arriving energy at the target;
g) computing a two-way wave equation propagation for wave propagation from the target to the receivers associated with the
selected source by the acquisition geometry;

h) computing the energy and the associated attributes received by the receivers associated with the selected source by the
acquisition geometry from g);

i) repeat steps e) through h) for other sources in the selected acquisition geometry;
j) from the energy and attributes recorded in step f) create attribute displays that provide visual perspective of one or
more attributes of the energy propagated to the target from one or more sources;

k) from the energy and attributes computed in step h) create attribute displays that provide visual perspective of one or
more attributes of the energy associated with one or more acquisition sources propagated from the target to the receivers;

l) analyze the attribute displays in step j) and step k) to determine the source/receiver pair information that will provide
better imaging of the target; and

m) creating one or more geological images of the substructure using the source/receiver pair data identified in step l).

US Pat. No. 10,246,976

LINEAR INDUCTION MOTOR PLUNGER LIFT

ConocoPhillips Company, ...

1. A plunger lift system, comprising:a) a downhole tubing comprising a linear induction motor (LIM), and
b) a plunger lift device comprising magnets or electromagnets or magnetically responsive materials arranged in circumference around said plunger lift, and
c) wherein a lifting force for said plunger lift device is provided by said linear induction motor
wherein said plunger lift device comprising first and second plunger lifts devices connected in tandem by a hollow tube allowing fluid from said first plunger lift to said second plunger lift.

US Pat. No. 10,082,331

PROCESS FOR CONTROLLING LIQUEFIED NATURAL GAS HEATING VALUE

CONOCOPHILLIPS COMPANY, ...

1. A process for liquefying a natural gas stream in a liquefied natural gas (LNG) facility, the process comprising:a) providing a heavies/NGL recovery system that comprises a first distillation column and a second distillation column wherein the second distillation column is an natural gas liquids (NGL) column;
b) introducing a first portion of the natural gas stream from a liquefaction system into a first heat exchanger to produce a first cooled stream;
c) introducing a second portion of the natural gas stream into the first distillation column, wherein prior to entry into the first distillation column the stream is combined with the first cooled stream to form a combined stream;
d) using the first distillation column to separate the combined stream into a first predominately vapor stream and a first predominately liquid bottoms stream;
e) removing the first predominately vapor stream from the first distillation column and reintroducing the first predominately vapor stream into the liquefaction system;
f) removing the first predominately liquid bottoms stream from the first distillation column and introducing the first predominately liquid bottoms stream into the first heat exchanger to produce a first heated stream;
g) separating the first heated stream to form a portion of first heated stream and a remaining portion of the first heated stream, wherein the portion of the first heated stream is introduced into the bottom of the first distillation column;
h) introducing the remaining portion of the first heated stream into the second distillation column;
i) using the second distillation column to separate at least a portion of the remaining portion of the first heated stream into a second predominately liquid bottoms stream and a second predominately vapor stream;
j) removing the second predominately vapor stream from the second distillation column and introducing the second predominately vapor stream into a second heat exchanger in indirect heat exchange with an external coolant to produce a second cooled stream;
k) introducing the second cooled stream into a separation vessel to separate the second cooled stream into a third vapor fraction and a third liquid fraction;
l) introducing at least a portion of the third vapor fraction into a fuel gas system fuel gas, wherein the at least a portion of the third vapor fraction is relatively concentrated in ethane and propane; and
m) returning a portion of the third vapor fraction to a methane system component of the liquefaction system.

US Pat. No. 9,914,514

SUBSEA VESSEL AND USE

CONOCOPHILLIPS COMPANY, ...

1. A method of using a subsea vessel for buoyancy, comprising:
floating the vessel in water coupled by releasable engagement with a platform having equipment for delivery subsea, wherein
the vessel includes a shell arranged around at least one inner enclosure containing gas with concrete material poured to fill
between the shell and the enclosure;

submerging the vessel until supported by a seabed; and
releasing the engagement of the platform from the vessel thereby leaving the equipment subsea and causing ascent of the vessel
from the seabed for recovery of the vessel.

US Pat. No. 9,739,123

DUAL INJECTION POINTS IN SAGD

CONOCOPHILLIPS COMPANY, ...

1. A method for recovering petroleum from a formation, comprising:
a. providing at least three wells, wherein the at least three wells comprise at least one horizontal injection well, a second
injection well, and at least one horizontal production well,
wherein the at least one horizontal injection well and the at least one horizontal production well are a horizontal well pair
that are vertically aligned in said formation and are in fluid communication with said formation,
b. introducing a gaseous mixture into the at least one horizontal injection well and the second injection well at a temperature
and a pressure, wherein said gaseous mixture comprises steam and non-condensable gas (NCG); and

c. recovering a fluid comprising petroleum from said at least one horizontal production well,
wherein the at least one horizontal injection well is disposed 1-10 meters above the at least one horizontal production well,
and the second injection well is disposed at least 5 meters above said at least one horizontal injection well within said
formation wherein the pressure, temperature, and NCG introduced at the second injection well prevent refluxing, improve thermal
efficiency, and reduce cumulative steam-oil ratio.

US Pat. No. 9,726,769

METHOD FOR SEPARATING SEISMIC SOURCE DATA

CONOCOPHILLIPS COMPANY, ...

1. A method of separating seismic sources, comprising the steps of:
a) providing at least two vibratory sources and two or more receivers, wherein said vibratory sources are each capable of
generating a sweep of vibrations into the ground;

b) performing a sweep of vibrations into the ground by said vibratory sources and concurrently recording a setup field data
from each of said vibratory sources using each of said receivers, wherein an initial Ground Force Estimate (GFE) specific
to each of said vibratory sources is obtained;

c) performing iterative inversion for the setup field data from each of said vibratory sources using said initial GFE as preliminary
input to obtain inverted setup field data;

d) separating said inverted setup field data to obtain a shot record for each of said receivers from each of said vibratory
sources, wherein for each said vibratory source the number of said shot records is the same as the number of said receivers;

e) comparing and differentiating said shot records of the same vibratory source to yield a crosstalk modifier;
f) modifying the initial GFE using said crosstalk modifier to obtain an improved derived GFE; and
g) repeating steps b) to c) using said derived GFE instead of said initial GFE to minimize cross talk and obtain a final seismic
data record and an optimized derived GFE.

US Pat. No. 9,217,798

CONSTANT ENERGY DISPLACEMENTS

ConocoPhillips Company, ...

1. A process for delivering acoustic energy into the earth for seismic prospecting, the process comprising:
a) providing an electrically powered seismic source having about 100 to 5,000 linear electric motors carried by a frame where
a ground contact element of each linear electric motor is arranged to be provided in contact with the ground;

b) putting the ground contact element of each linear electric motor into contact with the ground; and
c) actuating the linear electric motors to repeatedly and forcefully press against the ground deflecting the ground and thereby
deliver acoustic energy to the ground and into the earth as a sweep where the sweep is characterized as having a core frequency
spectrum from about 2 Hz to about 120 Hz where the ground deflection is substantially consistent across the core frequency
spectrum.

US Pat. No. 10,655,453

SYSTEM AND METHOD FOR DETERMINING DRILL STRING MOTIONS USING ACCELERATION DATA

CONOCOPHILLIPS COMPANY, ...

1. A method comprising:(a) determining gravitational and centripetal accelerations by performing a local running mean of acceleration measurements from a drill pipe;
(b) removing the local running mean to yield corrected acceleration data due to vibration only;
(c) transforming the corrected acceleration data from a local rotating coordinate frame to a global stationary coordinate frame;
(d) mapping in real time, the acceleration data in the global stationary coordinate frame into continuous drill-string positions; and
(e) determining, via a computing device, dysfunctions for detecting equipment failure based on the continuous drill-string positions.

US Pat. No. 10,550,308

PREFLUSH CHEMICALS FOR SCALE INHIBITOR SQUEEZE

ConocoPhillips Company, ...

7. A scale inhibitor squeeze method for minimizing scaling in a reservoir, comprising:a) injecting a preflush solution into a wellbore in a reservoir;
b) injecting a scale inhibitor fluid into said wellbore;
c) injecting a push fluid to push the injected scale inhibitor fluid into the reservoir surrounding said wellbore;
d) shutting in said wellbore for a period of time;
e) opening said wellbore for back flow of said push fluid and said scale inhibitor fluid and lastly for back flow of said preflush solution; and
f) producing a hydrocarbon reservoir fluid from said wellbore;
wherein said preflush solution comprises at least 90 vol % petroleum miscible fluid, at least 1 vol % alkyl polyglycoside (APG), at least 0.5 vol % ethoxylated alcohol (EA) or alcohol ethoxysulfates (AES), and at least 1 vol % linear alcohol, and wherein said preflush solution forms a Winsor Type III or Type IV microemulsion with water.

US Pat. No. 10,385,678

METHOD FOR ANALYSING PORE PRESSURE IN SHALE FORMATIONS

CONOCOPHILLIPS COMPANY, ...

1. A method for analyzing pore pressure in a subterranean organic-rich or gas- and/or oil-bearing shale formation comprising:gathering from a well formed in a subterranean formation (i) resistivity log data and (ii) one or more types of log data indicative of porosity selected from the group consisting of: sonic slowness and bulk density;
storing the resistivity log data and the one or more types of log data indicative of porosity on a non-transitory computer storage medium;
combining the resistivity log data with the one or more types of log data indicative of porosity, via a computer processor to generate a combined log data;
generating a combined log data graph for a defined depth window of the subterranean formation, wherein the combined log data graph provides a more accurate pore pressure as compared to either the resistivity log data or the one or more types of log data indicative of porosity;
calculating an estimated pore pressure for a given depth in the shale formation, wherein the estimated pore pressure is given by
Pcombined=(a*(Sv?(Sv?Ph)*(R0/Rn)x+b*(Sv?(Sv?Ph)*(?Tn/?T0)y ))/(a+b)where:a, b are constants which can be varied;
Sv is vertical stress at current depth;
Pcombined is pore pressure calculated from both resistivity and sonic curves;
Ph is hydrostatic pressure;
R0, ?T0 is based line (trend) resistivity and sonic interval transit time at current depth;
Rn, ?Tn observed resistivity and sonic interval transit time at current depth; and
x, y are Eaton exponents; and
managing a back-pressure on a drilling mud system to maintain the back-pressure at or above the estimated pore pressure.

US Pat. No. 10,120,343

TIME CORRECTIONS FOR DRILLING DATA

CONOCOPHILLIPS COMPANY, ...

1. A process for adjusting a time reference of time series data acquired from a wellbore sensor relative to a reference time series where the process comprises:a. acquiring a first time series from a sensor of a drill string in a wellbore during a drilling operation;
b. acquiring a reference time series;
c. determining a linear moveout time correction to apply to the first time series, the linear moveout time correction equal to a depth of the sensor divided by a signal propagation velocity;
d. applying the linear moveout time correction to the first time series;
e. cross-correlating the first time series with the reference time series to determine a cross-correlation time correction to apply to the first time series;
f. applying the cross-correlation time correction to the first time series to obtain a cross-correlation corrected time series;
g. displaying the cross-correlation corrected time series via an output interface during the drilling operation; and
h. monitoring and identifying a dysfunction of the drill string during the drilling operation using the cross-correlation corrected time series.

US Pat. No. 10,114,132

OPTIMAL PHASE RELATIONSHIP

CONOCOPHILLIPS COMPANY, ...


wherein the two to eight vibratory sources are positioned proximate to a predetermined location on a surface of earth.

US Pat. No. 9,988,895

METHOD FOR DETERMINING HYDRAULIC FRACTURE ORIENTATION AND DIMENSION

CONOCOPHILLIPS COMPANY, ...

28. A method for characterizing a subterranean formation comprising:inducing one or more fractures in a section of the subterranean formation;
determining a pressure response caused by change in volumetric stresses of the subterranean formation, wherein the pressure response is measured by a sensor that is in at least partial hydraulic isolation with the section of the subterranean formation; and
determining a physical feature of the one or more fractures via a geomechanical model that relates the pressure response to the physical feature.

US Pat. No. 9,823,372

CONTROLLED SPACED STREAMER ACQUISITION

ConocoPhillips Company, ...

1. A method of obtaining seismic measurements of an area of interest, the method comprising:
disposing a cable in a marine environment, the cable configured to be towed by a vessel;
disposing a plurality of sensors at a first interval along the cable, the plurality of sensors configured to receive reflections
resulting from a seismic source and each of the plurality of sensors configured to receive the reflection corresponding with
a particular subsurface location; and

controlling the plurality of sensors to dynamically turn on a first set of the plurality of sensors and dynamically turn off
a second set of the plurality of sensors wherein the controlling the plurality of sensors is based on topology or geology
of the area of interest.

US Pat. No. 9,529,102

CATERPILLAR-STYLE SEISMIC DATA ACQUISITION USING AUTONOMOUS, CONTINUOUSLY RECORDING SEISMIC DATA RECORDERS

ConocoPhillips Company, ...

1. A process for collecting seismic data for a survey area where source trucks shake shot points and autonomous, continuously
recording seismic recorders record data at listening points, the process comprising:
a) creating a geophysical survey layout for the survey area including defining individual locations for each of a plurality
of shot points and each of a plurality of listening points;

b) estimating the average number of shot points that will be shaken during a normal work day wherein the term active shot
points means shot points that are currently being shaken and active source patch means a generally contiguous geographical
array of shot points within the survey area that are expected to be shaken during a normal work day;

c) selecting within the survey area, a series of vibe paths within which one or more source trucks are to progress from shot
point to shot point through all of the shot points within the vibe path, and wherein listening paths comprise the listening
points within the vibe path and on either side of the vibe path within range of shot points within the vibe path where useful,
recordable seismic data may be recorded and active listening patch means the listening points within the listening path range
of the active shot points and comprise listening points so that listening points in the active listening patch are receiving
or will soon receive useful, recordable seismic data;

d) deploying a plurality of autonomous, continuously recording seismic recorders to the active listening patch, wherein the
plurality of the autonomous, continuously recording seismic recorders are arranged in a geographical array having an aspect
ratio of less than 5 to 1, wherein the aspect ratio is defined as the ratio of the longest transverse dimension of the geographical
shape to the shortest dimension of the geographical shape;

e) retrieving autonomous, continuously recording seismic recorders that are behind the active listening patch; and
f) re-deploying the retrieved autonomous, continuously recording seismic recorders to listening points in front of the active
listening patch within the listening path while the one or more source trucks progress from shot point to shot point.

US Pat. No. 9,164,187

ELECTRICAL ENERGY ACCUMULATOR

ConocoPhillips Company, ...

1. A vibratory seismic source for delivering acoustic energy into the ground for seismic prospecting, the source comprising:
a) a generator for creating electric power;
b) an electric power accumulator for storing electric power created by the generator;
c) about 100 to 5,000 linear motors arranged in a grid and carried by a frame, wherein each linear motor includes a rod that
is arranged to move generally vertically to contact the ground at a lower end of the rod; and

d) a control system for directing electricity from the generator and concurrently from the electric power accumulator to electrically
power movement of the rods such that the rods vibrate the ground and deliver acoustic energy into the ground.

US Pat. No. 10,655,450

IFR1 SURVEY METHODOLOGY

CONOCOPHILLIPS COMPANY, ...

1. A method of directional drilling, the method comprising:obtaining a single set of in-field referencing (IFR) values for a planned well, the single set of IFR values captured by measuring local geomagnetic field data at a single location in a mid-lateral section of the planned well;
generating an improved magnetic model by combining the single set of IFR values with a global magnetic model;
obtaining downhole magnetic field data, the downhole magnetic field data captured along a borehole using surveying instrumentation, the borehole being drilled for the planned well; and
determining an orientation of the borehole based on the downhole magnetic field data and the improved magnetic model.

US Pat. No. 10,564,305

EFFICIENT INTERNAL MULTIPLE PREDICTION METHODS

ConocoPhillips Company, ...

1. A method for seismic data processing comprising:obtaining seismic data for a subterranean structure, the seismic data including contribution from internal multiples;
solving a series of partial differential wave equations each representing a reflected portion of predicted internal multiples of the seismic data, wherein a first partial differential wave equation describes propagation of a seismic wave going from a first reflector to a second reflector, wherein a second partial differential wave equation describes propagation of the seismic wave going from the second reflector to a third reflector, and wherein a third partial differential wave equation describes propagation of the seismic wave going from the third reflector to a seismic receiver, the third partial differential wave equation providing the predicted internal multiples;
outputting the predicted internal multiples for attenuation; and
removing the predicted internal multiples from an image of the subterranean structure.

US Pat. No. 10,550,679

DEPRESSURIZING OIL RESERVOIRS FOR SAGD

ConocoPhillips Company, ...

1. A method for production of heavy oil, the method comprising:a) providing one or more horizontal downhole heater production wells (DHH wells) in a heavy oil reservoir at a first pressure, each of said DHH wells configured for electric downhole heating with an electric heater and configured for production of said heavy oil;
b) electrically heating each of said DHH wells and producing said heavy oil for a preconditioning period until said first pressure is reduced to a second pressure, wherein said second pressure is at least 20% less than said first pressure;
c) drilling one or more horizontal wellpairs after said preconditioning period, each of said wellpairs comprising an upper well parallel and over a lower well, each of said wellpairs positioned either beside one of said DHH wells or between a pair of said DHH wells;
d) injecting steam at a first steam injection temperature into said upper well and said lower well of each of said wellpairs until said upper well and said lower well of each of said wellpairs are in fluid communication;
e) converting said lower well of each of said wellpairs to a producer well and injecting steam at a second steam injection temperature only into said upper well of each of said wellpairs; and
f) producing said heavy oil at said lower well of each of said wellpairs with steam assisted gravity drainage (SAGD);
wherein said first and second steam injection temperatures are lower than in a method that is the same as said method but without step b.

US Pat. No. 10,526,866

CASING EXPANSION FOR WELL PLUGGING

ConocoPhillips Company, ...

1. A method of plugging a well or portion thereof, said method comprising:a) cutting an uncemented casing at a top of a plugging interval;
b) expanding said uncemented casing below said cut until an expanded tubing touches a reservoir wall surrounding said section in 360° throughout said plugging interval;
c) confirming that said expanded tubing touches the reservoir in 360° throughout said plugging interval; and
d) cementing said plugging interval.

US Pat. No. 10,526,887

DEPTH/ORIENTATION DETECTION TOOL AND METHODS THEREOF

ConocoPhillips Company, ...

1. A method for perforating a cemented casing in a wellbore, comprising the steps of:providing a target mass that is substantially radioactively inert into a casing cemented into a wellbore, disposed in a subterranean formation, wherein the casing is characterized by a longitudinal axis and a radial axis;
locating the target mass in proximity to the casing, wherein the target mass is situated at a known radial offset angle from a sensitive apparatus in said casing;
irradiating a region around the target mass in said casing;
detecting the radial location of the target mass in said casing as an area of reduced radioactive response;
determining a perforation target in said casing based on the radial location of the target mass and the known radial offset angle so as to reduce the risk of damage to the sensitive apparatus; and
perforating the casing at the perforation target in a direction substantially away from the sensitive apparatus so as to not damage the sensitive apparatus.

US Pat. No. 10,385,654

SYSTEM AND METHOD FOR SEALING MULTILATERAL JUNCTIONS

ConocoPhillips Company, ...

1. A method for sealing a multilateral well junction, comprising:(a) installing a prefabricated liner comprising a window with a metal sleeve in a well bore wherein the sleeve creates a solid section of a liner over said window;
(b) increasing a temperature of the metal sleeve of the prefabricated liner with a heater to form molten metal and open said window;
(c) distributing the molten metal of the metal sleeve of the prefabricated liner within an annulus between said prefabricated liner and said wellbore;
(d) solidifying the molten metal of the metal sleeve of the prefabricated liner by reducing the temperature of said molten metal;
(e) drilling a sidewell through said opened window;
(f) installing a prefabricated junction at said opened window to form a multilateral well junction, said prefabricated junction comprising a metal sleeve;
(g) increasing a temperature of the metal sleeve of the prefabricated junction with said heater to form a molten metal;
(h) distributing the molten metal of the metal sleeve of the prefabricated junction within an annulus at said multilateral well junction; and
(i) solidifying the molten metal of the metal sleeve of the prefabricated junction by reducing the temperature of said molten metal to form a seal, thereby sealing said multilateral well junction.

US Pat. No. 10,161,227

PERMANENT BYPASS WHIPSTOCK ASSEMBLY FOR DRILLING AND COMPLETING A SIDETRACK WELL AND PRESERVING ACCESS TO THE ORIGINAL WELLBORE

ConocoPhillips Company, ...

1. A process for drilling a sidetrack wellbore from a tailpipe through a liner pipe and into a desired formation, wherein the process comprises:a. incorporating a permanent bypass whipstock assembly into a section of a length of a tailpipe, wherein said permanent bypass whipstock assembly has an elongated generally cylindrical body, and within a middle section of said permanent bypass whipstock assembly, a primary path and a deviating sidetrack path, wherein said primary path extends from a first end and a second end and allowing complete access to production below the permanent bypass whipstock assembly; wherein said deviating sidetrack path has a downhole end along a peripheral side of said permanent bypass whipstock assembly and a uphole end closer to the first end of and open to said primary path of said permanent bypass whipstock assembly, wherein said tailpipe is releasably connected to the first and second ends of the primary path; wherein said permanent bypass whipstock assembly has a larger diameter than said tailpipe;
b. installing said permanent bypass whipstock and tailpipe into a production assembly;
c. introducing said production assembly inside a liner in a wellbore, wherein said permanent bypass whipstock assembly is in close proximity to said liner eliminating the need for cement, wherein said primary path of said permanent bypass whipstock assembly is slightly offset from an axis of said liner to create the larger diameter of the permanent bypass whipstock assembly as compared to the tailpipe, wherein said deviating sidetrack path diverges from said primary path at an incline to ultimately form the sidetrack wellbore, wherein the permanent bypass whipstock assembly reduces the clearance to no more than is necessary to run an additional permanent bypass whipstock assembly, a packer assembly or combinations thereof into the liner;
d. positioning said production assembly into a wellbore with the deviating sidetrack path of the permanent bypass whipstock assembly aligned in a predetermined direction for forming the sidetrack well which may later be drilled;
e. sealing said wellbore with said production assembly;
f. installing a diverter, wherein the diverter closes said primary path below the desired location of said sidetrack well, wherein the diverter is installed independent of the permanent bypass whipstock assembly, wherein said diverter directs tools from the primary path to said deviating sidetrack path, wherein the diverter is retrievable;
g. installing a milling system, wherein the milling system includes a milling bit at the downhole end of a drill string whereby when the milling system reaches the diverter the milling system is deflected onto said deviating sidetrack path and continues along the deviating sidetrack path whereby the milling system forms a window in the liner;
h. removing the milling system;
i. installing a drill system, wherein the drill system includes a drillbit located at the downhole end of a drill string, wherein the drill system runs through the primary path and through the permanent bypass whipstock assembly whereby the drill system is diverted onto the deviating sidetrack path by the diverter whereby the drill system reaches the window formed in the liner by the milling system;
j. drilling a sidetrack wellbore with the drill system at an angle between 1.5 to 3 degrees;
k. removing the drill system; and
l. installing a liner pipe casing into the sidetrack wellbore, wherein the liner pipe is run down said primary path and through said permanent bypass whipstock assembly whereby said liner pipe is diverted onto the deviating sidetrack path by the diverter,wherein the liner pipe casing substantially supports the formation exposed by the window,wherein said permanent bypass whipstock assembly is permanently installed in said wellbore.

US Pat. No. 10,633,956

DUAL TYPE INFLOW CONTROL DEVICES

ConocoPhillips Company, ...

2. A dual type inflow control device (dual-type ICD), comprising:a) a tube and a sleeve fitting over said tube, said sleeve having at least one inlet, and said tube having at least one opening to an interior of said tube; and
b) an annulus between said tube and said sleeve having a fluidic pathway therein from said inlet to said opening, said fluidic pathway having a first pattern and a second pattern different from said first pattern;
where said first and second patterns are arranged in series, and said first pattern is helical and said second pattern is hybrid channel and wherein said helical channel fluidic pathway is optimized for a production phase of SAGD and said hybrid channel fluidic pathway is optimized for a startup phase of SAGD.

US Pat. No. 10,633,957

REDUCING SOLVENT RETENTION IN ES-SAGD

ConocoPhillips Company, ...

1. A method of producing hydrocarbons from a subterranean formation that has at least one injection well and at least one producing well that can communicate with at least a portion of said formation, and said injection well being in fluid communication with said production well, the method being an Expanding Solvent-Steam-Assisted Gravity Drainage (ES-SAGD) and SAGD combination consisting essentially of:a) co-injecting a fluid comprising 75% steam and 25% solvent at a first pressure into said injection well for a first period of time of approximately 4.5 years, wherein said solvent comprises a mixture with between 85 and 95 v % of C5 to C12 hydrocarbons;
b) co-producing said hydrocarbons and said solvent from said production well;
c) recapturing said solvent that is co-produced along with said hydrocarbons, and recycling said recaptured solvent in step a); and,
d) injecting steam only into the injection well at a second pressure for a second period of time after said first period of time and producing said hydrocarbons from said production well,
wherein said second pressure is lower than said first pressure.

US Pat. No. 10,633,969

DYNAMIC IN-SITU MEASUREMENT OF RESERVOIR WETTABILITY

ConocoPhillips Company, ...

1. A method for in-situ characterization of a wettability of a reservoir rock in a subterranean formation, comprising:(a) sealing an interval corresponding to a selected depth or depths within a reservoir rock in a subterranean formation;
(b) injecting a displacement fluid into the interval, wherein the displacement fluid displaces a reservoir fluid stored in the reservoir rock via imbibition;
(c) measuring a rate of a front of said displacement fluid or said reservoir fluid movement in the reservoir rock via a nuclear magnetic resonance (NMR) logging tool to obtain an imbibition rate; and
(d) assessing real-time wettability of the reservoir rock based on the imbibition rate measured in step (c).

US Pat. No. 10,545,260

UPDATING GEOLOGICAL FACIES MODELS USING THE ENSEMBLE KALMAN FILTER

Conocophillips Company, ...

1. A computer-based method of history matching a facies geostatistical model of a hydrocarbon reservoir, the method comprising:creating an ensemble of initial realizations of a facies geostatistical model in which each one of the initial realizations is a function of at least one of a plurality of initial uniform random vectors, the model being a discontinuous multipoint simulation model;
deriving simulated dynamic responses from each initial realization of the ensemble of initial realizations for a given time period;
performing a Gaussian score transform on each initial uniform random vector to create an ensemble of initial Gaussian random vectors;
deriving a correlation matrix correlating each one of the initial Gaussian random vectors and the simulated dynamic responses, and correlating the simulated dynamic responses with each other;
obtaining measured data from a reservoir for the given time period;
using the correlation matrix, applying ensemble Kalman filter, using a computing processor, to the ensemble of initial Gaussian random vectors to update the ensemble of initial Gaussian random vectors to the measured data, thereby creating updated Gaussian vectors;
computing updated uniform vectors corresponding to the updated Gaussian vectors;
deriving from the updated uniform vectors an ensemble of updated realizations; and
generating a channel probability map based on the ensemble of updated realizations,
wherein,
the method preserves statistical data and geological features of the model.

US Pat. No. 10,488,546

AUTONOMOUS ELECTRICAL METHODS NODE

CONOCOPHILLIPS COMPANY, ...

1. A system for evaluating and measuring geometry of a fracture, the system comprising:a grid of receivers arranged on a surface, wherein each receiver includes at least one geophysical receiver package connected to a seismic interface box, wherein the grid of receivers is time stamped and synchronized to a global position time to measure a baseline surface, and wherein the grid of receivers detects an electrical signal conducted along and reflected back from an electrically active proppant;
an electromagnetic coil attached to the seismic interface box; and
the seismic interface box connected to an autonomous seismic data node, wherein the seismic interface box coverts the electrical signal received from the at least one geophysical receiver package into a voltage signal compatible with the autonomous seismic data node, and a fracture geometry is determined by at least one of an inversion technique or a modelling technique of the voltage signal.

US Pat. No. 10,392,271

METHOD OF REMOVING HYDROGEN-SULFIDE FROM WATER

CONOCOPHILLIPS COMPANY, ...

1. A method for removing hydrogen sulfide from a liquid stream comprising produced water from an underground oil or gas producing operation, the method comprising:contacting a first side of a porous, gas-liquid separation membrane with a liquid stream comprising a first amount of hydrogen sulfide; and
contacting a second, opposite side of the separation membrane with a receiving fluid having a lower concentration of hydrogen sulfide than the liquid stream, wherein the hydrogen sulfide moves through the pores of the membrane from the first side to the second side, to provide a reduced-sulfide liquid stream having a second amount of hydrogen sulfide that is less than the first amount of hydrogen sulfide in the liquid stream, wherein the receiving fluid comprises water and an organic amine reactive with hydrogen sulfide.

US Pat. No. 10,302,429

SEISMIC STREAMER SHAPE CORRECTION USING DERIVED COMPENSATED MAGNETIC FIELDS

CONOCOPHILLIPS COMPANY, ...

1. A method for estimating a location of each hydrophone in a seismic streamer, the method comprising:towing, via a seismic vessel, a seismic streamer comprising a plurality of hydrophones disposed along a cable in a series and a plurality of magnetic compasses interspersed between the plurality of hydrophones;
measuring, via the plurality of magnetic compasses, a plurality of azimuths, each of the plurality of magnetic compasses measuring one of the plurality of azimuths and transmitting the one of the plurality of azimuths to the seismic vessel;
towing, via the seismic vessel, an instrument assembly vessel while the plurality of azimuths are measured by the plurality of magnetic compasses, the instrument assembly vessel comprising (a) an inertial reference direction device configured to measure a deviation of an aiming direction of the instrument assembly vessel from a reference direction, and (b) a reference magnetic compass configured to measure an ambient magnetic field direction with respect to the aiming direction of the instrument assembly vessel and to transmit the ambient magnetic field direction;
measuring a first deviation of the aiming direction of the instrument assembly vessel from the reference direction using the inertial reference direction device;
measuring a second deviation of the aiming direction of the instrument assembly vessel from the ambient magnetic field direction using the reference magnetic compass;
calculating a third deviation of the ambient magnetic field direction from the reference direction using the first deviation and the second deviation;
calculating a corrected azimuth for each of the plurality of magnetic compasses using the plurality of azimuths and the third deviation;
estimating a location of each of the plurality of hydrophones using the corrected azimuth for each of the plurality of magnetic compasses; and
displaying the location of each of the plurality of hydrophones.

US Pat. No. 10,287,874

HYDRAULIC FRACTURE MONITORING BY LOW-FREQUENCY DAS

ConocoPhillips Company, ...

1. A method of optimizing a hydraulic fracturing stimulation of a reservoir comprising:a) installing one or more fiber optic cables in at least one wellbore;
b) attaching said one or more fiber optic cables to an interrogator having interrogation and reflection recording functions;
c) fracturing a stage of a multistage hydraulic fracturing stimulation in a reservoir using pre-determined parameters;
d) interrogating at least one of said fiber optic cable with an interrogation signal during said fracturing step;
e) recording one or more reflected datasets;
f) converting said one or more reflected datasets into a continuous record;
g) transforming the continuous record with a low-pass filter transform with a range of greater than 0 to 50 millihertz (mHz) to provide a transformed record;
h) down sampling the transformed record;
i) interpreting the down-sampled transformed record to provide an interpreted record;
j) optimizing said pre-determined parameters of said hydraulic fracturing stimulation using said interpreted record to provide optimized parameters; and,
k) using said optimized parameters for fracturing a subsequent stage in said reservoir.

US Pat. No. 9,920,596

COAL BED METHANE RECOVERY

CONOCOPHILLIPS COMPANY, ...

1. A method comprising:
inserting a first electrode in a first well and a second electrode in a second well each intersecting a subterranean formation
containing coal, said first and second electrodes in electrical contact with the formation;

passing electric current through water from the first well to the second well by applying a voltage across the first and second
electrodes for resistive heating of the water within the formation;

heating the water such that the temperature of the coal remains below an in-situ boiling point of the water;
recovering methane desorbed from the coal due to the coal being heated by the water and without the coal being heated above
a pyrolysis temperature of the coal; and

dewatering of the formation concurrent with the recovering of the methane,
wherein said water maintains an electrical conduit between the first and second electrodes heating water in the formation
between the first and second wells.

US Pat. No. 9,702,237

HYBRID STEAM GENERATION WITH CARBON DIOXIDE RECYCLE

ConocoPhillips Company, ...

1. A method of recovering hydrocarbons with steam, comprising:
generating steam in a first device in which combustion heats water for vaporization and exhaust from the combustion remains
separated from the steam produced;

generating steam in a second device in which water vaporizes by direct contact with combustion products to produce a resulting
fluid including the steam and carbon dioxide;

injecting the steam from the first device and the fluid from the second device into a formation to facilitate recovery of
a mixture including the hydrocarbons, condensate of the steam and the carbon dioxide; and

processing the mixture to separate out the carbon dioxide from said mixture; and
recycling said separated carbon dioxide by injection into said formation.

US Pat. No. 9,651,300

SEMI-CLOSED LOOP LNG PROCESS

CONOCOPHILLIPS COMPANY, ...

1. A method for liquefying a natural gas stream comprising the steps of:
providing a liquefied natural gas facility having at least three sequential cooling cycles, each employing a different refrigerant;
wherein the at least three sequential cooling cycles comprise a first cooling cycle with a first refrigerant, a second cooling
cycle with a second refrigerant, and a third cooling cycle with a third refrigerant, wherein the third refrigerant is a predominantly
methane refrigerant;

wherein the third cooling cycle comprises an open-loop methane refrigeration cycle;
cooling the natural gas stream in the first cooling cycle with the first refrigerant;
cooling the natural gas stream in the second cooling cycle with the second refrigerant;
introducing the natural gas stream to a heavies removal column for separating the natural gas stream into a heavies stream
and a heavies-reduced natural gas stream;

compressing a predominantly methane stream to form a compressed methane refrigerant;
separating the compressed methane refrigerant into a first compressed methane refrigerant portion and a second compressed
methane refrigerant portion;

cooling the first compressed methane refrigerant portion in the second cooling cycle via indirect heat exchange with the second
refrigerant to form a cooled intermediate refrigerant;

combining the cooled intermediate refrigerant with the second compressed methane refrigerant portion to form an intermediate
refrigerant stream;

separating the intermediate refrigerant stream into a third compressed methane refrigerant portion and a fourth compressed
methane refrigerant portion;

introducing the heavies-reduced natural gas stream into the open-loop methane refrigeration cycle by combining the heavies-reduced
natural gas stream with the third compressed methane refrigerant portion to form a combined stream;

introducing the combined stream into a methane economizer for cooling to form a first natural gas stream;
cooling the fourth compressed methane refrigerant portion in the second cooling cycle via indirect heat exchange with the
second refrigerant to form a cooled methane refrigerant product;

introducing the cooled methane refrigerant product to a methane refrigerant accumulation vessel wherein a liquid level is
formed in the methane refrigerant accumulation vessel;

controlling a liquid level in the methane refrigerant accumulation vessel by adjusting a flow of the third compressed methane
refrigerant portion with respect to a flow of the fourth compressed methane refrigerant portion to maintain the liquid level
in the methane refrigerant accumulation vessel;

introducing the cooled methane refrigerant product from the methane refrigerant accumulation vessel into the methane economizer
for cooling to form the predominately methane refrigerant;

cooling the first natural gas stream in a plurality of separate heat exchangers via indirect heat exchange with the predominately
methane refrigerant to form a liquefied natural gas product and a vapor portion of the first natural gas stream;

combining a portion of the predominately methane refrigerant with the vapor portion of the first natural gas stream to form
part of the predominantly methane stream that is compressed.

US Pat. No. 10,605,043

DEGRADABLE PUMP IN SHOE

ConocoPhillips Company, ...

9. A process for cementing hydrocarbon well comprising:placing a bottom plug with a low pressure diaphragm in a production casing in a wellbore;
injecting cement on top of the bottom plug in the production casing;
placing a top plug in the production casing, wherein the top plug comprises
an interlocking nose,
a hollow body,
a degradable plug, and
an interlocking tail;
injecting a wash solution on top of the top plug until the top plug is tightly sealed upon the bottom plug; and
degrading the degradable plug,
wherein the production casing is in fluid communication with the wellbore after the degradable plug is degraded.

US Pat. No. 10,590,736

FUSIBLE ALLOY PLUG IN FLOW CONTROL DEVICE

ConocoPhillips Company, ...

1. An apparatus for controlling hydraulic flow along a length of a well, comprising:a. a plurality of pipe joints including a plurality of passive flow control devices (“FCDs”) in a well in a reservoir;
b. each FCD having an exclusion media to limit particulate flow into said FCD;
c. each FCD having one or more apertures therein to restrict hydraulic flow into said FCD;
d. each FCD having one or more temporary fusible alloy plugs securely installed into said one or more apertures to temporarily block hydraulic flow into said FCD;
e. each FCD's plugs having different melting points, such that a first FCD has first plugs that melt at Tm1, which is higher than a temperature of said reservoir, and a second FCD has second plugs that melt at Tm2, which is higher than Tm1, thus allowing for the passive removal of said first plugs upon heating said reservoir to Tm1 and thereby controlling hydraulic flow along a length of said well without mechanical intervention.

US Pat. No. 10,472,942

BLOWDOWN PRESSURE MAINTENANCE WITH FOAM

ConocoPhillips Company, ...

1. A method for recovering petroleum from a formation containing heavy hydrocarbons, wherein an injection well and a production well are in fluid communication with the formation, and wherein the method comprises:a) injecting a first fluid into the formation through the injection well in an enhanced oil recovery process to form a chamber in the formation, wherein the first fluid comprises one or more of solvents, steam, and combinations thereof;
b) recovering a second fluid comprising heavy hydrocarbons from the production well with said enhanced oil recovery process and forming a mature chamber, wherein economic recovery can no longer be achieved with said enhanced oil recovery process;
c) engaging in blowdown operations after the formation of the mature chamber, wherein the blowdown operations comprise (i) ceasing said injecting the first fluid into the injection well and said enhanced oil recovery process; and (ii) providing a foam in the mature chamber to maintain pressure in the mature chamber with said foam instead of the first fluid; and
d) recovering the second fluid comprising heavy hydrocarbons during the blowdown operations.

US Pat. No. 10,227,865

SYSTEM AND METHOD FOR DETERMINING DRILL STRING MOTIONS USING ACCELERATION DATA

CONOCOPHILLIPS COMPANY, ...

1. A method comprising:(a) determining gravitational and centripetal accelerations by performing a local running mean of acceleration measurements from a drill pipe;
(b) removing the local running mean to yield corrected acceleration data due to vibration only;
(c) transforming the corrected acceleration data from a local rotating coordinate frame to a global stationary coordinate frame; and
(d) mapping in real time, the acceleration data in the global stationary coordinate frame into continuous drill-string positions,
wherein the acceleration data is mapped into the continuous drill-string positions using:
P(x,y,z,t+dt)=P(x,y,z,t)+??a(x,y,z,t)dt2,
where P(x, y, z, t) is a position vector in a global stationary coordinate frame referenced at a center of the drill pipe; a(x, y, z, t) is an acceleration vector in the global stationary coordinate frame referenced at the center of the drill pipe; t is travel time of the drill pipe; and dt is time interval the drill pipe moves from P(x, y, z, t) to P(x, y, z, t+dt).

US Pat. No. 10,161,221

DUAL VACUUM INSULATED TUBING WELL DESIGN

ConocoPhillips Company, ...

1. A method of well completion in cold reservoirs, said method comprising completing at least a portion of injector wells and producer wells with concentric dual vacuum insulated piping, said concentric dual vacuum insulated piping comprising an outer vacuum insulated piping surrounding an inner vacuum insulated piping, and further comprising couplings surrounding said outer vacuum insulated piping that are staggered from couplings surrounding said inner vacuum insulated piping, wherein said dual vacuum insulated piping mitigates heat loss more than single vacuum insulated piping, wherein said dual vacuum insulated piping with staggered coupling mitigates heat loss more than dual vacuum insulated piping without staggered couplings;wherein each vacuum insulated piping has two nested pipes with a vacuum therebetween.

US Pat. No. 9,920,985

LIQUEFIED NATURAL GAS PLANT WITH ETHYLENE INDEPENDENT HEAVIES RECOVERY SYSTEM

CONOCOPHILLIPS COMPANY, ...

1. A method for liquefaction of natural gas comprising:
cooling a portion of a natural gas feed stream in a first propane refrigeration stage to produce a cooled natural gas feed
stream;

splitting the cooled natural gas feed stream into first and second portions upstream of a second propane refrigeration stage,
wherein the first portion of the cooled natural gas feed stream is cooled in the second propane refrigeration stage prior
to combining upstream of a third propane refrigeration stage the first and second portions of the cooled natural gas feed
stream to form a combined natural gas stream upon the second portion of the cooled natural gas feed stream being cooled by
a heavies-rich stream;

separating the combined natural gas stream cooled in the third propane refrigeration stage into a first lights stream and
a first heavies stream;

expanding the first lights stream to form an expanded first lights stream;
separating the expanded first lights stream into a second lights stream and a second heavies stream;
introducing at least a portion of the first heavies stream, at least a portion of the second heavies stream and at least a
portion of the second lights stream into a heavies removal column to form a first heavies-depleted stream and the heavies-rich
stream;

separating at least a portion of the heavies-rich stream into a second heavies-depleted stream and a heavier stream;
compressing the second heavies-depleted stream into a compressed second heavies-depleted stream; and
combining downstream of the heavies removal column the first heavies-depleted stream and at least part of the second heavies-depleted
stream for further cooling into liquefied natural gas product, wherein the first and second heavies-depleted streams are combined
upstream of an initial stage chiller of an ethylene refrigeration cycle providing at least part of the further cooling into
the liquefied natural gas product.

US Pat. No. 9,896,359

CHEMICAL TREATMENT FOR ORGANIC FOULING IN BOILERS

ConocoPhillips Company, ...

1. A method of generating steam, comprising:
adding at least 10 parts per million of a polymerization inhibitor to feed water with a dissolved molecular oxygen and dissolved
organic species, wherein a concentration of the dissolved molecular oxygen is less than one part per million, wherein said
polymerization inhibitor inhibits coupling of said dissolved organic species; and

supplying the feed water to a boiler for producing steam, with coupling of the dissolved organic species under boiler conditions
limited by the polymerization inhibitor.

US Pat. No. 9,632,193

COMPRESSIVE SENSING

ConocoPhillips Company, ...

1. A computer-implemented method for determining optimal sampling grid during seismic data reconstruction, the method comprising:
a) constructing an optimization model, via a computing processor, given by minu?Su?1 s.t. ?Ru?b?2?? wherein S is a discrete transform matrix, b is seismic data on an observed grid, u is seismic data on a reconstruction
grid, ? represents noise level in observed data, and matrix R is a sampling operator;

b) defining mutual coherence as

 wherein r is sampling grid, r1 are Fourier transform coefficients, ?=exp(?2??{square root over (?1)}/n), and n is number of elements in r;

c) deriving a mutual coherence proxy, wherein the mutual coherence proxy is a proxy for mutual coherence when S is over-complete
and wherein the mutual coherence proxy is exactly the mutual coherence when S is a Fourier transform; and

d) determining a sample grid r*=arg minr ?(r).

US Pat. No. 10,634,802

PRIME NUMBER SURVEY DESIGN

ConocoPhillips Company, ...

1. A method of acquiring seismic data of a subsurface, the method comprising:implementing a seismic survey design using:
a plurality of spaced seismic energy source stations arranged in a linear fashion to form a plurality of source lines, wherein a first ratio of source line spacing to source station spacing is a prime number greater than one to one (prime:1), and
a plurality of spaced seismic energy receiver stations arranged in the linear fashion to form a plurality of receiver lines, wherein a second ratio of receiver line spacing to receiver station spacing is another prime number greater than one to one (prime:1);
performing a seismic survey in accordance with the seismic survey design;
recording seismic data obtained via the seismic survey; and,
mapping the subsurface with the recorded seismic data,
wherein,
the first ratio and the second ratio are different prime numbers.

US Pat. No. 10,634,814

ADVANCED PARALLEL “MANY-CORE” FRAMEWORK FOR RESERVOIR SIMULATION

ConocoPhillips Company, ...

1. A method of simulation of a reservoir model, comprising:receiving physical information about a reservoir, wherein the physical information includes at least one of well logs, seismic surveys, structural and stratigraphic mapping, and/or production history;
generating a reservoir geological model from the physical information, wherein the reservoir model comprises a plurality of blocks;
applying a predetermined equation set to each of the plurality of blocks depending on a physics model being simulated;
processing the reservoir model, by choosing one or more heuristic rules, the one or more heuristic rules determining a combination of one or more software components and one or more hardware components for the predetermined equation set for each of the plurality of blocks, wherein the one or more hardware components includes a plurality of central processing units (CPUs) and a plurality of graphics processing units (GPUs), the plurality of CPUs and the plurality of GPUs defining a ratio of CPUs to GPUs;
solving the predetermined equation set of each of the plurality of blocks serially and in parallel using the combination of the one or more software components and/or the one or more hardware components;
adjusting, dynamically, a quantity of CPUs within the plurality of CPUs and/or a quantity of GPUs within the plurality of GPUs, wherein the one or more heuristic rules determines the quantity of CPUs and the quantity of GPUs as the reservoir model is processed.

US Pat. No. 10,605,941

METHODS FOR SIMULTANEOUS SOURCE SEPARATION

ConocoPhillips Company, ...

1. A multi-stage inversion method for deblending seismic data, the method comprising:a) acquiring, via a plurality of shots fired from at least one vessel, blended seismic data from a plurality of seismic sources using a compressive sensing sampling scheme, the at least one vessel driven at a constant speed while permitting natural causes to affect the constant speed;
b) constructing an optimization model that relates the blended seismic data to unblended seismic data;
c) performing sparse inversion, via a computer processor, on the optimization model to yield a result;
d) estimating high-amplitude coherent energy from the result;
e) re-blending the high-amplitude coherent energy; and
f) computing a deblended seismic data by attenuating at least a portion of the high-amplitude coherent energy from the blended seismic data.
US Pat. No. 10,597,579

ANTI-RETENTION AGENT IN STEAM-SOLVENT OIL RECOVERY

ConocoPhillips Company, ...

1. A method of producing hydrocarbons from a subterranean formation comprising rock and hydrocarbon that has at least one injection well and at least one producing well in fluid communication with each other, the method comprising:co-injecting steam and solvent into said injection well;
selecting an anti-retention agent having a density between 0.000598-0.0770 g/cm3 and a viscosity between 0.0123-0.0216 cP and a higher affinity for said solvent than does water or said rock;
injecting said anti-retention agent comprising a foam or a colloidal dispersion or a gel into said injection well,
producing production fluids comprising hydrocarbon, water and solvent from said production well; and
recovering solvent from said production fluids, wherein more solvent is recovered than would be recovered without the injecting of said anti-retention agent.

US Pat. No. 10,408,055

CRUSTAL AND DISTURBANCE FIELD SURVEY CORRECTION

CONOCOPHILLIPS COMPANY, ...

1. A system to continuously control drilling in an area based on a real-time on-site magnetic survey of the area, the system comprising:an autonomous vehicle operable to traverse over a predetermined area;
a magnetometer coupled to the autonomous vehicle and operable to obtain magnetic measurements at a controlled rate, the magnetometer obtaining a uniform sampling of the magnetic measurements over the predetermined area;
a processor configured to obtain the magnetic survey from the magnetic measurements and determine the azimuth of a borehole formed within a subterranean formation; and
a controller operably coupled with a drill string, the controller operable to continuously adjust a drill bit disposed on the drill string based on the azimuth of the borehole as determined by the magnetic survey, wherein the controller operably adjusts the drill bit to a predetermined well path.

US Pat. No. 10,392,266

TREATMENT OF PRODUCED WATER USING INDIRECT HEAT

CONOCOPHILLIPS COMPANY, ...

1. A method of generating steam for enhanced oil recovery techniques, comprising:admitting a batch of untreated water into a batch vessel, wherein the batch vessel has a demister and at least one heating coil in contact with the untreated water;
passing a heated waste flue gas stream through the at least one heating coil, wherein the heated waste flue gas has a temperature between 170° C. and 240° C.;
heating the at least one heating coil with the heated waste flue gas;
vaporizing the batch of untreated water with the heated heating coil to create intermediate steam;
flowing the intermediate steam through the demister to remove solids;
condensing the intermediate steam in a condenser to form an overhead gas stream and a condensed water stream;
separating the overhead gas stream and the condensed water stream;
passing the overhead gas stream through a knock out drum to remove residual water;
combining the residual water and the condensed water stream to form a treated water; and
heating the treated water in a furnace to generate an injection steam for the enhanced oil recovery and to generate the heated waste flue gas stream passed through the at least one heating coil.

US Pat. No. 10,267,009

METHOD OF FORMING A MUDLINE CELLAR FOR OFFSHORE ARCTIC DRILLING

ConocoPhillips Company, ...

1. A method of forming a mudline cellar comprising:positioning a mudline cellar forming member on a seafloor surface, the mudline cellar forming member having a cylindrical cross section and including a first open end and a second open end opposite said first end and a continuous outer surface and a continuous inner surface between said first end and said second end that defines an uninterrupted inner cavity;
driving the mudline cellar forming member into the seafloor surface with a pile driver system using a plurality of impact forces on said first end of the mudline cellar forming member;
lowering a water jet and a vacuum to said inner cavity; and
delivering a pressurized stream of sea water via said water jet into said inner cavity to break up a portion of seafloor and vacuuming said portion of seafloor via said vacuum,
thereby excavating the inner cavity of the mudline cellar forming member from said first end to said second end to establish a mudline cellar,
wherein the entire excavated inner cavity is devoid of seafloor, and
wherein there is substantially no change in structural integrity of the seafloor surface outside of the mudline cellar.

US Pat. No. 10,228,475

OPTIMAL SURVEY DESIGN

CONOCOPHILLIPS COMPANY, ...

1. A method of evaluating a seismic survey design, the method comprising:a) determining locations of a plurality of seismic sources and a plurality of receivers geographically in a seismic survey design;
b) summing responses, offsets, and azimuth relationships for the locations in a central midpoint space (CMP);
c) compiling said responses, said offsets and said azimuth relationships for the locations into a CMP array;
d) applying an F-K transform to said CMP array;
e) applying a frequency-wavenumber filter to said CMP array;
f) evaluating the CMP array for artifacts;
g) modifying said seismic survey design to reduce said artifacts;
h) repeating steps a-f to yield an optimal seismic survey design, the optimal seismic survey design having said artifacts reduced; and
i) applying said optimal seismic survey design to a reservoir by changing one or more of the locations of the plurality of seismic sources and/or the plurality of receivers to minimize said artifacts.

US Pat. No. 10,126,450

BLACK HOLE BOUNDARY CONDITIONS

CONOCOPHILLIPS COMPANY, ...

1. A method of seismic processing and imaging to avoid image distortion, said method comprising the steps of:i) obtaining a base case seismic data from a subterranean formation, said base case seismic data including a base case image of said subterranean formation;
ii) determining a black hole region in said subterranean formation, wherein said black hole region has at least one physical characteristic not readily available and insufficient information for accurate seismic modeling;
iii) defining a black hole boundary condition around said black hole region to reduce or eliminate image distortion wherein image distortion is caused by seismic energy waves interacting with said boundary;
iv) performing seismic forward modeling with said black hole boundary condition applied thereto;
v) generating a reservoir image from said modeling;
vi) comparing said reservoir image with said base case image to determine an impact of the black hole region on said reservoir image; and
vii) obtaining a revised reservoir image of the subterranean formation by correcting for said impact.

US Pat. No. 9,605,520

IN-SITU ZONAL ISOLATION AND TREATMENT OF WELLS

ConocoPhillips Company, ...

1. A process for isolating and treating a first fluid producing zone of an underground formation in an earthen well where
the well includes a second fluid producing zone and a filter media within an annular production space extending between a
tubular production pipe and the underground formation or casing pipe, where access from the surface through the tubular production
pipe to the second fluid producing zone is preserved for subsequent production following the isolating and treating procedure,
wherein the process for isolating the first zone comprises:
a) installing a removable sealing element into the tubular production pipe at a level further into the ground than the first
fluid producing zone;

b) injecting a settable or reactive low viscosity permeability poison into the tubular production pipe and out into the filter
media in the annular production space to fill a segment of the filter media in the annular production space between the first
and second fluid producing zones to eventually separate and substantially seal the first and second zones from one another
against fluid flow in the filter media in the annular production space;

c) converting the settable or reactive low viscosity permeability poison in the filter media into a fluid seal forming a barrier
against flow within a sand control screen in the annular production space;

d) injecting a treatment material into the tubular production pipe onto the fluid seal and through the annular production
space and into the formation at the first fluid producing zone; and,

e) opening up the interior of the tubular production pipe to regain access to the second fluid producing zone by removing
portions of said treatment material, the fluid seal and an isolation material within the tubular production pipe so that fluids
may enter the production pipe from the second zone and be extracted to the surface past the now treated first fluid producing
zone.

US Pat. No. 10,633,600

PROCESS FOR REMOVING MERCURY FROM CRUDE OIL

ConocoPhillips Company, ...

1. A method of removing mercury from crude oil, comprising:a) mixing an organic phosphite with a crude oil comprising mercury in various forms to form a crude oil mixture;
b) heating said crude oil mixture to at least 100° C. and less than 200° C. until at least 95% of the mercury in various forms is converted to elemental mercury;
c) converting the elemental mercury to gaseous elemental mercury; and
d) removing the gaseous elemental mercury from said crude oil.

US Pat. No. 10,550,663

METHODS, SYSTEMS, AND DEVICES FOR SEALING STAGE TOOL LEAKS WITH MELTABLE ALLOY

ConocoPhillips Company, ...

1. A stage tool for wellbore cementing, comprising:an external stage tool body; and
a sliding sleeve within the external stage tool body configured to regulate cement flow through the stage tool;
wherein the external stage tool body comprises a body cement port; and the sliding sleeve comprises a sleeve cement port;
wherein the sliding sleeve is configured to have a closed configuration wherein the body cement port and the sleeve cement port are not aligned, and an open configuration wherein the body cement port and the sleeve cement port are aligned to allow cement flow to a wellbore;
wherein the sliding sleeve comprises a meltable alloy configured to seal a leak; and
wherein the meltable alloy is configured to be melted by a heating source, flow into the leak, and resolidify as the melted alloy cools, thereby sealing the leak.

US Pat. No. 10,544,883

CONDUIT SEAL ASSEMBLY

ConocoPhillips Company, ...

1. A gas processing container for liquefying gases, comprising:a plurality of walls configured to form a chamber having an air-tight seal;
gas processing equipment in the chamber to convert gaseous materials to liquid, at least some of the gas processing equipment configured to operate inside the chamber at temperatures of 0 degrees Celsius or below; and
a conduit seal assembly extending through a first wall of the plurality of walls, the conduit seal assembly comprising:
an outer conduit having a first end with a first opening and a second end, opposite the first end, with a second opening;
a first seal in the first opening for resisting a first range of temperatures;
a second seal in the second opening for resisting a second range of temperatures that extends below the first range of temperatures, the first and second seals defining a cavity and providing an air-tight seal of the cavity; and
a temperature-resistant internal boot that further protects the second end, wherein the temperature-resistant internal boot maintains flexibility at temperatures of ?150 degrees Celsius and below.

US Pat. No. 10,508,048

REMOVAL OF OIL RECOVERY CHEMICALS FROM PRODUCTION FLUIDS

ConocoPhillips Company, ...

1. A method of processing production fluid, comprising;receiving production fluid from a borehole in an earth formation, the production fluid including surfactants injected into the earth formation to stimulate production of hydrocarbons therefrom;
processing the production fluid to separate the production fluid into at least an oil phase and a produced water, and softening produced water to remove metal cations therefrom;
introducing a treatment fluid from a treatment fluid source into the produced water, the treatment fluid including a concentration of multivalent cations, the multivalent cations configured to reduce water solubility of the surfactants and directing at least a portion of a reject stream from the softening step into the produced water, the reject stream including the metal cations removed from the produced water; and
removing the surfactants from the produced water.

US Pat. No. 10,488,552

FLOW CONTROL DEVICE SIMULATION

ConocoPhillips Company, ...

1. A method of improving steam assisted gravity drainage (SAGD) in a reservoir, comprising:a) determining a function for differential pressure through a well flow control device based on properties including flow rate, density, viscosity, steam quality, pressure and temperature of a fluid that includes both water and steam, wherein said well flow control device is modeled as a series of chokes separated by chambers, wherein pressure drop calculations are applied to said chokes and enthalpy steam flash calculations are applied to said chambers;
b) transforming the function for differential pressure to an input parameter of a reservoir model of a reservoir;
c) simulating hydrocarbon production in said reservoir model while accounting for both the flow control device and the reservoir; and
d) optimizing a SAGD completion in said reservoir based on said simulated hydrocarbon production from step c), thereby improving SAGD in said reservoir.

US Pat. No. 10,416,349

PHASE PREDICTIONS USING GEOCHEMICAL DATA

CONOCOPHILLIPS COMPANY, ...

1. A method of predicting fluid phase behavior in a reservoir, the method comprising:extracting at least one petroleum sample from one or more predetermined locations of the reservoir, the at least one petroleum sample including at least one of a reservoir fluid, a mud gas, or core and cutting extracts;
estimating a thermal maturity of the at least one petroleum sample;
estimating an API gravity, a condensed gas ratio (CGR), and a gas to oil ratio (GOR) of the at least one petroleum sample using a predetermined correlation with the thermal maturity;
estimating a hydrocarbon component composition and a gas gravity of the at least one petroleum sample reservoir fluid from the API gravity and the CGR and the GOR, the hydrocarbon component composition comprising C1 to C6 components and a C7+ fraction;
obtaining one or more critical properties for each of the C1 to C6 components in the hydrocarbon component composition of the at least one petroleum sample;
splitting the C7+ fraction in the hydrocarbon component composition of the at least one petroleum sample into C7 to Cn components (where n>7);
estimating one or more mole fractions and one or more critical properties for the C7 to Cn components in the hydrocarbon component composition of the reservoir fluid;
reducing the hydrocarbon component composition of the at least one petroleum sample by lumping one or more hydrocarbon components to form one or more lumped components;
building a pseudo equation-of-state (EOS) model using the hydrocarbon component composition of the at least one petroleum sample, the one or more critical properties of the C1 to C6 components and the one or more critical properties for the C7 to Cn components, Peneloux volume shift parameters and binary interaction parameters for the one or more lumped components and any unlumped components along with EOS constants for a given EOS model;
comparing pseudo EOS model calculations with the CGR, GOR, API and gas gravity;
generating a final EOS model by tuning the pseudo EOS model until the pseudo EOS model calculations are within predetermined tolerance limits of the CGR, GOR, API and gas gravity;
generating a prediction of fluid phase behavior and properties of the reservoir with the final EOS mode; and
performing at least one drilling operation at the reservoir based on the prediction of fluid phase behavior and properties.

US Pat. No. 10,408,054

METHOD FOR ESTIMATING STRESS MAGNITUDE

CONOCOPHILLIPS COMPANY, ...

1. A method of calculating principal horizontal stresses along a wellbore into a subterranean formation, the method comprising:obtaining physical properties of the wellbore, the physical properties comprising one or more of density log, compressive and tensile rock strength, frictional strength of any discontinuity, wellbore path, position and type of wellbore failure, and mud weight;
calculating a first horizontal stress based on at least one of the physical properties based on an assumption of frictional forces in the earth;
calculating a second horizontal stress based on an assumption of a uniaxial elastic earth crust;
comparing the first horizontal stress with the second horizontal stress;
performing percentile filtering to assign a scaling factor;
calculating a third horizontal stress by applying the scaling factor based on both the assumption of the frictional forces and the assumption of the uniaxial elastic earth crust, the first horizontal stress, the second horizontal stress, and the third horizontal stress providing an optimum integrated solution for the principal horizontal stresses; and
using the optimum integrated solution for the principal horizontal stresses to at least one of design or implement a hydraulic fracturing process in the subterranean formation.

US Pat. No. 10,401,514

SEISMIC AZIMUTHAL GRADIENT ESTIMATION

CONOCOPHILLIPS COMPANY, ...

1. A method for processing 3-D seismic data comprising:a) forming, using a computing processor, common image location gathers of seismic traces as a function of time or depth, offset, and azimuth;
b) performing a linear regression on a gather at each time or depth to generate a model that includes an intercept term A, an average gradient term Bavg, an anisotropic gradient term Bcos, and an anisotropic gradient term Bsin;
c) calculating joint correlations of Bcos and Bsin seismic traces over a plurality of rectangular prisms in lateral position and time or depth, each prism centered about its own analysis point;
d) forming a vector whose rectangular coordinates are (M, R) for each analysis point, wherein M represent half of difference between mean-squared amplitudes of Bcos and Bsin within the prism, and R represent the average product of Bcos and Bsin within the prism;
e) calculating angles 2 ?up or 2 ?down the vector makes with the M axis;
f) taking one-half the rotation angles ?up or ?down as symmetry azimuths of vertical reservoir fractures; and
g) determining azimuthal amplitude gradient based on the determined symmetry azimuth,
wherein said common image location gathers of seismic traces describe subsurface heterogeneity of a reservoir.

US Pat. No. 10,370,949

THERMAL CONDITIONING OF FISHBONE WELL CONFIGURATIONS

CONOCOPHILLIPS COMPANY, ...

1. A method for steam assisted gravity drainage (SAGD) production of hydrocarbons, comprising:a) providing a plurality of horizontal production wells at a first depth at or near a bottom of a hydrocarbon play;
b) providing a plurality of horizontal injection wells, each injection well laterally spaced at a distance D from an adjacent production well, wherein said distance D is at least 50 meters:
c) providing a plurality of lateral wells originating from at least some of said horizontal production wells or horizontal injection wells or both, wherein said plurality of lateral wells cover at least 90% of said distance D and are open-hole laterals:
d) preheating a reservoir by injecting steam into all wells to establish fluid communication between said injection wells and said production wells;
e) preheating said plurality of lateral wells using electromagnetic heating, resistive heating, or chemical heating; and
f) continuing steam injection in said injection wells only, and simultaneously producing mobilized heavy oil from said production wells.

US Pat. No. 10,370,957

MEASURING DOWNHOLE TEMPERATURE BY COMBINING DAS/DTS DATA

CONOCOPHILLIPS COMPANY, ...

1. A method of measuring temperature variations along a wellbore, the method comprising:a) providing one or more fiber optic cables along a length of a wellbore;
b) recording distributed acoustic sensing (DAS) signals along the wellbore well using at least one fiber optic cable;
c) simultaneously recording distributed temperature sensing (DTS) signals from the well using at least one fiber optic cable;
d) low-pass filter and down-sample the DAS signals to obtain low-frequency DAS data;
e) converting the low-frequency DAS data to temperature variation using the following equation (1):
wherein D(x,t) is the low-frequency DAS, ? is the constant that converts optical phase rate to temperature variation, ?(t) is the drift noise existing in the DAS data;
f) estimating borehole temperature by minimizing the error function c using the following equation (2):

wherein T0 is the DTS data, D is inverted DAS data, and ? is a parameter that determines the relative importance of minimizing the DAS data misfit, as compared to DTS misfit, and ? may be frequency dependent.

US Pat. No. 10,352,143

BLOWDOWN METHOD FOR THERMAL RECOVERY PROCESSES

ConocoPhillips Company, ...

1. A method of blowdown for a steam chamber of a thermal recovery process, the method comprising:producing oil from a well using a thermal recovery process and steam injection to create a steam chamber;
reducing steam injection and reducing pressure in the steam chamber during blowdown;
introducing a blowdown mixture into the steam chamber during blowdown, the blowdown mixture comprising glycol and water;
adsorbing heat from the steam chamber onto the blowdown mixture;
introducing a viscosifying agent into the steam chamber during blowdown;
emulsifying oil from the steam chamber with the viscosifying agent to produce oil or emulsions thereof; and
recovering the blowdown mixture and residual oil or emulsions thereof from the steam chamber during blowdown.

US Pat. No. 10,338,242

SURFACE WAVE TOMOGRAPHY USING SPARSE DATA ACQUISITION

ConocoPhillips Company, ...

1. A method for monitoring a frozen subsurface structure to detect thawing-related problems, the method comprising:obtaining seismic data;
estimating travel time or phase delay or both of Rayleigh waves in the seismic data at a central frequency;
performing tomography to the travel time or the phase delay estimated at the central frequency to obtain a slice of seismic velocity at the central frequency;
repeating the estimating of the travel time or phase delay or both and the performing of the tomography to the travel time or the phase delay for a range of central frequencies;
performing a dispersion inversion on slices of seismic velocity for the range of central frequencies to obtain a 3-D velocity cube in depth, the 3-D velocity cube in depth providing an indication of thawing of the frozen subsurface structure; and
monitoring the thawing of the frozen subsurface structure via repeating at least the obtaining of the seismic data every day, every few days, or bi-weekly to determine a progression of the thawing.

US Pat. No. 10,302,615

METHOD TO TUNE RADIO FREQUENCIES TO BREAK EMULSIONS

CONOCOPHILLIPS COMPANY, ...

1. A method for determining an optimal radio frequency to break an emulsion, the method comprising:analyzing an oil and water interface of an emulsion to obtain chemical characterization data;
defining the oil and water interface at a molecular level based on the chemical characterization data;
simulating oscillation of molecules at the oil and water interface under different radio frequencies;
determining an optimal radio frequency to break the emulsion based on the oscillation of the molecules at the oil and water interface;
generating, at a frequency generator, the optimal radio frequency; and
applying the optimal radio frequency to the emulsion.

US Pat. No. 10,247,409

REMOTE PREHEAT AND PAD STEAM GENERATION

CONOCOPHILLIPS COMPANY, ...

1. A method of generating steam for use in a well to produce oil, said method comprising:a) heating a boiler feedwater located at a central processing facility (CPF) to produce heated boiler feedwater (HBFW);
b) transporting said HBFW to a well pad via hot water lines, wherein said HBFW has a subcool of 5-30° C.;
c) feeding said HBFW into a well pad boiler located at said well pad;
d) converting said HBFW to steam in said well pad boiler; and
e) injecting said steam into a well located at said well pad to produce oil.

US Pat. No. 10,635,762

RESERVOIR SOURING FORECASTING

ConocoPhillips Company, ...

1. A simulation method of a hydrocarbon field development configuration, comprising:a) providing a computer having one or more parallel graphics processing unit (GPU);
b) providing historical data for a hydrocarbon field;
c) inputting, into said GPU, the network topography, field layout, fluid description, and reservoir characteristics of one or more field configurations to create a field model of said hydrocarbon field;
d) utilizing object-oriented software, on said GPU, for dividing fluid flow physics models of a reservior field configuration the flow physics and H2S generation mechanisms of one or more fluids for said one or more field configurations into a plurality of individual basic elements of appropriate units for individual calculation so that the behavior of each individual basic element can be analyzed separately, wherein at least one of said basic elements incorporates said historical data;
e) defining one or more time scales and/or one or more spatial levels for simulating one or more individual basic elements;
f) simulating H2S generation and transport and fluid flow for at least one field model and one or more individual basic elements over said time scales and/or spatial level; and,
g) displaying the results of said simulating step.

US Pat. No. 10,584,554

TWO-MATERIAL PANDA PLUG

ConocoPhillips Company, ...

1. A two-material plug for a wellbore comprising:a) an eutectic alloy base layer,
b) a resin layer above and in physical contact with said eutectic alloy base layer,
c) a heater sleeve embedded within said resin layer and said eutectic alloy base layer and said heater sleeve reinforcing said two-material plug, and
d) wherein said two-material plug forms a rock-to-rock seal in a wellbore.

US Pat. No. 10,488,104

HEAT EXCHANGER SYSTEM WITH MONO-CYCLONE INLINE SEPARATOR

CONOCOPHILLIPS COMPANY, ...

1. A method of performing a heat exchange using a heat exchanger, the method comprising:providing a gas/liquid mixture to a gas/liquid separator, wherein the gas/liquid separator is an inline mono-cyclonic separator that is fluidly connected to an inlet of a core-in-shell heat exchanger, wherein the core-in-shell heat exchanger includes one or more cores disposed therein;
separating gas from liquid via the gas/liquid separator, wherein the separating occurs upstream of the inlet of the core-in-shell heat exchanger;
providing the gas to a first region of the core-in-shell heat exchanger;
providing the liquid to a sump, the sump fluidly coupled to the core-in-shell heat exchanger;
running the liquid in a second region through a core of the core-in-shell heat exchanger to exchange heat with a fluid running through the core;
maintaining a predetermined liquid level in the second region via one or more risers fluidly coupling the sump and the second region;
preventing gas accumulation in the sump via one or more vapor vents, the one or more vapor vents having an inlet formed at a top inside surface of the sump and an outlet disposed in the first region, thereby providing fluidic communication between the sump and the first region of the core-in-shell heat exchanger; and
wherein the one or more risers having an inlet disposed below a first liquid level within the sump and an outlet disposed below the predetermined liquid level in the second region, thereby providing fluidic communication between the sump and the second region of the core-in-shell heat exchanger.

US Pat. No. 10,480,781

REMOVAL OF CARBONACEOUS MICROBEADS

CONOCOPHILLIPS COMPANY, ...

1. A method for mitigating fouling in a once-through steam generator train comprising:obtaining foulant samples from the once-through steam generator train;
obtaining water samples from one or more locations along the once-through steam generator train;
recovering filtered solids from the water samples from the one or more locations;
characterizing at least one physical property of the foulant samples and the filtered solids;
determining locations along the once-through steam generator train that include foulant precursor based on a matching of the at least one physical property between the foulant samples and the filtered solids; and
installing an absorbent at locations that include the foulant precursor.

US Pat. No. 10,464,826

SEMI-CONTINUOUS TREATMENT OF PRODUCED WATER WITH BOILER FLUE GAS

ConocoPhillips Company, ...

1. A method of generating steam for enhanced oil recovery techniques, comprising:a) admitting a batch of untreated water into a contacting vessel, wherein said contacting vessel has a bubble cap tray and a demister;
b) bubbling heated waste flue gas from a steam generator through said bubble cap tray and through the batch of untreated water;
c) vaporizing the batch of untreated water with the heated waste flue gas to create intermediate steam;
d) condensing the intermediate steam mixed with the heated waste flue gas in a condenser to form a gas stream and a treated water stream;
e) heating the treated water stream in the steam generator to produce injection steam for enhanced oil recovery and the heated waste flue gas that is bubbled through the batch of untreated water in step b); and
f) removing sediments from the contacting vessel;
wherein two contacting vessels are operated sequentially, such that one can be in use while the other is being cleaned in step f).

US Pat. No. 10,458,228

LOW FREQUENCY DISTRIBUTED ACOUSTIC SENSING

ConocoPhillips Company, ...

1. A method for improving hydrocarbon production, where the method comprises:a) installing one or more fiber optic cables along a wellbore in a hydrocarbon formation;
b) installing one or more interrogators on at least one fiber optic cable;
c) interrogating at least one fiber optic cable with an interrogation signal;
d) obtaining one or more distributed acoustic sensing (DAS) datasets from the interrogator;
e) converting one or more DAS datasets from the interrogator into a continuous record;
f) transforming the continuous record with a low-pass filter to 1-50 milliHz while down sampling into a transformed well signal;
g) interpreting the transformed well signal; and
h) using the interpreted well signal to improve hydrocarbon production from said hydrocarbon formation.